Abstract: Techniques for determining rock properties include exerting a compressive load with a test apparatus across a rock sample that includes a specified length-to-diameter ratio; measuring, with a strain gauge, a strain on the rock sample during the compressive loading; determining, based at least in part on the compressive load, a mechanical property of the rock sample; and determining, based at least in part on the measured strain and the compressive load, an elastic property of the rock sample.

Abstract: The present disclosure describes methods and systems for fracturing geological formations in a hydrocarbon reservoir. One method includes forming a borehole in a hydrocarbon reservoir from a surface of the hydrocarbon reservoir extending downward into the hydrocarbon reservoir; transmitting an electromagnetic (EM) wave through the borehole: directing at least a portion of the EM wave to rocks at a location below the surface in the hydrocarbon reservoir; and fracturing the rocks at the location below the surface in the hydrocarbon reservoir by irradiating the rocks around the borehole using at least the portion of the EM wave, wherein irradiating the rocks elevates pore-water pressure in the rocks causing fracturing of the rocks.

Abstract: A method for correcting low permeability laboratory measurements for leaks. A pulse-decay permeability (PDP) experiment is performed on a core sample retrieved from a formation. The PDP experiment includes flowing fluid through the core sample in a sealed enclosure. In response to flowing the fluid through the core sample, a change in fluid pressure is measured over time. Based on the change in fluid pressure over time, a leakage of fluid from the sealed enclosure is determined. In response to determining the leakage of fluid from the sealed enclosure, an analytical model of the leakage is determined based on the change in fluid pressure over time.

Abstract: Methods and systems for determining permeability, as a function of pore pressure, and porosity of a subsurface formation. The method includes positioning a sample in a sample assembly comprising of a gas and a pressure gauge, inside a pressure vessel comprising gas or liquid and a pressure gauge, measuring a first gas pressure, pi, of the sample inside the pressure vessel, applying a second gas pressure, po, to the pressure vessel, the second gas pressure being greater than the first gas pressure, measuring a third gas pressure, p, at time, t, at location, x, from the inlet of sample inside the pressure vessel, determining a total gas mass per unit volume of the subsurface formation, m, and determining the permeability, k, of the subsurface formation as a function of pore pressure based at least in part on the first gas pressure, the second pressure, the third gas pressure, and the gas density, with a single test run.

Abstract: Techniques for determining rock properties include exerting a compressive load with a test apparatus across a rock sample that includes a specified length-to-diameter ratio; measuring, with a strain gauge, a strain on the rock sample during the compressive loading; determining, based at least in part on the compressive load, a mechanical property of the rock sample; and determining, based at least in part on the measured strain and the compressive load, an elastic property of the rock sample.

Abstract: The present disclosure describes methods and systems for fracturing geological formations in a hydrocarbon reservoir. One method includes forming a borehole in a hydrocarbon reservoir from a surface of the hydrocarbon reservoir extending downward into the hydrocarbon reservoir; transmitting an electromagnetic (EM) wave through the borehole: directing at least a portion of the EM wave to rocks at a location below the surface in the hydrocarbon reservoir; and fracturing the rocks at the location below the surface in the hydrocarbon reservoir by irradiating the rocks around the borehole using at least the portion of the EM wave, wherein irradiating the rocks elevates pore-water pressure in the rocks causing fracturing of the rocks.

Abstract: A compressive load is exerted with a test apparatus across a rock sample that has a specified length-to-diameter ratio. A strain on the rock sample is measured during the compressive loading with a strain gauge. A mechanical property of the rock sample is determined based at least in part on the compressive load. An elastic property of the rock sample is determined based at least in part on the measured strain and the compressive load.

Abstract: A method for determining the tensile strength of a rock sample comprising the steps of obtaining the rock sample, measuring a water content of the rock sample through a water measurement method, determining a matrix bulk modulus of the rock sample, wherein the matrix bulk modulus is determined through a matrix modulus method, heating the rock sample with electromagnetic energy such that the electromagnetic energy heats the water content in the rock sample from an initial temperature, wherein heating the water content causes a pore-water pressure of the rock sample to increase, detecting a break in the rock sample with a sensor, wherein the increase in the pore-water pressure causes the rock sample to break, wherein the break occurs at a break time, at a break temperature; and calculating the pore-water pressure through the water content, the matrix bulk modulus, and the break temperature of the water content.

Abstract: Techniques for determining rock properties include exerting a compressive load with a test apparatus across a rock sample that includes a specified length-to-diameter ratio; measuring, with a strain gauge, a strain on the rock sample during the compressive loading; determining, based at least in part on the compressive load, a mechanical property of the rock sample; and determining, based at least in part on the measured strain and the compressive load, an elastic property of the rock sample.

Abstract: Measures of the hydrocarbon content of a shale gas formation or reservoir are obtained. Nuclear magnetic resonance (NMR) well logs are obtained from a well in the reservoir measures of the total fluid, including both water and hydrocarbon, in the shale of the reservoir. NMR measurement at the surface of shale subsurface samples obtained in the form of drill cuttings or core samples from the same well provide measures of total water content of the shale. At the surface, pressure on the subsurface sample becomes that of atmospheric pressure, and hydrocarbon gas contained in the shale cuttings bleeds off The remaining fluid within the shale cuttings is then only water, which can be measured using NMR techniques. Compensation for the effect of drilling fluids (drilling mud) on the NMR measures from the fluid cuttings is also performed. The hydrocarbon gas content of the formation shale can be determined from the difference between formation NMR well log readings and NMR measurements from subsurface sample.

Abstract: The present disclosure describes methods and systems for fracturing geological formations in a hydrocarbon reservoir. One method includes forming a borehole in a hydrocarbon reservoir from a surface of the hydrocarbon reservoir extending downward into the hydrocarbon reservoir; transmitting an electromagnetic (EM) wave through the borehole: directing at least a portion of the EM wave to rocks at a location below the surface in the hydrocarbon reservoir; and fracturing the rocks at the location below the surface in the hydrocarbon reservoir by irradiating the rocks around the borehole using at least the portion of the EM wave, wherein irradiating the rocks elevates pore-water pressure in the rocks causing fracturing of the rocks.

Abstract: The present disclosure describes methods and systems for fracturing geological formations in a hydrocarbon reservoir. One method includes forming a borehole in a hydrocarbon reservoir from a surface of the hydrocarbon reservoir extending downward into the hydrocarbon reservoir; transmitting an electromagnetic (EM) wave through the borehole: directing at least a portion of the EM wave to rocks at a location below the surface in the hydrocarbon reservoir; and fracturing the rocks at the location below the surface in the hydrocarbon reservoir by irradiating the rocks around the borehole using at least the portion of the EM wave, wherein irradiating the rocks elevates pore-water pressure in the rocks causing fracturing of the rocks.

Abstract: A compressive load is exerted with a test apparatus across a rock sample that has a specified length-to-diameter ratio. A strain on the rock sample is measured during the compressive loading with a strain gauge. A mechanical property of the rock sample is determined based at least in part on the compressive load. An elastic property of the rock sample is determined based at least in part on the measured strain and the compressive load.

Abstract: Techniques for determining rock properties include exerting a compressive load with a test apparatus across a rock sample that includes a specified length-to-diameter ratio; measuring, with a strain gauge, a strain on the rock sample during the compressive loading; determining, based at least in part on the compressive load, a mechanical property of the rock sample; and determining, based at least in part on the measured strain and the compressive load, an elastic property of the rock sample.

Abstract: Methods and systems for determining permeability, as a function of pore pressure, and porosity of a subsurface formation. The method includes positioning a sample in a sample assembly comprising of a gas and a pressure gauge, inside a pressure vessel comprising gas or liquid and a pressure gauge, measuring a first gas pressure, pi, of the sample inside the pressure vessel, applying a second gas pressure, po, to the pressure vessel, the second gas pressure being greater than the first gas pressure, measuring a third gas pressure, p, at time, t, at location, x, from the inlet of sample inside the pressure vessel, determining a total gas mass per unit volume of the subsurface formation, m, and determining the permeability, k, of the subsurface formation as a function of pore pressure based at least in part on the first gas pressure, the second pressure, the third gas pressure, and the gas density, with a single test run.

Abstract: The present invention relates to methods for analyzing and modeling natural gas flow in subterranean shale reservoirs. In preferred embodiments, methodologies and techniques for determining and modeling natural gas flow in shale formations using methodologies and techniques capable of determining natural gas properties related to dual-continuum flow, permeability and pressure within a subterranean shale reservoir. In some embodiments, the natural gas properties are determined by subjecting a subterranean shale reservoir sample to pulse-decay analysis. In certain embodiments, the methodologies and techniques described herein may be used in various reservoirs exhibiting macroporosity and/or microporosity, such as fractured reservoirs and carbonate reservoirs composed of reservoir fluids.

Abstract: The disclosure relates to methods for determining imbibition of hydraulic fracturing fluids into hydrocarbon-bearing formations. More specifically, the disclosure relates to laboratory methods for determining certain unconventional flow parameters to measure the imbibition over time of hydraulic fracturing fluids into a low-permeability hydrocarbon-bearing rock formation.

Abstract: A method for determining the tensile strength of a rock sample comprising the steps of obtaining the rock sample, measuring a water content of the rock sample through a water measurement method, determining a matrix bulk modulus of the rock sample, wherein the matrix bulk modulus is determined through a matrix modulus method, heating the rock sample with electromagnetic energy such that the electromagnetic energy heats the water content in the rock sample from an initial temperature, wherein heating the water content causes a pore-water pressure of the rock sample to increase, detecting a break in the rock sample with a sensor, wherein the increase in the pore-water pressure causes the rock sample to break, wherein the break occurs at a break time, at a break temperature; and calculating the pore-water pressure through the water content, the matrix bulk modulus, and the break temperature of the water content.