Abstract: A system for analyzing fluid flow in unconventional, hydraulically-fractured porous media. In one embodiment, the system comprises a reservoir test sample, wherein the reservoir test sample comprises a core barrel, annular fluid, a synthetic tubing, supporting layers, and a core sample stack, wherein the core sample stack comprises one or more core slots.

Abstract: A system for analyzing fluid flow in unconventional, hydraulically-fractured porous media. In one embodiment, the system comprises a reservoir test sample, wherein the reservoir test sample comprises a core barrel, annular fluid, a synthetic tubing, supporting layers, and a core sample stack, wherein the core sample stack comprises one or more core slots.

Abstract: A primary drainage process, a core aging process, a spontaneous water imbibition process, a forced water imbibition process, a spontaneous hydrocarbon imbibition process, and a secondary drainage process is conducted on a rock sample. For each of the primary drainage process, the spontaneous water imbibition process, the forced water imbibition process, the spontaneous hydrocarbon imbibition process, and the secondary drainage process, a pressure distribution and a fluid saturation distribution are measured across multiple locations along the rock sample. For each of the locations, the pressure distribution and the fluid saturation distribution are combined to produce a capillary pressure bounding curve and scanning loop for the rock sample, and a relative permeability bounding curve and scanning loop are determined at least based on the measured fluid saturation and pressure distributions at the respective location.

Abstract: The present application provides a method and a system for determining a saturation exponent of a heterogeneous carbonate reservoir. The method comprises: dividing a target reservoir into at least two reservoir types in accordance with a predetermined rule; obtaining a correspondence relationship between a saturation exponent and a bound water saturation in each of the reservoir types; determining the reservoir type to which a to-be-measured core belongs in accordance with the predetermined rule; obtaining a bound water saturation of the to-be-measured core; and calculating the saturation exponent of the to-be-measured core according to the bound water saturation of the to-be-measured core on the basis of the correspondence relationship of the reservoir type to which the to-be-measured core belongs.

Abstract: A system method and apparatus for determining the disposition or orientation of a structural feature or structural feature present in a borehole core, such as a core sample. The apparatus is provided to capture data on structural features present in the core sample. The apparatus includes an orientation arrangement configured to determine the orientation, or change in orientation, of the apparatus, and a data-capturing arrangement configured to capture orientation data generated by the orientation arrangement. The orientation arrangement may include a gyroscope. The apparatus also includes an alignment arrangement operable to align the apparatus with a structural feature relating to the core sample. The alignment arrangement may include an alignment indicator operable to provide visual indication on the surface of the core sample. The method may include real-time delivery of data from the point of acquisition to cloud-based storage.

Abstract: The invention discloses a method and system for obtaining an evaluation model and an evaluation method and system for the plugging performance of drilling fluid. The method for obtaining the evaluation model comprises: applying a confining pressure to a holding device where a preset fracture model is located, wherein a displacement differential pressure of two ends of the holding device is a preset displacement differential pressure; measuring a flow of standard measuring fluid flowing through the preset fracture model under different confining pressures, wherein the different confining pressures gradually increase according to a first preset rule; and controlling to stop increasing the confining pressure when the flow of the standard measuring fluid flowing through the preset fracture model reaches a preset flow so as to compress the preset fracture model into the evaluation model at a micro-nano level.

Abstract: A method for testing an unconventional core sample is provided. The method involves loading the unconventional core sample into a sample holder and introducing fluid into the sample holder at an elevated pressure such that fluid is injected into the internal pore space of the unconventional core sample in order to resaturate the unconventional core sample with the fluid, wherein the fluid is selected from the group including a hydrocarbon fluid and a water-based formation fluid. An apparatus and a system used in combination with the method are also provided.

Abstract: Methods for determining the hardness and/or ductility of a material by compression of the material are provided as a first aspect of the invention. Typically, compression is performed on multiple sides of a geologic material sample in a contemporaneous manner. Devices and systems for performing such methods also are provided. These methods, devices, and systems can be combined with additional methods, devices, and systems of the invention that provide for the analysis of compounds contained in such samples, which can indicate the presence of valuable materials, such as petroleum-associated hydrocarbons. Alternatively, these additional methods, devices, and systems can also stand independently of the methods, devices, and systems for analyzing ductility and/or hardness of materials.

Abstract: The present disclosure discloses a core holding system, comprising: a sleeve in which a cavity capable of accommodating a core is formed; an adjustment plug set comprising a plurality of adjustment plugs having grooves of different diameters, wherein any one of the adjustment plugs is dismountably connectable to the sleeve, and when the adjustment plug is mounted on the sleeve, an end of the adjustment plug having the groove is insertable into the sleeve while abutting against the core; a heating module provided to sheathe the sleeve; and a thermal insulation module provided to sheathe the heating module.

Abstract: A perforation test target is provided. The perforation test target includes a metal plate and a core sample adhered to the metal plate at one end. The perforation test target further including a first sleeve adhered to the core sample, where a flow impedance of each of a plurality of portions of the first sleeve is based on a predetermined impedance map.

Abstract: A method and a system are provided to prepare a plurality of cuttings or other rock fragments or other porous media, such as cuttings from a drilling interval or multiple intervals, for computer tomographic scanning at the same time. A method and system also are provided to allow organization of mass quantities of cuttings or other rock fragments obtained from intervals of a well to more accurately categorize the cuttings to assist selections thereof for more detailed digital rock analysis, such as using SEM and FIB-SEM systems, are provided. A method and system also are provided to allow characterization of facies occurrence frequency of a depth interval using drill cuttings or other rock fragments. Computerized systems, computer readable media, and programs for performing the methods are also provided.

Abstract: A system for testing a core sample comprises a non-permeable sleeve configured to be placed over a core sample, a first pair of opposing actuators to apply opposing force to the non-permeable sleeve in a first axis normal to an axis of the core sample, a second pair of opposing actuators to apply opposing force to the non-permeable sleeve in a second axis normal to the axis of the core sample and normal to the first axis, a wellbore pressure reservoir to provide simulated wellbore pressure, and a formation pressure reservoir to provide simulated formation fluid pressure.

Abstract: Disclosed is an apparatus and method for testing a cemented bonding with the formation under wellbore pressure conditions. The apparatus comprises a pressure chamber containing a core of formation material. The cement material to be tested is allowed to set or bond to one side of the core while formation fluids under wellbore pressure conditions are present on the other side. Leakage of formation fluids is measured to evaluate the quality of the interface between the cement and formation materials.

Abstract: A tool comprising a tool body having an opening defined by interior walls extending into the tool body and a casing disposed within the opening. The tool further includes a scintillator material disposed within the casing and a first compressive member disposed within the tool body at a first axial location. The first axial location extends for a fraction of a total axial length of the casing and exerts a first radially compressive force at the first axial location.

Abstract: A rock core flow test system comprises a first high pressure accumulator, a second high pressure accumulator, and a fast opening flow control device coupled to a wellbore facing end of the rock core. The fast opening flow control device opens when a pressure differential across the flow control device exceeds a predetermined threshold. The first high pressure accumulator is coupled to at least one of a pore end of the rock core and a radial surface of the rock core. The second high pressure accumulator is coupled to the fast opening flow control device. The system further comprises a pressure sensor coupled to the rock core flow test system between the fast opening flow control device and the second high pressure accumulator.

Abstract: Systems and methods for gas sorption analysis, or analogous practices, of samples from unconventional reservoirs are described. The described analysis of samples is used to determine various properties of unconventional reservoirs, which are used in evaluating their worth and producibility.

Abstract: A method for determining the frequency-dependent dielectric permittivity spectrum of a rock sample, comprising:—defining a series of electromagnetic measurement data comprising at least a first measurement at a frequency from which a substantially frequency-independent value of dielectric permittivity ??, can be obtained; and at least second and third measurements at different frequencies from which values for frequency-dependent dielectric permittivity ?rock (f) can be obtained; and—using the first, second and third measurements to determine the frequency-dependent spectrum of the sample.

Abstract: According to various embodiments, a method may include measuring a first capacitance of a sample at a first frequency using a measurement system, measuring a second capacitance of the sample at a second frequency using the measurement system, calculating a ratio of the first capacitance to the second capacitance, and determining a formation water resistivity or conductivity of the sample using the ratio.

Abstract: A method for determining a property of a formation is described herein. The method includes positioning a wellbore tool at a location within a wellbore. A formation fluid is withdrawn from the formation using the wellbore tool. The formation fluid is passed through a flow line within the wellbore tool and a formation fluid sample is extracted from the flow line. The method further includes analyzing the formation fluid sample within the wellbore tool to determine a property of the formation fluid sample. The analysis is performed by excluding mud filtrate contamination within the flow line.

Abstract: An apparatus for measuring permittivity of a sample. The apparatus includes: a sample chamber including a sealed space portion in which a sample to be measured is put; a pressure adjusting unit for varying pressure by applying water pressure to the space portion of the sample chamber; a permittivity sensor for measuring permittivity of the sample and disposed outside the sample chamber; measurement conducting wires including conductors, installed to contact the sample and connected to the permittivity sensor by using electric wires; and a data logger for storing data relating to permittivity that is measured by the permittivity sensor.

Abstract: For the purpose of determining a weight concentration of a clay material in a porous medium sample, a specific active surface area of the clay material and an initial specific active surface area of the porous sample are measured. A water solution of the clay material is pumped through the sample and a specific active surface area of the sample of the porous medium is measured after the pumping. Then, the weight concentration of the clay material is calculated.

Abstract: A method of testing a core sample is provided. The method comprises determining an impedance map, attaching a sleeve to the core sample, and measuring a flow performance of the core sample. An impedance of each of a plurality of portions of the sleeve is based on the impedance map.

Abstract: Core samples may be easily, quickly, and safely split using a fluid cutter, such as a water jet. Cutting may take place upon exit of the sample from the drill tube, or core samples may be placed in core carriers for cutting. Core samples may also be stored and transported in the core carriers. Assessment of core samples is facilitated by scanning the core samples, with the results stored to produce a virtual core sample. Virtual core samples may be displayed on a computing device, including a core sample display device which simulates the appearance of a section of an actual core.

Abstract: A method and apparatus for monitoring swelling changes consists of a cylindrical cell assembly (80) capable of withstanding high pressure and high temperature with a wafer holder (48) containing a wafer (42) of solid sample. A sensor rod (56) moves in response to expansion or contraction of the sample wafer (42) and its movement is measured by either an LVDT sensor (66) or a magnetometer (116). Heat is provided via a heater (30) and pressure is controlled via a pressurization inlet (16) or pressurization fluid (68).

Abstract: A method and apparatus for monitoring swelling changes consists of a cylindrical cell assembly (80) capable of withstanding high pressure and high temperature with a wafer holder (48) containing a wafer (42) of solid sample. A sensor rod (56) moves in response to expansion or contraction of the sample wafer (42) and its movement is measured by either an LVDT sensor (66) or a magnetometer (116). Heat is provided via a heater (30) and pressure is controlled via a pressurization inlet (16) or pressurization fluid (68).

Abstract: A method of testing a core sample is provided. The method comprises determining an impedance map, attaching a sleeve to the core sample, and measuring a flow performance of the core sample. An impedance of each of a plurality of portions of the sleeve is based on the impedance map.

Abstract: An apparatus for use in a wellbore may include a tool having a first section configured to receive a core and a second section configured to collect a gas escaping from the core. The apparatus may also include a sensor associated to provide signals relating to a property of gas. In one aspect, the second section may be removable and may be pressurized. The apparatus may also include a recorder that records data representative of the signals received from the sensor. The recorder may record data while the tool is retrieved from the wellbore. A method for estimating a parameter of interest of a formation includes retrieving a core from the formation, collecting a gas escaping from the core as the core is retrieved to the surface, and measuring at least one property of gas while the core is retrieved to the surface.

Abstract: A method of testing a core sample is provided. The method comprises determining an impedance map, attaching a sleeve to the core sample, and measuring a flow performance of the core sample. An impedance of each of a plurality of portions of the sleeve is based on the impedance map.

Abstract: A method of estimating the recovery factor for the volume drained by at least one producing gas well that penetrates a tight gas reservoir or a coalbed methane reservoir, the method comprising: (a) calibrating changes in the isotopic composition of at least one component of the gas that is produced from the gas well with increasing recovery factor; (b) obtaining a sample of produced gas from the producing gas well and analyzing the sample to obtain the isotopic composition of the component of the produced gas; (c) using the calibration obtained in step (a) and the isotopic composition determined in step (b) to estimate the recovery factor for the volume drained by the gas well; (d) using the estimate of the recovery factor determined in step (c) and the cumulative volume of gas produced from the gas well to determine the volume drained by the gas well; and (e) optionally, periodically repeating steps (b) to (d) to determine any increase in recovery factor for the volume drained by the gas well with time and a

Abstract: Methods and apparatus to measure flow of a drilling fluid composition include a test housing including a test matrix located between an inlet and an outlet, a test valve connected between the inlet of the test housing and a fluid reservoir, and a pressure assembly configured to apply pressure to drilling fluid contained in the fluid reservoir. The apparatus and methods further include a sample valve connected to the outlet of the test housing and a measurement device configured to measure a filtrate fluid flowing through the outlet. A method to measure flow of a drilling fluid includes measuring an amount of filtrate fluid flowing through the test matrix as a function of time.

Abstract: A core sample holder assembly for performing laboratory core flooding experiments with a core sample: a pressure chamber provided by a tubular hull made of a carbon fiber composite material and an aluminum liner, and a pair of disk-shaped flanges; a flexible core sample holder sleeve within the pressure chamber, which sleeve comprises a tubular steel sheet with a plastic inner lining; an opening for injecting oil into an annular space between the hull and the sleeve; pressure control means for maintaining the oil at a predetermined pressure; an fluid injection port for injecting a fluid into a cylindrical core sample within the sleeve; a fluid outlet port arranged in the other flange for discharge of fluid from the core sample; and means for monitoring the migration of injected and/or pore fluid through the pores of the core sample.

Abstract: A method for analyzing properties of fluids contained in a geological formation including the steps of lowering a tool containing a chromatograph down to a location within the geological formation; setting the tool into position; extracting a sample of formation fluid from the location within the geological formation under controlled conditions and directing it into the chromatograph; and analyzing the composition of the formation fluid sample located downhole. The formation fluid sample is delivered to the chromatograph with or without admixture with a solvent. A sampling tool for use in the method forms another aspect of the invention.

Abstract: The current invention provides a method for enhancing the formation stability of water sensitive, reactive formations penetrated by a wellbore. The method of the current invention provides an accurate evaluation of the impact of cementing fluids on water sensitive, reactive formations and provides the ability to accurately formulate cementing fluids in order to enhance the stability of such formations. When necessary, the method of the current invention additionally provides for the application of an osmotic semi-permeable membrane to the face of the formation.

Abstract: A highly accurate, fully compensated, high spatial resolution, wave propagation system for measuring dielectric constant and resistivity of fluids or solids in a cylindrical enclosure and method for measuring well core characteristics in-situ or in a laboratory. One embodiment of the invention relies on waves propagated from transmitters above and below two spaced receivers which transmit and receive electromagnetic waves via slots on the inner periphery of a cylinder structure. The data is then processed with a CPU either down hole for later retrieval or on the surface for real-time monitoring.

Abstract: The present invention is related to an apparatus and a non-destructive method for determining the porosity of an element, particularly a thin film, formed on a substrate, said substrate being positioned in a pressurized chamber, said chamber being at a predetermined pressure and at a predetermined temperature. According to this method a gaseous substance like e.g. toluene vapour is admitted in said chamber and after a predetermined period of time the porosity of the thin film is determined by means of at least on ellipsometric measurement. Particularly, the optical characteristics resulting from this in-situ ellipsometry are used to determine the amount of gaseous substance condensed in the pores of the film. These amounts are used to calculate the porosity of the film.

Abstract: Device for studying physical properties of a solid sample (S) in the presence of fluids, at relatively high temperature and pressure. The device comprises an elongate rigid body (1) closed at the opposite ends thereof by two covers (2, 3), a flexible sheath (9) around the sample, cooperating with two end pieces (7, 8) so as to delimit, inside the rigid body, a containment vessel, injection means for displacing fluids under pressure through the sample in its sheath, measuring means for measuring various parameters of the sample and means (P) for injecting a fluid under pressure around flexible sheath (9) so as to exert a radial pressure and possibly an axial pressure around the sample, means for heating the fluid under pressure associated with at least one of the two covers (3, 4) and means including a turbine (12) for example, for homogenizing the temperature around the sheath by circulation of the fluid heated on contact with the heating means. The body is preferably made of a composite material.

Abstract: Shale reactivity is evaluated by testing a preserved test plug of shale sample in a triaxial test machine, the test plug being prepared by collecting a downhole shale sample and keeping it all times immersed in a preserving mineral oil so as to avoid dehydration, then applying radial and axial pressure on the test plug surrounded by mineral oil up to equilibration to overburden pressure, the test fluid being then contacted with the sample and the interaction of fluid and sample being evaluated by axial and radial deformations as measured by a triaxial detector apparatus sensitive to vertical and radial strains occurring across the shale sample, while the shale sample is subjected to any of a set of different conditions including a temperature or thermal potential, a hydraulic potential and/or a chemical potential. Only one fluid is tested on each sample.