Abstract: Methods for determining reservoir characteristics of a well can include receiving a first core from the well; performing an experiment to determine the wave velocity associated with a first direction of the first core, the experiment including: transmitting an ultrasonic wave through the first core in the first direction; receiving the transmitted ultrasonic wave; and determining a directional wave velocity of the first core based on the transmitted ultrasonic wave and the received transmitted ultrasonic wave, wherein the directional wave velocity represents a wave velocity along the first direction; rotating the first core about a longitudinal axis of the first core; and performing the experiment along a second direction of the first core.

Abstract: A method for estimating in-situ porosity based on cutting images employs a neural network trained with labeled images, the labels indicating wireline porosity values. The method may be used to obtain porosity values along a vertical, deviated or horizontal well, where wireline logging data is not available or unreliable. The method uses machine learning. Training and validating the neural network may be ongoing processes in the sense that any new labeled image that becomes available can be added to the training set and the neural network being retrained to enhance its predictive performance.

Abstract: The long-reach drilling machine is for exploration drilling and core sample collecting and comprises a drill string comprising a variable number of hollow drill rods, a drill bit installed at a first end of the drill string, a ground-resting drill base for installation outside a borehole, a mast attached to the drill base, a drill head installed on and movable along the mast and to which a second end of the drill string is connected, the drill head rotating the drill string, a core tube movable within the drill string between a first position at the drill string first end for receiving a core sample and a second position at the drill string second end, an borehole core tube displacer capable of displacing the core tube between its first and second positions, and an external core tube displacer, distinct from the borehole core tube displacer, comprising a frame that is fixed relative to the drill string, a tube prehension device mounted to the frame and capable of traction on the core tube, and an actuator mou

Abstract: The present invention comprises a drill cuttings composite core apparatus, system, and method that may utilize sieve shaker equipped with a solvent wash system to separate, clean, and size cuttings; a centrifugal mill equipped with a 12 tooth rotor and 1.0 mm ring sieve; a compactor mold that may be 1.5 inches in diameter and up to 6 inches long; dual piston compactor with independent air control valves; and a spacer on top of a bottom piston that may allow compacted core to be pushed up through top of mold for easy removal with no special tools or handling and so forth.

Abstract: An electromagnetic measurement tool for making multi-frequency, full tensor, complex, electromagnetic measurements includes a triaxial transmitter and a triaxial receiver deployed on a tubular member. An electronic module is configured to obtain electromagnetic measurements at four or more distinct frequencies. The measurement tool may be used for various applications including obtaining a resistivity of sand layers in an alternating shale-sand formation; computing a dielectric permittivity, a conductivity anisotropy, and/or a permittivity anisotropy of a formation sample; and/or identifying formation mineralization including discriminating between pyrite and graphite inclusions and/or computing weight percent graphite and/or pyrite in the formation sample.

Abstract: A method of performing a rock core flow performance test includes increasing a pressure applied to at least one surface of the rock core to a first pressure, measuring the pressure on a wellbore facing axial end of the rock core to determine a time interval over which the measured pressure drops from a second pressure to a third pressure, and determining a high pressure production ratio of the rock core based on the time interval.

Abstract: Apparatus and methods for measuring confining pressure, axial strain and radial strain of zonal isolation materials are described. This information is useful for evaluating these materials and predicting seal performance and potential failures of these materials.

Abstract: System and method of well space provision for forming a geologic testing space for proving an operation of an unproven downhole apparatus (78, 92), generally referred to as new technology, within an aged geology, during the rig-less abandonment of an aging well to, in use, reallocate operation of said unproven downhole apparatus from unproven to proven operation within a proximally similarly aged geology of said aging well, another aging well (79), a new well (80), or a field of said wells (79, 80) generally referred to as Brownfields and Greenfields, wherein said unproven downhole apparatus comprises a hydrodynamic bearing boring apparatus (1A, 1E, 1BM, 9AA, 92D) or a bore hole piston apparatus (1A, 1AF, 92A-92C, 92E-92G).

Abstract: Apparatus and methods for measuring confining pressure, axial strain and radial strain of zonal isolation materials are described. This information is useful for evaluating these materials and predicting seal performance and potential failures of these materials.

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 conveyance via wireline or drillstring in a wellbore extending into a subterranean formation, the apparatus comprising a coring bit assembly, a first motor operatively coupled to the coring bit assembly via a gear box to rotationally drive the coring bit assembly, and a second motor to drive the coring bit assembly into the formation while the coring bit assembly is rotated by the first motor, wherein the coring bit assembly comprises a feature to permit the coring bit assembly to be broken when the coring bit assembly becomes stuck in the formation.

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: 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: Samples of hydrocarbon are obtained with a coring tool. An analysis of some thermal or electrical properties of the core samples may be performed downhole. The core samples may also be preserved in containers sealed and/or refrigerated prior to being brought uphole for analysis. The hydrocarbon trapped in the pore space of the core samples may be extracted from the core samples downhole. The extracted hydrocarbon may be preserved in chambers and/or analyzed downhole.

Abstract: One or more embodiments and methods of analyzing a formation sample with in a coring tool are disclosed herein. The methods and embodiments may include extracting a first core from a sidewall of a wellbore with a coring tool at a first depth, ultrasonically measuring a sound speed of the first core, transmitting the ultrasonically measured sound speed of the first core to a surface display unit, analyzing the ultrasonically measured sound speed in real time, determining the quality of the first core, extracting a second core at the first depth if the first core is determined to be low quality, and extracting the second core at a second depth if the core first is determined to be high quality.

Abstract: Provided is an apparatus for extracting, analyzing, and storing gas in a drilled core on a ship.

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 computer-implemented method of characterizing elastic properties of a subsurface formation at various fluid saturation conditions is disclosed.

Abstract: Apparatus and methods for estimating a downhole property are provided. The apparatus may include a downhole tool having a predetermined temperature calibration based at least in part on an expected downhole temperature and a temperature controller in communication with the downhole tool that maintains a downhole tool temperature substantially within the predetermined temperature calibration. A method may include conveying a downhole tool having a predetermined temperature calibration based at least in part on an expected downhole temperature in a well borehole and adjusting the temperature of the downhole tool during downhole operation to maintain a downhole tool temperature substantially within the predetermined temperature calibration.

Abstract: Methods are described using resistivity ahead of a drill bit measurements obtained while drilling a subterranean well using a drilling mud. Resistivity data ahead of the bit is gathered during drilling and prior to penetrating a region of interest of a target subterranean formation using the drill bit and the drilling mud. The drill string progresses at target dip and azimuth angles toward the region on interest. The resistivity data is used to determine the top of the region of interest while the drill bit advances toward but does not penetrate the region. A core bit is then installed and a whole core of the region of interest obtained. Resistivity ahead of a drill bit measurements obtained while drilling a subterranean well may also be compared with conventional resistivity measurements obtained from one or more offset wells.

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 portable apparatus (111) to measure the change in behaviour of a rock specimen (113) in a fluid (25) of prescribed composition. The rock specimen (113) is prepared from drill cuttings, wellbore cave-in material, or core offcuts returned during the drilling operation of a wellbore. The apparatus (111) comprises a vessel (23) in which the fluid (25) and specimen (113) are placed. The apparatus (111) has a loading means for applying at least one load upon the specimen (113) and at least one measuring device (119) to measure the deformation of the specimen (113) in response to a change in load. The apparatus (111) also comprises a stirring system to maintain uniformity of the fluid (25) and a temperature regulating device (131) to maintain the fluid (25) at the desired temperature.

Abstract: Samples of hydrocarbon are obtained with a coring tool. An analysis of some thermal or electrical properties of the core samples may be performed downhole. The core samples may also be preserved in containers sealed and/or refrigerated prior to being brought uphole for analysis. The hydrocarbon trapped in the pore space of the core samples may be extracted from the core samples downhole. The extracted hydrocarbon may be preserved in chambers and/or analyzed downhole.

Abstract: Samples of hydrocarbon are obtained with a coring tool. An analysis of some thermal or electrical properties of the core samples may be performed downhole. The core samples may also be preserved in containers sealed and/or refrigerated prior to being brought uphole for analysis. The hydrocarbon trapped in the pore space of the core samples may be extracted from the core samples downhole. The extracted hydrocarbon may be preserved in chambers and/or analyzed downhole.

Abstract: Apparatus and methods to analyze downhole fluids are described herein. A disclosed example method involves obtaining a sample of a downhole fluid, and depressurizing at least a portion of the sample. Additionally, a disclosed example method involves ionizing at least the portion of the sample, and analyzing the ionized portion of the sample to determine a parameter of the downhole fluid.

Abstract: A method for treating an oil shale formation comprising dawsonite includes assessing a dawsonite composition of one or more zones in the formation. Heat from one or more heaters is provided to the formation such that different amounts of heat are provided to zones with different dawsonite compositions. The provided heat is allowed to transfer from the heaters to the formation. Fluids are produced from the formation.

Abstract: A wireline-conveyed side-wall core coring tool for acquiring side-wall core from a geological formation for performing in-situ side-wall core analysis. The coring tool has a core analysis unit operable to measure geophysical properties of an acquired side-wall core. The measured geophysical properties may be used to determine the success of the acquisition of side-wall cores by the coring tool. The core analysis unit is operable of performing an in-situ interpretation of measured geophysical property of the side-wall core and transmitting in near real-time the measurements or the interpretation results to surface data acquisition and processing apparatus.

Abstract: A method and apparatus for determining petrophysical parameters within a geologic formation pressurizes a geologic sample through a set of predetermined effective pressures, energizes the sample at each predetermined effective pressure with an electric current and/or sonic energy, and measures a conductivity value (electrical conductivity and/or sonic velocity). Permeability and/or porosity are also measured at each pressure through a traditional method and the functions are compared so that permeability and/or porosity can be subsequently derived from a sonic or electrical measurement of a comparable sample under a effective pressure. An apparatus is also described for acquiring the measurements under tri-axial compression, with a computerized interface in one embodiment.

Abstract: A method and apparatus for determining petrophysical parameters within a geologic formation pressurizes a geologic sample through a set of predetermined effective pressures, energizes the sample at each predetermined effective pressure with an electric current and/or sonic energy, and measures a conductivity value (electrical conductivity and/or sonic velocity). Permeability and/or porosity are also measured at each pressure through a traditional method and the functions are compared so that permeability and/or porosity can be subsequently derived from a sonic or electrical measurement of a comparable sample under a effective pressure. An apparatus is also described for acquiring the measurements under tri-axial compression, with a computerized interface in one embodiment.

Abstract: Samples of hydrocarbon are obtained with a coring tool. An analysis of some thermal or electrical properties of the core samples may be performed downhole. The core samples may also be preserved in containers sealed and/or refrigerated prior to being brought uphole for analysis. The hydrocarbon trapped in the pore space of the core samples may be extracted from the core samples downhole. The extracted hydrocarbon may be preserved in chambers and/or analyzed downhole.

Abstract: The present invention relates to assays for ascribing catalytic activity to rock samples by virtue of zero-valent transition metals potentially being present within the sample. Embodiments of the present invention are generally directed to novel assays for measuring intrinsic paleocatalytic activities (k) of sedimentary rocks for converting oil to gas and projecting the activities to the subsurface based on the measured linear relationship between ln(k) and temperature (T).

Abstract: The present invention is intended to take a sample of an emulsion circulating in a line. The emulsion is momentarily diverted from the main circulation line 1 thereof to a bypass line 2. By restoring circulation of the emulsion in main line 1, an emulsion sample still present in bypass line 2 is confined under pressure. The emulsion sample is then stabilized according to a well-known method. Since the size and the distribution of the drops no longer evolve with time, the sample can be observed and analyzed after sampling. The invention more particularly applies to the field of petroleum industry and it is notably intended to take a sample of a petroleum effluent in form of an emulsion at wellheads.

Abstract: Exfiltrometer apparatus includes a container for holding soil. A sample container for holding sample soil is positionable with respect to the container so that the sample soil contained in the sample container is in communication with soil contained in the container. A first tensiometer operatively associated with the sample container senses a surface water potential at about a surface of the sample soil contained in the sample container. A second tensiometer operatively associated with the sample container senses a first subsurface water potential below the surface of the sample soil. A water content sensor operatively associated with the sample container senses a water content in the sample soil. A water supply supplies water to the sample soil. A data logger operatively connected to the first and second tensiometers, and to the water content sensor receives and processes data provided by the first and second tensiometers and by the water content sensor.

Abstract: A method for measuring the infiltration of coring fluid into a core sample taken from a formation comprises a) providing a coring fluid containing cesium in a first concentration, b) using the coring fluid and a coring means to generate the core sample, c) determining the concentration of cesium present in the core sample; and d) comparing the core sample cesium concentration to the first concentration. A further preferred step comprises using the comparison in step d) to calculate the degree of infiltration of the coring fluid into the core sample.

Abstract: A method for predicting the secondary porosity system (SPS) porosity, and thereby permeability, of a coal bed involves determining an initial condition in the coal bed, including an initial SPS pressure and an initial sorbed gas composition, determining a pressure strain effect due to increasing the SPS pressure to a value greater than the initial SPS pressure, and determining a sorption strain effect due to changes in the sorbed gas composition resulting from decreasing the methane content and increasing the content of a stronger adsorbing fluid (SAG) relative to the initial sorbed gas composition. Preferably, the method uses data from test injections of water and/or a weaker adsorbing fluid (WAG) and a SAG. The data is used in the inventors' model to compute a SPS porosity and an absolute permeability at a reference SPS pressure and a reference sorbed gas composition. Preferably, the reference pressure is atmospheric pressure.

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.