18 results about "Formation evaluation" patented technology

A method of deploying a pulsed neutron logging tool. The method may comprise detecting natural gamma rays from the subterranean formation via one or more detectors of the pulsed neutron logging tool, broadcasting neutrons into the subterranean formation, and detecting neutron-induced gamma rays and natural gamma rays from the subterranean formation. The method may further comprise creating an inelastic spectrum, a capture spectrum, or a capture time decay from the natural gamma rays or the neutron-induced gamma rays, forming an inelastic yields, a capture elemental yields, or a formation sigma form the inelastic spectrum, the capture spectrum, or the capture time decay, creating a closure model from the inelastic yields and / or capture elemental yields and / or a formation sigma, and identifying a porosity, a mineral weight fraction, or a quality figure of merit from the closure model that quantifies geologic hydrogen reservoir quality.

The invention discloses a rock physical forward modeling method applicable to formation pore fluid of carbon dioxide, and relates to the technical field of petroleum and natural gas engineering. The method comprises the steps of firstly obtaining a carbon dioxide physical property constraint condition based on a state equation of carbon dioxide under a reservoir temperature and pressure condition, and then based on the constraint condition and according to logging information of a target well, core analysis and a laboratory test result, carrying out formation evaluation to calculate reservoir parameters. Then, based on reservoir parameters, the sandstone content is obtained through calculation, a rock physical volume model of a target well is constructed, and finally, based on the model, corresponding rock physical forward modeling is conducted according to different carbon dioxide saturations by means of the equivalent medium theory to generate stratum elastic attribute parameters. And the change relation between the corresponding saturation and the stratum elastic attribute parameters is quantitatively represented, so that the CO2 quantitative monitoring precision and reliability can be remarkably improved by comprehensively considering the special physical properties of CO2, the fluid replacement mechanism and the seismic wave propagation characteristics.

This invention describes a method of conducting formation evaluation and in particular inferring formation mineralogy when the formation is complex, and when the set of available downhole measurements is limited in information content or quality. One or more embodiments of the method can use a core mineralogy database to generate effective mineral assemblage that captures the natural systematic correlations between series of minerals.

This invention discloses an integrated logging-while-drilling (LOD) and measurement drill string assembly, relating to the field of oil and gas drilling engineering technology. It provides a series connection scheme for core protective drill string components, offering two switchable configurations: one with a mud motor and one without. Both configurations consist of an azimuth density neutron logging sub, a bidirectional communication power supply sub, an acoustic logging sub, a resistivity logging sub, an upper connecting sub, a flexible sub, a lower connecting sub, an azimuth gamma logging sub, and a steering actuator connected in series according to a fixed logic. The configuration with a mud motor only requires adding a mud motor at a designated location to complete the structural switch, without changing the series connection of the remaining subs. This assembly scheme is applicable to various drilling scenarios such as offshore exploration and development, deepwater drilling, complex directional wells, highly deviated wells, and horizontal wells. It enables integrated operations of geological steering, formation evaluation, and wellbore stability analysis during drilling, effectively improving drilling efficiency and reducing operational risks.

The invention relates to the technical field of reservoir formation evaluation of oil and gas basins, and provides a method for measuring the uniform temperature of an inclusion, which comprises the following steps: cooling a test sample until the test sample generates bubbles; raising the temperature of the test sample until bubbles disappear, and recording the temperature at the moment as a quasi-uniform temperature; cooling the test sample in the preset cooling interval; observing whether bubbles reappear in the test sample or not; if not, taking the current quasi-uniform temperature as the uniform temperature; and if yes, adding one unit experiment precision to the value of the quasi-uniform temperature, heating the test sample until the temperature reaches the quasi-uniform temperature, and repeatedly cooling and heating. According to the invention, the technical problem that the measurement result is easily influenced by the observation ability and subjective factors of measurement personnel to cause errors because the inclusion uniform temperature measurement method in the prior art depends on naked eye observation of whether bubbles disappear can be solved.

An apparatus and method utilize a trained machine learning model to synthesize formation evaluation data such as formation tops and LWD logs. In some instances, the synthesis of formation evaluation data may further be based upon drilling mechanics data collected during drilling, thus effectively enabling formation evaluation data to be synthesized primarily based upon surface measurements collected in real time, and in many cases without the need for collecting downhole measurements during drilling. In addition, in some instances, a machine learning model implemented as a generative adversarial network (GAN) may be used to synthesize formation evaluation data, with drilling mechanics data collected during drilling also used in some instances.

This invention relates to the field of oil and gas drilling, and discloses a method, apparatus, equipment, and medium for formation drillability assessment based on multi-source information fusion. It combines multi-source information from logging data, seismic data, and drilling data, and fully leverages complementary information from different data types through seismic frequency division and multi-channel information fusion, compensating for the shortcomings of single information sources in formation evaluation. Through the deep learning capabilities of neural networks, the neural network can learn complex nonlinear relationships from multi-source data, thereby improving the accuracy and reliability of formation drillability prediction. This invention is not limited to point-like or localized formation assessments; it can be extended to three-dimensional formation drillability calculations, achieving comprehensive assessment of the entire target area, effectively optimizing drilling paths, reducing drilling risks, and improving the accuracy of formation drillability assessment.

The invention relates to a natural gas hydrate three-phase saturation acquisition method and device, equipment and a medium, and relates to the technical field of formation evaluation. The method comprises the steps that a neutron porosity well logging interpretation model of a target well mixed interval is established based on neutron well logging data, establishing a neutron porosity interpretation model of a pure hydrate layer section which is similar to and adjacent to the mixed layer section of the target well in lithology; establishing a nuclear magnetic porosity well logging interpretation model of the mixed interval of the target well based on the nuclear magnetic resonance well logging data; establishing a nuclear magnetic porosity interpretation model of a pure hydrate layer section which is similar to the lithology of the target well mixed layer section and adjacent to the target well mixed layer section; and solving the three-phase saturation based on each model, the average formation porosity, the average neutron porosity and the average nuclear magnetic porosity. According to the acquisition method provided by the invention, the nuclear magnetic resonance-neutron interpretation model is established on the basis of nuclear magnetic resonance logging and neutron logging, the three-phase saturation of the hydrate, the free gas and the water in the mixed layer section is accurately acquired, and accurate reservoir parameters are provided for hydrate resource quantity evaluation.

The present disclosure relates to various systems and methods for utilizing these T1-T2 maps for enhanced formation evaluation. For example, as described in greater detail herein, these techniques include: (1) Tikhonov regularization used in an NMR inversion and resultant bias, (2) variable depth averaging of NMR two-dimensional (2D) maps on per T1-T2 basis, and (3) NMR kernel correction.

Examples described herein provide a computer-implemented method for performing automatic geosteering. The method includes receiving, by a processing system, formation evaluation data from a bottom hole assembly disposed in a wellbore. The method also includes determining, by the processing system, position data of a formation boundary from the formation evaluation data. The method also includes extrapolating, by the processing system, the position data to generate extrapolated position data of the formation boundary. The method also includes adjusting a trajectory of the wellbore based at least in part on the extrapolated position data of the formation boundary.

A method for classifying a subterranean formation includes deploying an electromagnetic logging tool in a wellbore penetrating the subterranean formation, causing the electromagnetic logging tool to make electromagnetic logging measurements in the wellbore, and evaluating the electromagnetic logging measurements with a trained machine learning primary classifier to classify the subterranean formation as either a 1D formation or a non-1D formation.

A method of obtaining formation evaluation data includes deploying an evaluation tool string into a drill string located in a wellbore. The method can also include seating the evaluation tool string in a portion of the drill string configured to optimize formation evaluation using the evaluation tool located therein.

This invention discloses a multi-adaptive rotary steerable logging-while-drilling (LSD) assembly, belonging to the field of oil drilling technology. This assembly uses a traditional steerable actuator as its core, forming multiple integrated solutions compatible with existing logging instruments, dual-master control architectures, Russian platforms, rotary steerable systems, and next-generation integrated systems. It is compatible with both drilling conditions with and without mud motors. Component cascading is achieved through flexible subs, conversion subs, upper and lower communication subs, and extension connection components of existing logging instruments. This effectively improves the problems of poor compatibility, low integration, measurement lag, insufficient communication stability under complex conditions, and weak compatibility of existing drilling assemblies. This invention has the advantages of multi-platform compatibility, near-bit synchronous measurement, bidirectional stable communication, and integrated geological guidance, and is suitable for drilling and formation evaluation operations in directional wells, horizontal wells, and extended reach wells.

The invention discloses a device and method for evaluating stratum properties by measuring near-bit data at high frequency, and relates to the technical field of stratum evaluation while drilling, and the device comprises an axial force measuring probe which is arranged at the rear part of a cutting tooth and can be in contact with the surface of a rock mass when the rock mass is cut by the cutting tooth; the packaging type measuring unit is arranged in the drill bit and is connected with the axial force measuring probe; the packaging type measuring unit comprises a data acquisition module used for acquiring axial force time sequence data acquired by an axial force measuring probe, and three-axis acceleration time sequence data, three-axis magnetic field intensity time sequence data and rotating speed time sequence data acquired by an internal sensor; and the data processing system is used for evaluating stratum properties according to the axial force time sequence data, the three-axis acceleration time sequence data, the three-axis magnetic field intensity time sequence data and the rotating speed time sequence data. The method does not depend on special equipment or independent construction operation, and is not interfered by factors such as mud types and borehole sizes.

Systems and methods are provided for analyzing sample images, such as for cuttings obtained during drilling of a geologic formation. The system utilizes automated image processing to detect and correct blurriness and saturated pixels in the sample images and control related devices based on the detection. The system allows the acquisition of high quality logging curves for real-time and / or near real-time geologic formation evaluation and geosteering.

Methods and systems for determining formation properties in subsurface operations include drilling into a formation with a disintegrating device disposed on a downhole string, monitoring dynamics information signals in the downhole string with a dynamics information sensor to obtain dynamics information data, applying a transfer function to the dynamics information data to obtain a dynamics information signature, and analyzing the dynamics information signature to determine a formation property of the formation drilled by the disintegrating device.

A method of deploying a pulsed neutron logging tool. The method may comprise detecting natural gamma rays from the subterranean formation via one or more detectors of the pulsed neutron logging tool, broadcasting neutrons into the subterranean formation, and detecting neutron-induced gamma rays and natural gamma rays from the subterranean formation. The method may further comprise creating an inelastic spectrum, a capture spectrum, or a capture time decay from the natural gamma rays or the neutron-induced gamma rays, forming an inelastic yields, a capture elemental yields, or a formation sigma form the inelastic spectrum, the capture spectrum, or the capture time decay, creating a closure model from the inelastic yields and / or capture elemental yields and / or a formation sigma, and identifying a porosity, a mineral weight fraction, or a quality figure of merit from the closure model that quantifies geologic hydrogen reservoir quality.