A method for extracting amplitude-versus-reflection angle, or amplitude-versus-offset information from input data, includes receiving the input data d, receiving an initial earth model V that includes at least a pressure-wave velocity vp, calculating an updated, extended domain earth model Ve based on the input data d, and the initial earth model V, using a full waveform inversion process, where the updated, extended domain earth model Ve is expressed in an extended domain, transforming the updated, extended domain earth model Ve from the extended domain to an ordinary domain, to obtain an ordinary domain updated earth model, extracting the amplitude-versus-reflection angle or amplitude-versus-offset information from the ordinary domain updated earth model; and generating an image of a subsurface that is indicative of the formation in the subsurface, based on the extracted amplitude-versus-reflection angle or amplitude-versus-offset information.
G06F 30/28 - Design optimisation, verification or simulation using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]
Methods and devices according to various embodiments perform reliable automated core-to-log depth matching. A core-to-log depth matching method includes: (i) pairing a core segment of core property values obtained by analyzing rock samples extracted at core depths from a well and a log segment of log property values obtained from measurements performed with a logging tool at log depths in the well, (ii) for each pair, determining a block-shifting of the core segment relative to the log segment so as to maximize a similarity metric between the core property values and the log property values, and (iii) performing an affine warping based on a tuned set of hyperparameters to adjust length of at least one of core segments.
A method (600) for inverting seismic data in elastic full waveform inversion (FWI) includes receiving (602) recorded seismic data; calculating (604) a wavefield with an attenuated interface wave based on an attenuation term that describes a wave attenuation along a travelling direction, wherein the attenuated interface wave corresponds to a wave traveling along a low-velocity guide or along an interface between two different media and the travelling direction is aligned with the interface; calculating (606) an updated velocity model using (1) the wavefield corresponding to the attenuated interface wave and (2) a body wave wavefield ; and generating (608) an image of a subsurface based on the updated velocity model of the subsurface.
A method for inverting seismic data in elastic full waveform inversion (FWI) includes receiving recorded seismic data; calculating a wavefield with an attenuated interface wave us based on an attenuation term that describes a wave attenuation along a travelling direction, wherein the attenuated interface wave us corresponds to a wave traveling along a low-velocity guide or along an interface between two different media and the travelling direction is aligned with the interface; calculating an updated velocity model using (1) the wavefield corresponding to the attenuated interface wave us and (2) a body wave wavefield ub; and generating an image of a subsurface based on the updated velocity model of the subsurface.
G01V 1/32 - Transforming one recording into another
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
5.
SYSTEM AND METHOD FOR PHASE CLOSURE MASKING FOR INTERFEROMETRIC SYNTHETIC APERTURE RADAR IMAGES
A device and method for determining surface displacement in a structure based on interferometric synthetic aperture radar (InSAR) includes receiving a stack of wrapped interferograms, performing multilooking on the stack of wrapped interferograms to generate multilooked interferograms, calculating phase closure residual maps based on the multilooked interferograms, calculating average phase closure residual maps based on the phase closure residuals, masking pixels in the multilooked interferograms, based on the average phase closure residual maps, to obtain masked interferograms, unwrapping the masked interferograms to obtain unwrapped, masked interferograms, and generating an InSAR time series product based on the unwrapped, masked interferograms.
Methods of seismic data processing employ neural networks and use a reflectivity image based on the acquired seismic data to generate output training datasets. The neural networks thus trained are used for generating production datasets, without ghosts, source effects, multiples and/or populating a predetermined set of bins in inline-crossline plane for a set of offset classes.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
G01V 1/32 - Transforming one recording into another
A method for autopicking of bedding in a well includes receiving image logs associated with the well, eliminating tool marks from the image logs, performing a grid search for (1) a vertical amplitude and (2) a horizontal shift of the bedding at plural sampling depths to obtain a predicted bedding, calculating an azimuth and a dip of the predicted bedding, and generating an image of the predicted bedding, wherein the image includes structural features of the well.
G06V 10/26 - Segmentation of patterns in the image fieldCutting or merging of image elements to establish the pattern region, e.g. clustering-based techniquesDetection of occlusion
G06V 10/44 - Local feature extraction by analysis of parts of the pattern, e.g. by detecting edges, contours, loops, corners, strokes or intersectionsConnectivity analysis, e.g. of connected components
G06V 10/72 - Data preparation, e.g. statistical preprocessing of image or video features
G06V 10/764 - Arrangements for image or video recognition or understanding using pattern recognition or machine learning using classification, e.g. of video objects
G06V 10/77 - Processing image or video features in feature spacesArrangements for image or video recognition or understanding using pattern recognition or machine learning using data integration or data reduction, e.g. principal component analysis [PCA] or independent component analysis [ICA] or self-organising maps [SOM]Blind source separation
G06V 10/82 - Arrangements for image or video recognition or understanding using pattern recognition or machine learning using neural networks
An uninterruptible cooling system includes a heat generating electronic component (104) enshrouded by a first container (105), a heat exchanger (106) enshrouded by a second container (103), and an Uninterruptible Cooling Supply (UCS) (201, 101). The uninterruptible cooling system further includes a heat exchange fluid and a fluid pump (108) to circulate the heat exchange fluid through conduits fluidly connecting the first container (105), the second container (103), and the UCS (201, 101). The UCS (201, 101) includes a radiator (410, 310, 210) enshrouded by a casing (409, 309, 209) and a heat transfer compound (411, 311, 211) positioned in a space external to the radiator (410, 310, 210) and internal to the casing (409, 309, 209). The heat transfer compound (411, 311, 211) within the Uninterruptible Cooling Supply has a solid to liquid phase change threshold that is greater than the operating temperature of the heat exchange fluid downstream of the heat exchanger (106) and less than the maximum temperature of the heat generating electronic component (104).
H05K 7/20 - Modifications to facilitate cooling, ventilating, or heating
F28D 15/02 - Heat-exchange apparatus with the intermediate heat-transfer medium in closed tubes passing into or through the conduit walls in which the medium condenses and evaporates, e.g. heat-pipes
A system (300, 200, 100) for cooling electronic components in a cooling fluid immersion environment includes a container (227, 127), a support (206, 106), a conduit, and a pump (409, 309, 109). The container retains a first cooling fluid (217, 117). The support suspends the electronic components in the container. The conduit transports the cooling gas (231) into the container. The conduit includes an inlet section (405, 340. 205, 105), a middle section (402. 202, 102), and an outlet section (815, 615, 515, 415, 215, 115). The inlet section includes a conduit inlet (341, 141) positioned outside of the container. The outlet section is submersed in the first cooling fluid within the container and beneath the electronic components such that the cooling gas exits the conduit and enters the first cooling fluid. The pump pressurizes and directs the cooling gas into and out of the conduit.
An imaging system (400) includes an imager (410) having first and second light sensors (465, 467), the first light sensor (465) being configured to record light in a first wavelength range and the second light sensor (467) being configured to record light in a second wavelength range, an alignment mechanism (440) configured to be attached to the imager (410), an illumination source (450) configured to generate a supercontinuum light beam, and a light shaping mechanism (452) configured to transform the supercontinuum light beam into a linear strip of light (450B). The alignment mechanism (440) is configured to adjust a position of the light shaping mechanism (452) so that a back scattered light (710), resulting from a scattering of the linear strip of light (450B) from a target (620), has an intensity above a given minimum for each of the first and second light sensors (465, 467).
An uninterruptible cooling system includes a heat generating electronic component enshrouded by a first container, a heat exchanger enshrouded by a second container, and an Uninterruptible Cooling Supply (UCS). The uninterruptible cooling system further includes a heat exchange fluid and a fluid pump to circulate the heat exchange fluid through conduits fluidly connecting the first container, the second container, and the UCS. The UCS includes a radiator enshrouded by a casing and a heat transfer compound positioned in a space external to the radiator and internal to the casing. The heat transfer compound within the Uninterruptible Cooling Supply has a solid to liquid phase change threshold that is greater than the operating temperature of the heat exchange fluid downstream of the heat exchanger and less than the maximum temperature of the heat generating electronic component.
A system for cooling electronic components in a cooling fluid immersion environment includes a container, a support, a conduit, and a pump. The container retains a first cooling fluid. The support suspends the electronic components in the container. The conduit transports the cooling gas into the container. The conduit includes an inlet section, a middle section, and an outlet section. The inlet section includes a conduit inlet positioned outside of the container. The outlet section includes outlets. The outlet section is submersed in the first cooling fluid within the container and beneath the electronic components such that the cooling gas exits the conduit and enters the first cooling fluid. The pump pressurizes and directs the cooling gas into and out of the conduit. The conduit is positioned downstream of the pump.
An assembly for directing a fluid flow of a dielectric oil through a server includes shrouds and a manifold including ducts, a recess, cavities, and channels. Each shroud houses a radiator that is connected to a conduit of a heat exchange loop. The manifold is removably coupled to the shrouds. The ducts fluidly connect to the shrouds and are formed along an upper surface of the manifold. The recess receives a lower end of a server. The cavities are formed within the recess, and each cavity houses one or more micropumps that circulate the dielectric oil through the server. The channels fluidly connect the micropumps and the ducts such that the dielectric oil is transferred from the ducts to the micropumps through the channels.
An assembly (17) for directing a fluid flow of a dielectric oil (57) through a server (13) includes shrouds (27) and a manifold (25) including ducts (75), a recess (83), cavities (91), and channels (99). Each shroud (27) houses a radiator (43) that is connected to a conduit of a heat exchange loop. The manifold (25) is removably coupled to the shrouds (27). The ducts (75) fluidly connect to the shrouds (27) and are formed along an upper surface of the manifold (25). The recess (83) receives a lower end of a server (13). The cavities (91) are formed within the recess (83), and each cavity houses one or more micropumps (29) that circulate the dielectric oil (57) through the server (13). The channels (99) fluidly connect the micropumps (29) and the ducts (75) such that the dielectric oil (57) is transferred from the ducts (75) to the micropumps (29) through the channels (99).
A method for calculating a cation exchange capacity, CEC, associated with a mineral sample includes receiving a material sample, altering the material sample to become a mineral sample that fits into an automated mineralogy and petrography system, analyzing the mineral sample with the automated mineralogy and petrography system to generate a mineral map, selecting only clays from the mineral map, calculating a total surface area of the clays in the mineral map, and calculating the CEC value of the material sample based on the total surface area of the clays of the mineral map and for all minerals in the mineral map.
G01N 23/2251 - Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups , or by measuring secondary emission from the material using electron or ion microprobes using incident electron beams, e.g. scanning electron microscopy [SEM]
A method for generating a training dataset for determining grain boundaries and minerals in a thin section of a rock sample, includes receiving the thin section of the rock sample, generating optical images of the thin section with an optical tool, generating mineral phase images of the thin section with an electron microscopy tool, computing first and second pseudo-images based on different features extracted from the optical images, generating the training dataset based on (1) the optical images, (2) the mineral phase images, and (3) the pseudo-images, and training a single deep neural network, DNN, based on the training dataset to simultaneously determine a mineral type and grain boundaries in the thin section of the rock sample.
G06V 10/143 - Sensing or illuminating at different wavelengths
G06V 10/26 - Segmentation of patterns in the image fieldCutting or merging of image elements to establish the pattern region, e.g. clustering-based techniquesDetection of occlusion
G06V 10/42 - Global feature extraction by analysis of the whole pattern, e.g. using frequency domain transformations or autocorrelation
G06V 10/82 - Arrangements for image or video recognition or understanding using pattern recognition or machine learning using neural networks
G06V 20/69 - Microscopic objects, e.g. biological cells or cellular parts
17.
HEAT EXTRACTION SYSTEM AND METHOD FOR EXTREME ENVIRONMENTS
A tool for extracting heat from a reservoir includes a shoe made of a material that withstands temperatures larger than 500° C., an outer pipe attached to the shoe, an inner pipe located within the outer pipe and forming an annulus with the outer pipe, the inner pipe having a bore, and a flexible connection configured to connect the outer pipe to the shoe so that the outer pipe is allowed to extend and contract without leaking a fluid inside the annulus. The inner pipe and the outer pipe are configured to form an uninterrupted loop path for the fluid, between a top of the annulus and a top of the bore while also allowing the fluid to directly contact the shoe.
F24T 10/17 - Geothermal collectors with circulation of working fluids through underground channels, the working fluids not coming into direct contact with the ground using tube assemblies suitable for insertion into boreholes in the ground, e.g. geothermal probes using tubes closed at one end, i.e. return-type tubes
A spine interconnect device for a datacenter with liquid-cooled electronic components. The spine interconnect device includes a first bus bar and a second bus bar. The first and second bus bars each include one or more high power conductors. The spine interconnect device further includes a spine support configured to suspend the first bus bar and the second bus bar above the electronic components and a plurality of tap-off boxes each with a plurality of power ports. Each tap-off box is connected to and supported by the first bus bar or the second bus bar. The spine interconnect device further includes a plurality of power cables interconnecting the plurality of power ports to the electronic components, a low power tray with networking cables, and a networking switch. The spine interconnect device further includes a cold water conduit and a warm water return conduit and a manifold.
A spine interconnect device (200) for a datacenter with liquid-cooled electronic components. The spine interconnect device (200) includes a first bus bar (204) and a second bus bar (206). The first and second bus bars (204, 206) each include one or more high power conductors. The spine interconnect device (200) further includes a spine support (202) configured to suspend the first bus bar (204) and the second bus bar (206) above the electronic components and a plurality of tap-off boxes (208) each with a plurality of power ports. Each tap-off box is connected to and supported by the first bus bar (204) or the second bus bar (206). The spine interconnect device (200) further includes a plurality of power cables (210) interconnecting the plurality of power ports to the electronic components, a low power tray (212) with networking cables (214), and a networking switch. The spine interconnect device (200) further includes a cold water conduit (216) and a warm water return conduit (218) and a manifold (220).
A method for generating an image (IF) of a subsurface includes receiving an initial earth model of the subsurface, receiving a recorded dataset d associated with the subsurface, generating a modeled dataset p based on the initial earth model and recording positions corresponding to the recorded dataset d, wherein the modeled dataset p is calculated based on a parameter volume PV that varies in time, updating the initial earth model, to generate an updated earth model, based on a misfit function that depends on the recorded dataset d and the modeled dataset p, and generating the image IF of the subsurface based on the updated earth model.
A multi-source for generating seismic waves includes plural source arrays, each source array being configured to generate seismic waves in water, and each source array being configured to be attached to a same towing vessel and plural umbilicals, each connecting a corresponding source array to the towing vessel. Each umbilical has a different length from the other umbilicals of the plural umbilicals when the plural source arrays are deployed in water so that an inline offset increment DX between any two adjacent source arrays, along an inline direction, is non-zero.
A heat extraction system for extracting heat from a reservoir, the system including a co-axial tool configured to be placed underground, the co-axial tool having an outer pipe and an inner pipe located within the outer pipe, each of the outer pipe and the inner pipe being connected to a shoe so that a fluid flows through an annulus defined by the inner and outer pipes, reaches the shoe, and flows through a bore of the inner pipe; and a power generator fluidly connected to a chemical processing unit to receive a fluid, and also fluidly connected with a first port to the inner pipe and with a second port to the outer pipe of the co-axial tool. A temperature difference of the fluid at the power generator and at the co-axial tool drives the power generator to generate energy.
F24T 10/17 - Geothermal collectors with circulation of working fluids through underground channels, the working fluids not coming into direct contact with the ground using tube assemblies suitable for insertion into boreholes in the ground, e.g. geothermal probes using tubes closed at one end, i.e. return-type tubes
E21B 41/00 - Equipment or details not covered by groups
E21B 43/295 - Gasification of minerals, e.g. for producing mixtures of combustible gases
A device for cooling an electronic component in a cooling fluid immersion environment includes a heatsink, a casing, a micropump, and a first conduit. The heatsink is removably attached to the electronic component and includes baffles that direct the cooling fluid to flow over the electronic component. The cooling fluid absorbs heat from the electronic component. The casing includes an inlet orifice, an outlet orifice, and an internal volume containing the heatsink and the electronic component. The micropump actuates to forcefully direct the cooling fluid from an area surrounding the device, through the inlet orifice, through the series of baffles of the heatsink, and out of the outlet orifice of the casing. Further, the first conduit is connected to the micropump and directs the cooling fluid to the series of baffles of the heatsink within the internal volume of the casing.
H01L 23/473 - Arrangements for cooling, heating, ventilating or temperature compensation involving the transfer of heat by flowing fluids by flowing liquids
A device for cooling an electronic component in a cooling fluid immersion environment includes a heatsink, a casing, a micropump, and a first conduit. The heatsink is removably attached to the electronic component and includes baffles that direct the cooling fluid to flow over the electronic component. The cooling fluid absorbs heat from the electronic component. The casing includes an inlet orifice, an outlet orifice, and an internal volume containing the heatsink and the electronic component. The micropump actuates to forcefully direct the cooling fluid from an area surrounding the device, through the inlet orifice, through the series of baffles of the heatsink, and out of the outlet orifice of the casing. Further, the first conduit is connected to the micropump and directs the cooling fluid to the series of baffles of the heatsink within the internal volume of the casing.
A support for directing a fluid flow of a dielectric oil through a server includes an upper deck, a central channel, a cooling channel, a lip, and a channel orifice. The upper deck extends in a longitudinal plane and provides an abutment surface for a connection face of the server. The central channel is formed as a first opening of the upper deck that contains the server. The cooling channel is formed as a second opening of the upper deck, and houses a conduit and a radiator of a heat exchanger. The lip protrudes from the upper deck, and directs the fluid flow of the dielectric oil from the central channel into the cooling channel. Further, the channel orifice fluidly connects the cooling channel to the central channel, and the dielectric oil is transferred from the cooling channel into the central channel through the channel orifice.
A method for depth matching well log data associated with a subsurface includes receiving recorded well log data, dividing the recorded well log data into a primary log and a secondary log, wherein the primary log is related to a first measured parameter and the secondary log is related to a second measured parameter, which is different from the first measured parameter, calculating depth shifts for the primary log and performing depth matching of the primary log, based on the calculated depth shifts, to obtain a depth matched primary log, applying the same depth shifts to the second log, and generating a map of geological features of the subsurface based on the depth matched primary and secondary logs.
G06F 30/28 - Design optimisation, verification or simulation using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]
A support for directing a fluid flow of a dielectric oil through a server includes an upper deck, a central channel, a cooling channel, a lip, and a channel orifice. The upper deck extends in a longitudinal plane and provides an abutment surface for a connection face of the server. The central channel is formed as a first opening of the upper deck that contains the server. The cooling channel is formed as a second opening of the upper deck, and houses a conduit and a radiator of a heat exchanger. The lip protrudes from the upper deck, and directs the fluid flow of the dielectric oil from the central channel into the cooling channel. Further, the channel orifice fluidly connects the cooling channel to the central channel, and the dielectric oil is transferred from the cooling channel into the central channel through the channel orifice.
H05K 7/20 - Modifications to facilitate cooling, ventilating, or heating
B33Y 80/00 - Products made by additive manufacturing
F28D 1/02 - Heat-exchange apparatus having stationary conduit assemblies for one heat-exchange medium only, the media being in contact with different sides of the conduit wall, in which the other heat-exchange medium is a large body of fluid, e.g. domestic or motor car radiators with the heat-exchange conduits immersed in the body of fluid
28.
NEAR-SURFACE P-VELOCITY ESTIMATE METHOD AND SYSTEM
A method for mapping near-surface velocities to layers of a subsurface includes receiving seismic data D associated with the subsurface, wherein the seismic data D includes at least one of P-wave energy, S-wave energy, or a mixture of P- and S-wave energy, applying a predictive deconvolution method to the seismic data D to calculate a synthetic gather F, of the subsurface, and generating a velocity model of the subsurface based on the synthetic gather F, where the velocity model maps near-surface velocities to the layers of the subsurface. A prediction deconvolution operator of the predictive deconvolution method, which corresponds to the synthetic gather F with changed sign, is a Green's function of the subsurface without any free surface.
A device for generating a chronostratigraphic chart for a given subsurface includes receiving biostratigraphic data including taxon names, standardizing the taxon names in the biostratigraphic data to obtain standardized taxon names, generating species biostratigraphic events from the standardized taxon names by estimating an abundance of each species in the biostratigraphic data with respect to a sample depth, assigning ages to the species biostratigraphic events, and generating the chronostratigraphic chart based on the species biostratigraphic events and the assigned ages.
A heat extraction system for extracting heat from a reservoir, the system including a co-axial tool configured to be placed underground, the co-axial tool having an outer pipe and an inner pipe located within the outer pipe, each of the outer pipe and the inner pipe being connected to a shoe so that a fluid flows through an annulus defined by the inner and outer pipes, reaches the shoe, and flows through a bore of the inner pipe; and a power generator fluidly connected to a chemical processing unit to receive a fluid, and also fluidly connected with a first port to the inner pipe and with a second port to the outer pipe of the co-axial tool. A temperature difference of the fluid at the power generator and at the co-axial tool drives the power generator to generate energy.
F24T 10/17 - Geothermal collectors with circulation of working fluids through underground channels, the working fluids not coming into direct contact with the ground using tube assemblies suitable for insertion into boreholes in the ground, e.g. geothermal probes using tubes closed at one end, i.e. return-type tubes
E21B 41/00 - Equipment or details not covered by groups
E21B 43/295 - Gasification of minerals, e.g. for producing mixtures of combustible gases
31.
METHOD AND SYSTEM FOR AUTOMATIC DETECTION OF FAIRY CIRCLES
A method for finding sub-circular surface depression, SSD, which contributes to exploration of a subsurface resource, the method including receiving (900) target images (401) associated with an area of interest, generating (902) pseudo-labels (506) with a foundation model (400) by prompting the foundation model (400) with input images (502), which are different from the target images (401), training (904) a semantic segmentation model (500) based on the pseudo-labels (506), generating (906) SSD predictions (510) with the semantic segmentation model (500), from the target images (401), and producing (908) an image of the area of interest, based on the SSD predictions (510), to identify a location of the resource.
G06V 10/26 - Segmentation of patterns in the image fieldCutting or merging of image elements to establish the pattern region, e.g. clustering-based techniquesDetection of occlusion
G06V 10/774 - Generating sets of training patternsBootstrap methods, e.g. bagging or boosting
G06V 10/82 - Arrangements for image or video recognition or understanding using pattern recognition or machine learning using neural networks
A method for extracting and displaying desired information from a set of tables includes storing a set of tables including information associated with a subsurface of the Earth; receiving a user query; selecting a table from the set of tables based on an embedding search performed for the user query, on a vector database of table-column questions of the set of tables; selecting one or more columns from the table based on a likelihood estimation performed in an embedding space, between (1) the user query and (2) a table summary and descriptions of columns for the selected table; determining one or more rows associated with the one or more columns; and displaying one or more answers in response to the user query.
Formation evaluation methods and apparatuses use a COMET technique to cross-calibrate the total porosity and effective porosity approaches using logging tool measurements. The COMET technique minimizes the difference between total water saturation value and effective water saturation value assuming that non-conductive pore volume calculated using total porosity and using effective porosity is the same.
An imaging system includes an imager having first and second light sensors, the first light sensor being configured to record light in a first wavelength range and the second light sensor being configured to record light in a second wavelength range, an alignment mechanism configured to be attached to the imager, an illumination source configured to generate a supercontinuum light beam, and a light shaping mechanism configured to transform the supercontinuum light beam into a linear strip of light. The alignment mechanism is configured to adjust a position of the light shaping mechanism so that a back scattered light, resulting from a scattering of the linear strip of light from a target, has an intensity above a given minimum for each of the first and second light sensors.
A method for preparing a block for chemical analysis includes providing a substantially inorganic mounting medium; providing a sample material that includes plastic and another material; mixing the substantially inorganic mounting medium with the sample material to generate the block; and smoothing a first surface of the block to expose the plastic.
A method for estimating a location on the ocean bottom for drilling a well for exploring a geothermal reservoir, includes receiving data sets indicative of the geothermal reservoir and ocean conditions above the geothermal reservoir, selecting plural factors represented in the data sets and indicative of the geothermal reservoir, associating each factor of the plural factors with one or more criterion that indicates a desirability of drilling the well at the location of the geothermal reservoir, assigning to each factor an individual score based on the one or more criterion, aggregating the individual scores into a single overall score, and selecting the location of the geothermal reservoir when the single overall score is larger than a given threshold.
A device for cooling an electronic component includes a casing enclosing a cavity, an inlet orifice, an outlet orifice, a radiative opening, and a reflective surface. The inlet orifice and the outlet orifice are hydraulically connected by the cavity. The cavity receives a cooling fluid from the inlet orifice and directs the cooling fluid to the outlet orifice. The radiative opening is disposed between the cavity and the electronic component and permits transmission of radiation from the electronic component to the cooling fluid in the cavity. The reflective surface is disposed in the cavity and reflects the radiation in the cavity.
A method for identifying minerals (342) in a geological sample (200) includes receiving (302) the geological sample (200) associated with a first subsurface, and generating (333) a labelled map (334) by applying an image registration procedure 5 (332) to (1) plural optical images (310) generated based on the geological sample (200), and (2) a mineral phases image (330) generated based on the geological sample (200). Each optical image of the plural optical images (310) is uniquely associated with one of a different polarization of an incident light or no polarization.
G06V 10/26 - Segmentation of patterns in the image fieldCutting or merging of image elements to establish the pattern region, e.g. clustering-based techniquesDetection of occlusion
G06V 10/80 - Fusion, i.e. combining data from various sources at the sensor level, preprocessing level, feature extraction level or classification level
G06V 10/82 - Arrangements for image or video recognition or understanding using pattern recognition or machine learning using neural networks
39.
GEOLOGIC INTERPRETATION METHOD AND SYSTEM BASED ON VISION-LANGUAGE MODEL
A method for delineating geological features of a surveyed subsurface with a vision-language model, VLM, the method including receiving verbal and/or written descriptions of the geological features, from a user, converting the verbal and/or written descriptions into interpretable input data using a large language model, LLM, configuring a pretrained VLM, based on the interpretable input data and geological images of another subsurface, to obtain a tailored VLM, and delineating with the tailored VLM, the geological features in an image of the subsurface, which is generated based on input seismic data d acquired over the subsurface.
A method for seismic exploration using a full waveform inversion, FWI, the method including receiving an initial velocity model V of the subsurface, receiving recorded data d related to the subsurface, generating synthetic data u related to the subsurface, using the initial velocity model V and a source signature of a source S, transforming the recorded data d and the synthetic data u, with a complex wavelet transform, into complex wavelet transformed recorded data d′ and complex wavelet transformed synthetic data u′, respectively, updating the initial velocity model V using the FWI to generate an updated velocity model, based on a cost function J which depends on the complex wavelet transformed recorded data d′ and the complex wavelet transformed synthetic data u′, and generating an image of a surveyed subsurface formation.
A method for imaging a formation of a subsurface includes receiving input data d related to the subsurface, generating synthetic data u related to the subsurface, by applying an implicit finite-difference approach to a reflectivity model r, updating a velocity model V based on the input data d and the synthetic data u, and generating an image of the formation in the subsurface based on the updated velocity model, wherein the formation is used to locate natural resources.
A joint timelapse full waveform inversion (FWI) method for estimating physical properties of a subsurface includes receiving seismic data related to the subsurface, wherein the seismic data includes a baseline dataset dB and a monitor dataset dM, defining an objective function of the FWI method, calculating a baseline gradient gB of the objective function for the baseline dataset dB, and a monitor gradient gM of the objective function for the monitor dataset dM, computing a baseline preconditioner P′B for the baseline dataset dB and a monitor preconditioner P′M for the monitor dataset dM so that each of the baseline preconditioner P′B and the monitor preconditioner P′M reflects similarities and/or differences of geometrical features of the baseline and monitor acquisition surveys, and determining physical properties of the subsurface based on a baseline physical properties update and a monitor physical properties update.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
43.
SYSTEM AND METHOD FOR EXTRACTING AMPLITUDE-VERSUS-ANGLE OR OFFSET INFORMATION FROM SEISMIC DATA
A method for extracting amplitude-versus-reflection angle, or amplitude- versus-offset information from input data, includes receiving (300) the input data d, receiving (302) an initial earth model V that includes at least a pressure-wave velocity vp, calculating (306) an updated, extended domain earth model Ve based on the input data d, and the initial earth model V, using a full waveform inversion process, where the updated, extended domain earth model Ve is expressed in an extended domain, transforming (308) the updated, extended domain earth model Ve from the extended domain to an ordinary domain, to obtain an ordinary domain updated earth model, extracting (310) the amplitude-versus-reflection angle or amplitude-versus-offset information from the ordinary domain updated earth model; and generating (312) an image of a subsurface that is indicative of the formation in the subsurface, based on the extracted amplitude-versus-reflection angle or amplitude-versus-offset information.
An umbilical-based marine acquisition system includes an umbilical cable configured to be attached with a proximal end to a vessel and to provide compressed air to a seismic source, a sensor loaded section having plural seismic sensors distributed along a length of the sensor loaded section, the sensor loaded section being configured to be attached with a distal end to another sensor loaded section or to the seismic source, and an umbilical-sensor section connection configured to connect a distal end of the umbilical cable to a proximal end of the sensor loaded section. The umbilical-sensor section connection and the sensor loaded section are configured to transmit seismic data acquired by the plural seismic sensors to the vessel.
A tool (100) for extracting heat from a reservoir includes a shoe (130) made of a material that withstands temperatures larger than 500 ˚C, an outer pipe (120) attached to the shoe (130), an inner pipe (110) located within the outer pipe (120) and forming an annulus (112) with the outer pipe (120), the inner pipe (110) having a bore (114), and a flexible connection (140) configured to connect the outer pipe (120) to the shoe (130) so that the outer pipe (120) is allowed to extend and contract without leaking a fluid (154) inside the annulus (112). The inner pipe (110) and the outer pipe (120) are configured to form an uninterrupted loop path (156) for the fluid (154), between a top of the annulus (112) and a top of the bore (114) while also allowing the fluid (154) to directly contact the shoe (130).
F24T 10/17 - Geothermal collectors with circulation of working fluids through underground channels, the working fluids not coming into direct contact with the ground using tube assemblies suitable for insertion into boreholes in the ground, e.g. geothermal probes using tubes closed at one end, i.e. return-type tubes
46.
HEAT EXTRACTION SYSTEM AND METHOD FOR EXTREME ENVIRONMENTS
A tool (100) for extracting heat from a reservoir includes a shoe (130) made of a material that withstands temperatures larger than 500 °C, an outer pipe (120) attached to the shoe (130), an inner pipe (110) located within the outer pipe (120) and forming an annulus (112) with the outer pipe (120), the inner pipe (110) having a bore (114), and a flexible connection (140) configured to connect the outer pipe (120) to the shoe (130) so that the outer pipe (120) is allowed to extend and contract without leaking a fluid (154) inside the annulus (112). The inner pipe (110) and the outer pipe (120) are configured to form an uninterrupted loop path (156) for the fluid (154), between a top of the annulus (112) and a top of the bore (114) while also allowing the fluid (154) to directly contact the shoe (130).
F24T 10/17 - Geothermal collectors with circulation of working fluids through underground channels, the working fluids not coming into direct contact with the ground using tube assemblies suitable for insertion into boreholes in the ground, e.g. geothermal probes using tubes closed at one end, i.e. return-type tubes
47.
Sparse ocean bottom nodes and mini-streamer acquisition system for enhancing subsurface imaging
A correlated sparse nodes and mini-streamers system for collecting seismic data includes plural nodes distributed on the ocean bottom, and a mini-streamer spread that includes plural mini-streamers. The plural nodes and the mini-streamer spread are configured to simultaneously collect seismic data from a surveyed subsurface, and wherein a length of the mini-streamers is equal to or less than three times an inline distance between adjacent nodes of the plural nodes.
A method for raw seismic data inversion includes receiving raw seismic data acquired over an underground formation, receiving an initial velocity model of the underground formation, performing a dynamic resolution full waveform inversion, DR-FWI, on the raw seismic data so that a tomography component of a velocity gradient G is compensated to generate a compensated tomographic component while a diving wave component and a migration component are preserved, outputting an updated velocity model based on an illumination compensated velocity gradient G′, which is calculated based on the compensated tomographic component), and locating natural resources in the underground formation using the updated velocity model updated by the DR-FWI.
A heat extraction system (400) for extracting heat from a reservoir, the system including a co-axial tool (420) configured to be placed underground, the co-axial tool (420) having an outer pipe (520) and an inner pipe (510) located within the outer pipe (520), each of the outer pipe (520) and the inner pipe (510) being connected to a shoe (530) so that a fluid flows through an annulus (512) defined by the inner and outer pipes, reaches the shoe (530), and flows through a bore (514) of the inner pipe (510); and a power generator (430) fluidly connected to a chemical processing unit (410) to receive a fluid (422), and also fluidly connected with a first port to the inner pipe (510) and with a second port to the outer pipe (520) of the co-axial tool (420). A temperature difference of the fluid (422) at the power generator (430) and at the co- axial tool (420) drives the power generator (430) to generate energy.
E21B 43/24 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
F24T 10/17 - Geothermal collectors with circulation of working fluids through underground channels, the working fluids not coming into direct contact with the ground using tube assemblies suitable for insertion into boreholes in the ground, e.g. geothermal probes using tubes closed at one end, i.e. return-type tubes
50.
SYSTEM AND METHOD FOR LEAST-SQUARES MIGRATION OF TIME-LAPSE SEISMIC DATA
A least-square migration, LSM, based method for generating a 4D image of a subsurface, the method including receiving seismic data d related to the subsurface, the seismic data d including a baseline dataset dB and a monitor dataset dM, calculating a baseline filter B and a monitor filter M based on a same common reflectivity r of the subsurface and corresponding remigrated baseline data mB1 and remigrated monitor data mM1 so that the base filter B applied to the remigrated baseline data mB1 equals the monitor filter M applied to the remigrated monitor data mM1, applying the baseline filter B to raw migrated baseline data mB0 and applying the monitor filter M to raw migrated monitor data mM0 to generate LSM baseline data mB and LSM monitor data mM, and generating the 4D image of the subsurface based on the LSM baseline data mB and the LSM monitor data mM.
A heat extraction system (400) for extracting heat from a reservoir, the system including a co-axial tool (420) configured to be placed underground, the co-axial tool (420) having an outer pipe (520) and an inner pipe (510) located within the outer pipe (520), each of the outer pipe (520) and the inner pipe (510) being connected to a shoe (530) so that a fluid flows through an annulus (512) defined by the inner and outer pipes, reaches the shoe (530), and flows through a bore (514) of the inner pipe (510); and a power generator (430) fluidly connected to a chemical processing unit (410) to receive a fluid (422), and also fluidly connected with a first port to the inner pipe (510) and with a second port to the outer pipe (520) of the co-axial tool (420). A temperature difference of the fluid (422) at the power generator (430) and at the co- axial tool (420) drives the power generator (430) to generate energy.
F24T 10/17 - Geothermal collectors with circulation of working fluids through underground channels, the working fluids not coming into direct contact with the ground using tube assemblies suitable for insertion into boreholes in the ground, e.g. geothermal probes using tubes closed at one end, i.e. return-type tubes
E21B 43/24 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
Computing device, computer instructions and method for processing input seismic data d associated with a surveyed subsurface. The method includes: receiving the input seismic data d recorded in a first domain by seismic receivers that travel in water, the input seismic data d including pressure data and particle motion data; generating a model p in a second domain, which is different from the first domain, to describe the input seismic data d; processing the model p to generate an output seismic dataset with attenuated noise; and generating an image of the surveyed subsurface based on the output seismic dataset.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
A method for internal multiple attenuation of seismic data associated with a subsurface. The method includes receiving seismic data d associated with the subsurface, wherein the seismic data d includes primaries and internal multiples, receiving a first reflectivity r1 associated with a first formation in the subsurface, calculating a second reflectivity r2 associated with a second formation in the subsurface, based on wavefield extrapolation of the seismic data d and a reflection in the first reflectivity r1, wherein the second formation is different from the first formation, calculating the internal multiples using (1) wavefield extrapolation of the seismic data d, (2) the reflection in the first reflectivity r1, and (3) a reflection in the second reflectivity r2, attenuating the internal multiplies from the seismic data d by subtraction, and generating an image of the subsurface indicative of geophysical features associated with oil or gas resources.
A method for removing multiples m from seismic data d associated with a subsurface, the method including receiving the seismic data d associated with the subsurface, forward propagating the seismic data d into the subsurface to form forward propagated data dΦ; receiving angular dependent reflectivities rθ, associated with an angular range Δθ, in the subsurface, for a given point; generating an angle dependent reflecting wavefield DΦθrθ based on the forward propagated data dΦ and the angular dependent reflectivities rθ; calculating a multiple model ΦDΦθrθ by forward propagating the angle dependent reflecting wavefield DΦθrθ to the receiver; attenuating multiplies m associated with the multiple model, from the seismic data d, by subtraction of the multiple model to calculate demultiple data dd; and generating an image of the subsurface.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
55.
Geothermal plant for extracting energy from a geothermal reservoir located below the ocean bottom
A geothermal plant, for extracting energy from a geothermal reservoir located below the ocean bottom, includes a floating platform; a riser that extends from a well drilled into the geothermal reservoir, to the floating platform; an electrical pump having a mechanical actuation part located in a bore of the riser, and an electronic part located outside the riser, wherein the electrical pump is configured to pump a geothermal liquid from the geothermal reservoir to the floating platform; and a power plant located on the floating platform and configured to use a steam produced by the geothermal liquid to generate electrical power. The electrical pump is placed at a depth of the riser where the geothermal liquid is in a single-phase.
F24T 10/20 - Geothermal collectors using underground water as working fluidGeothermal collectors using working fluid injected directly into the ground, e.g. using injection wells and recovery wells
A method for processing seismic data, the method including receiving seismic data acquired by at least one receiver over a water-covered subsurface formation; generating, based on the seismic data, a down-going wavefield; generating, based on the seismic data, a partial down-going wavefield with attenuated water-wave; estimating a subsurface reflectivity R using multi-dimensional deconvolution, which equates (1) a convolution of the down-going wavefield with the subsurface reflectivity R to (2) the partial down-going wavefield; and generating an image of the water-covered subsurface formation based on the subsurface reflectivity R.
A method for autopicking of bedding in a well includes receiving (500) image logs associated with the well, eliminating (502) tool marks from the image logs, performing (506) a grid search for (1) a vertical amplitude and (2) a horizontal shift of the bedding at plural sampling depths to obtain a predicted bedding, calculating (508) an azimuth and a dip of the predicted bedding, and generating an image of the predicted bedding, wherein the image includes structural features of the well.
G01V 3/18 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging
G01V 3/38 - Processing data, e.g. for analysis, for interpretation or for correction
58.
METHOD AND SYSTEM FOR IDENTIFYING GRAIN BOUNDARIES AND MINERALS IN A SAMPLE
A method for generating a training dataset (302) for determining grain boundaries and minerals in a thin section (320) of a rock sample, includes receiving (318) the thin section (320) of the rock sample, generating (324) optical images (306) of the thin section (320) with an optical tool, generating (322) mineral phase images (308) of the thin section (320) with an electron microscopy tool, computing (314) first and second pseudo-images (I1, I2) based on different features (310) extracted from the optical images (306), generating (316) the training dataset (302) based on (1) the optical images (306), (2) the mineral phase images (308), and (3) the pseudo- images (I1, I2), and training (317) a single deep neural network, DNN, (100/200) based on the training dataset (302) to simultaneously determine a mineral type and grain boundaries in the thin section of the rock sample.
G06V 10/14 - Optical characteristics of the device performing the acquisition or on the illumination arrangements
G06V 10/82 - Arrangements for image or video recognition or understanding using pattern recognition or machine learning using neural networks
G06V 10/774 - Generating sets of training patternsBootstrap methods, e.g. bagging or boosting
G06V 10/80 - Fusion, i.e. combining data from various sources at the sensor level, preprocessing level, feature extraction level or classification level
G06V 10/42 - Global feature extraction by analysis of the whole pattern, e.g. using frequency domain transformations or autocorrelation
G06V 10/143 - Sensing or illuminating at different wavelengths
G06V 10/26 - Segmentation of patterns in the image fieldCutting or merging of image elements to establish the pattern region, e.g. clustering-based techniquesDetection of occlusion
Seismic data is processed using a full-waveform inversion using a model with a pseudo-δ layer. The presence of the pseudo-δ layer in the model enables handing the difference at the water bottom between acoustically generated synthetic data and seismic data that corresponds to an elastic medium. The pseudo-δ layer may be less than 100 m thick and/or may be located directly underneath the water bottom. The pseudo-δ layer may have a negative value for S and a null value for ϵ (δ and ϵ being Thomsen's anisotropy parameters).
A method for calculating a cation exchange capacity, CEC, associated with a mineral sample includes receiving (900) a material sample (110), altering (902) the material sample (110) to become a mineral sample (112) that fits into an automated mineralogy and petrography system (120), analyzing (904) the mineral sample (112) with the automated mineralogy and petrography system (120) to generate a mineral map (210), selecting (906) only clays (220) from the mineral map (210), calculating (908) a total surface area (312) of the clays (220) in the mineral map (210), and calculating (916) the CEC value of the material sample (110) based on the total surface area (312) of the clays (220) of the mineral map (210) and for all minerals in the mineral map (210).
G01N 23/2251 - Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups , or by measuring secondary emission from the material using electron or ion microprobes using incident electron beams, e.g. scanning electron microscopy [SEM]
A method for seismic imaging of a subsurface using a full waveform inversion, FWI, includes the steps of obtaining an initial P-velocity model that describes how a seismic wave propagates through the subsurface, generating an S-velocity model based on the initial P-velocity model, generating an elastic synthetic dataset p based on the initial P-velocity model and the S-velocity model, receiving a recorded seismic dataset d of the subsurface, updating the P-velocity model based on a comparison between the synthetic dataset p and the recorded seismic dataset d, updating a reflectivity at various locations in the subsurface based on the updated P-velocity model, and generating an image of the subsurface based on the reflectivity.
Formation evaluation methods and apparatuses use a COMET technique to cross- calibrate the total porosity and effective porosity approaches using logging tool measurements. The COMET technique minimizes the difference between total water saturation value and effective water saturation value assuming that non-conductive pore volume calculated using total porosity and using effective porosity is the same.
G01V 3/34 - Transmitting data to recording or processing apparatusRecording data
G01N 24/08 - Investigating or analysing materials by the use of nuclear magnetic resonance, electron paramagnetic resonance or other spin effects by using nuclear magnetic resonance
63.
SYSTEM AND METHOD FOR PROBABILITY-BASED DETERMINATION OF STRATIGRAPHIC ANOMALIES IN A SUBSURFACE
A method for determining a stratigraphic anomaly in a subsurface of the earth includes receiving raw data x, assigning the rock samples to corresponding stratigraphic units of the subsurface, transforming the raw data x to a centred log-ratios clr(x) dataset, calculating p-values with a pairwise sum rank test between populations of the centred log-ratios clr(x) dataset, selecting a set of fingerprint elements from the elements of the rock samples, converting raw concentrations corresponding to the set of fingerprint elements to isometric log-ratios ilr data, determining a number of ilr sub-populations within each stratigraphic unit, applying mixture discriminant analysis to the isometric log-ratios ilr data, using the ilr sub-populations to calculate posterior probabilities of the rock samples, and identifying the stratigraphic anomaly based on the posterior probabilities.
G01N 23/223 - Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups , or by measuring secondary emission from the material by irradiating the sample with X-rays or gamma-rays and by measuring X-ray fluorescence
E21B 49/02 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil
64.
METHOD FOR PREPARATION, DETECTION, AND ANALYSIS OF SYNTHETIC POLYMERS USING AUTOMATED MINERALOGY SYSTEMS
A method for preparing a block (400) for chemical analysis includes providing (500) a substantially inorganic mounting medium (402); providing (502) a sample material (406) that includes plastic (410/412) and another material (404); mixing (504) the substantially inorganic mounting medium (402) with the sample material (406) to generate the block (400); and smoothing (510) a first surface of the block (400) to expose the plastic (410/412).
One method interpolates simulated seismic data of a coarse spatial sampling to a finer spatial sampling using a neural network. The neural network is previously trained using a set of simulated seismic data with the finer spatial sampling and a subset thereof with the coarse spatial sampling. The data is simulated using an image of the explored underground formation generated using real seismic data. The seismic dataset resulting from simulation and interpolation is used for denoising the seismic data acquired over the underground formation. Another method demigrates seismic data at a sparse density and then increases density by interpolating traces using a neural network.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
Seismic exploration methods and data processing apparatuses employ a deep neural network to remove seismic interference (SI) noise. Training data is generated by combining an SI model extracted using a conventional model from a subset of the seismic data, with SI free shots and simulated random noise. The trained DNN is used to process the entire seismic data thereby generating an image of subsurface formation for detecting presence and/or location of sought-after natural resources.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
G06F 30/27 - Design optimisation, verification or simulation using machine learning, e.g. artificial intelligence, neural networks, support vector machines [SVM] or training a model
67.
Seismic data recording and processing with different uncontaminated recording time lengths
A method for generating an image of a subsurface based on blended seismic data includes receiving the blended seismic data, which is recorded so that plural traces have uncontaminated parts with different uncontaminated recording time lengths, selecting plural subgroups (SG1, SG2) of traces so that each subgroup (SG1) includes only uncontaminated parts that have a same uncontaminated recording time length, processing the traces from each subgroup to generate processed traces, mapping the processed traces to a same sampling, combining the processed traces from the plural subgroups (SG1, SG2) to generate combined processed traces, and generating an image of a structure of the subsurface based on the combined processed traces.
Methods of seismic data processing employ neural networks and use a reflectivity image based on the acquired seismic data to generate output training datasets. The neural networks thus trained are used for generating production datasets, without ghosts, source effects, multiples and/or populating a predetermined set of bins in inline-crossline plane for a set of offset classes.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
A correlated sparse nodes and mini-streamers system for collecting seismic data includes plural nodes distributed on the ocean bottom, and a mini-streamer spread that includes plural mini-streamers. The plural nodes and the mini-streamer spread are configured to simultaneously collect seismic data from a surveyed subsurface, and wherein a length of the mini-streamers is equal to or less than three times an inline distance between adjacent nodes of the plural nodes.
A system for immersion cooling electronic components includes a cylindrical container having a circular cross section, a cooling element disposed in the cylindrical container and containing a first cooling fluid, and a volume of a second cooling fluid disposed in the cylindrical container and in contact with the cooling element for exchange of heat between the second cooling fluid and the first cooling fluid, the second cooling fluid comprising an immersion cooling fluid. A heat generating electronic component is disposed within the cylindrical container and at least partially immersed in the second cooling fluid for exchange of heat between the electronic component and the second cooling fluid, and a fluid circulating device is disposed in the second cooling fluid to direct a flow of the second cooling fluid through the electronic component and over the cooling element.
A system for cooling an electronic component includes a cylindrical container, a support, a heat exchanger, and one or more micropumps. The cylindrical container includes an internal volume that stores dielectric liquid. The internal volume is formed by an interior wall and a bottom of the cylindrical container. The support is positioned in the internal volume of the cylindrical container, and retains the electronic component within the dielectric liquid stored in the internal volume of the cylindrical container. The support also controls a flow of the dielectric liquid. The heat exchanger is positioned in the cylindrical container and circulates water from an external environment of the cylindrical container into and out of the internal volume of the cylindrical container. The one or more micropumps are integrally formed with and powered by the electronic component, and circulate the dielectric liquid through the electronic component.
Methods and seismic data processing apparatuses use a down-going annihilation operator to generate an image from seismic data acquired over a water-covered subsurface formation. The down-going annihilation operator is derived using a down-going wavefield and an estimated water-wave extracted from the seismic data. The down-going annihilation operator may be derived in plane-wave domain.
A geothermal plant (1600, 1700, 1800, 2000), for extracting energy from a geothermal reservoir (1230) located below the ocean bottom, includes a floating platform (1202); a riser (1240) that extends from a well (1208) drilled into the geothermal reservoir (1230), to the floating platform (1202); an electrical pump (1260) having a mechanical actuation part (1264) located in a bore of the riser (1240), and an electronic part (1266) located outside the riser, wherein the electrical pump (1260) is configured to pump a geothermal liquid (1226) from the geothermal reservoir (1230) to the floating platform (1202); and a power plant (1210) located on the floating platform (1202) and configured to use a steam (1222) produced by the geothermal liquid (1226) to generate electrical power. The electrical pump (1260) is placed at a depth of the riser (1240) where the geothermal liquid (1226) is in a single-phase.
F24T 10/20 - Geothermal collectors using underground water as working fluidGeothermal collectors using working fluid injected directly into the ground, e.g. using injection wells and recovery wells
Methods and devices according to various embodiments perform full-wave inversion jointly for datasets acquired at different times over the same underground formation using a time-lag cost function with target regularization terms. This approach improves the 4D signal within reservoirs and suppresses 4D noise outside.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
75.
Method and system using wave-equation for obtaining traveltime and amplitude used in Kirchhoff migration
Limitations in accuracy and computing power requirements impeding conventional Kirchhoff migration and reverse time migration are overcome by using the wave-equation Kirchhoff, WEK, technique with Kirchhoff migration. WEK technique includes forward-propagating a low-frequency wavefield from a shot location among pre-defined source locations, calculating an arrival traveltime of a maximum amplitude of the low-frequency wavefield, and applying Kirchhoff migration using the arrival traveltime and the maximum amplitude.
Computing device, computer instructions and method for processing input seismic data d. The method includes receiving the input seismic data d recorded in a first domain by seismic receivers that are towed in water, the input seismic data d including pressure data and/or and particle motion data; generating a model p in a second domain to describe the input data d; processing the model p to generate an output particle motion dataset; and generating an image of the surveyed subsurface based on the output particle motion dataset.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
A permutation that optimizes correspondence between the seismic data and the simulated data is computed using a graph space optimal transport formulation-based misfit. The seismic data or simulated data are transformed into auxiliary data by applying a portion of time shifts computed from the optimal permutation before updating the structural model of the explored underground formation. The full-waveform inversion minimization of the distance between auxiliary data and the seismic data or simulated data to which partial time shifts have not been applied, may be embedded in a Kantorovich-Rubinstein norm.
A DUnet engine produces a processed image of seismic data acquired over an underground formation. The DUnet engine includes: a contractive path that performs multilayer convolutions and contraction to extract a code from the seismic data input to the DUnet, an expansive path configured to perform multilayer convolutions and expansion of the code, using features provided by the contractive path through skip connections, and a model level that performs multilayer convolutions on outputs of the contractive path and expansive paths to produce the processed image and/or an image that is a difference between the processed image and the seismic data. A fraction of the seismic data may be selected for training the DUnet engine using an anchor method that automatically extends an initial seismic data subset, based on similarity measurements. A reweighting layer may further combine inputs received from layers of the DUnet model to preserve signal amplitude trend.
An exploration method starts from cuttings associated with sampling intervals and well data for a well in a subsurface formation. The cuttings are prepared and analyzed to extract textural and chemical/mineralogical data for plural fragments in each sample that is made of the cuttings in one sampling interval. The method then includes matching lithotypes of rock defined according to the textural and chemical/mineralogical data for each fragment with segments of the well data in the corresponding sampling interval to obtain correspondences between the lithotypes and depth ranges. The correspondences between the lithotypes and the depth ranges may be used as constraints for seismic data inversion.
G06K 9/62 - Methods or arrangements for recognition using electronic means
G01N 23/2251 - Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups , or by measuring secondary emission from the material using electron or ion microprobes using incident electron beams, e.g. scanning electron microscopy [SEM]
G01V 1/40 - SeismologySeismic or acoustic prospecting or detecting specially adapted for well-logging
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
A non-blended dataset related to a same surveyed area as a blended dataset is used to deblend the blended dataset. The non-blended dataset may be used to calculate a model dataset emulating the blended dataset, or may be transformed in a model domain and used to derive sparseness weights, model domain masking, scaling or shaping functions used to deblend the blended dataset.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
G01V 1/32 - Transforming one recording into another
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
81.
Characterizing fracture orientations in orthorhombic adjacent layers using the phase of azimuthal fourier coefficients
th Fourier coefficients' phases for different incidence angles may indicate that the fracture orientations in the orthorhombic adjacent layers are aligned, orthogonal, at 45°, that one of the layers is isotropic, etc.
Methods and apparatuses characterize fracture orientations in orthorhombic adjacent layer. Seismic data with azimuthal coverage enables calculating Fourier coefficients of reflectivity at an interface between the orthorhombic adjacent layers. The phases of 2nd and 4th FCs may be used to infer the fracture orientations in the orthorhombic adjacent layers. Analysis of 2nd and 4th Fourier coefficients' phases for different incidence angles may indicate that the fracture orientations in the orthorhombic adjacent layers are aligned, orthogonal, at 45 , that one of the layers is isotropic, etc.
Seismic exploration of an underground formation uses seismic excitations to probe the formation's properties such as reflectivity that can be imaged using reverse time migration. Using an equal area spherical binning at reflection points improves and simplifies RTM imaging together with adaptability to the data acquisition geometry, while overcoming drawbacks of conventional cylindrical binning.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
84.
Full waveform inversion method and apparatus using unsupervised machine learning
A quality control method and apparatus generate maps for cycle skipping analysis of velocity models that may be the input or the output of a full waveform inversion. A comparison of observed data and corresponding synthetic data generated using a candidate velocity model yields feature images of shots. The feature images are then grouped in clusters using unsupervised machine learning. Deviation of the feature images from an ideal non-cycle skipped image allows to measure the quality of the candidate velocity model.
G06F 30/27 - Design optimisation, verification or simulation using machine learning, e.g. artificial intelligence, neural networks, support vector machines [SVM] or training a model
Methods and apparatuses for seismic exploration of an underground structure obtain improved images by integrating partial match filtering in an FWI. Filtered (auxiliary) data replaces one of the observed data and the synthetic data in the FWI's objective function to avoid cycle skipping.
Methods and apparatuses for seismic data processing perform a least-squares reverse time migration method in which surface-attribute-independent coefficients for the surface attribute gathers are demigrated to reduce the computational cost.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
Computing device, computer instructions and method process input seismic data d recorded in a first domain by seismic receivers that travel in water, the input seismic data d including pressure and particle motion measurements, including up-going and down-going wave-fields. A model p is generated in a second domain by solving an inverse problem for the input seismic data d, wherein applying an L transform to the model p describes the input data d. An L′ transform, which is different from the L transform, is then applied to the model p to obtain an output seismic data in the first domain, the output seismic data having a characteristic imparted by the transform L′. The characteristic is related to pressure wave-fields and/or particle motion wave-fields interpolated at positions in-between the input seismic receivers. An image of the surveyed subsurface is generated based on the output seismic dataset.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
Methods and apparatuses for processing seismic data acquired with multicomponent sensors build an accurate S-wave velocity model of a surveyed underground formation using a full waveform inversion (FWI) approach. PS synthetic data is generated using approximative acoustic equations in anisotropic media with a P-wave model, a current S-wave velocity model and a reflectivity model as inputs. The current S-wave velocity model is updated using FWI to minimize an amplitude-discrepancy-mitigating cost function that alleviates the amplitude mismatch between the PS observed data and the PS synthetic data due to the use of the approximative acoustic equations.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
89.
Estimating permeability values from well logs using a depth blended model
Permeability values are estimated based on well logs using regression algorithms, such as gradient boosting and random forest. The training data is selected from well logs for which core-analysis-based permeability values are available. The estimated permeability values are used to plan hydrocarbon production. The well logs used to build the depth blended model may include total porosity, gamma ray, volume of calcite, density, resistivity, and neutron logs. Selecting the training data may include grouping the well logs according to regions expected to have similar characteristics, choosing a subset of the well logs corresponding to wells expected to provide stable models according to pre-determined criteria, and/or identifying training zones on the chosen well logs according to one or more rules. Validation and consistency checks may also be performed.
Property values inside an explored underground subsurface are determined using hybrid analytic and machine learning. A training dataset representing survey data acquired over the explored underground structure is used to obtain labels via an analytic inversion. A deep neural network model generated using the training dataset and the labels is used to predict property values corresponding to the survey data using the DNN model.
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.
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
G01N 15/08 - Investigating permeability, pore volume, or surface area of porous materials
G06V 10/764 - Arrangements for image or video recognition or understanding using pattern recognition or machine learning using classification, e.g. of video objects
G06V 10/82 - Arrangements for image or video recognition or understanding using pattern recognition or machine learning using neural networks
G06V 10/44 - Local feature extraction by analysis of parts of the pattern, e.g. by detecting edges, contours, loops, corners, strokes or intersectionsConnectivity analysis, e.g. of connected components
92.
Methods and devices performing adaptive quadratic Wasserstein full-waveform inversion
2-based full-wave inversion to transformed synthetic and seismic data. Data transformation ensures that the synthetic and seismic data are positive definite and have the same mass using an adaptive normalization. This approach yields superior results particularly when the underground structure includes salt bodies.
A method for de-blending seismic data associated with an interface located in a subsurface of the earth, includes receiving blended seismic data E generated by firing N source arrays according to a pre-determined sequence Seq; selecting N sub-datasets SDn from the blended seismic data E; interpolating each selected sub-dataset SDn to reference positions ref, where the blended seismic data E is expected to be recorded, to generate interpolated data k; de-blending, in a processor, the interpolated data k to generate de-blended data o; and generating an image of the interface of the subsurface based on the de-blended data o.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
G01V 1/37 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy specially adapted for seismic systems using continuous agitation of the ground
94.
AUTOMATICALLY DETECTING AND CORRECTING ANOMALIES IN LOG DATA
A geological exploration method starts by obtaining measurements and calculating properties along boreholes in an area of interest to generate log data including plural curves. Anomalies are detected along at least one curve of one of the boreholes. A machine learning regressor is trained using one or more curves without anomaly values of the one of the boreholes and/or of another similar borehole among the boreholes, to predict a synthetic curve corresponding to the at least one curve. The synthetic curve is then blended into the at least one curve.
A method for estimating breakdown pressure values along a wellbore starts from analyzing cuttings from locations along the wellbore to determine rock properties, including rock texture information associated with the locations. The anisotropic elastic and mechanical properties at the locations are calculated based on the rock properties and using at least one rock physics model. Rock weakness index values corresponding to the locations are then calculated based on the anisotropic elastic and mechanical properties and the rock texture information. The breakdown pressure values at the locations are estimated from the rock weakness index values.
Methods and systems for seismic data acquisition in a survey area use compressed sensing and take into consideration operational limitations. The operational limitations may be related to the equipment used for the survey, the topography of the surveyed area or limitations that otherwise optimize the survey path.
Methods for seismic exploration of an underground formation including at least one anisotropic layer perform a joint velocity-variation-with-azimuth, VVAz, and amplitude-variation-with-azimuth, AVAz, inversion using the azimuthal angle stacks to obtain a structural representation of the underground formation. The structural representation is used to generate scenarios for exploiting resources in at least one layer of the underground formation.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
98.
HIGH -PRODUCTIVITY SEISMIC DATA ACQUISITION USING CALENDAR- TIME -BASED SWEEP INITIATION
Methods and devices use improved FWI techniques for seismic exploration of subsurface formations including salt bodies using a travel-time cost function. In calculating the travel-time cost function, time-shifts may be weighted using cross-correlation coefficients of respective time-shifted recorded data and synthetic data generated based on current velocity model. The improved methods enhance the resulting image while avoiding cycle-skipping and issues related to amplitude difference between synthetic and recorded data.
A method for seismic exploration uses visco-acoustic FWI to model velocity and quality factor Q for an explored subsurface formation. The method employs frequency-dependent velocity to reduce cross-talk between Q and velocity and may be used for both isotropic and anisotropic media.
