A method includes receiving observed seismic data, determining an envelope or magnitude of the observed seismic data as a first observed value, generating a variable noise term based in part upon the first observed value, and utilizing the variable noise term to determine a likelihood function of a stochastic inversion operation. The method also includes utilizing the likelihood function to generate a posterior probability distribution in conjunction with the stochastic inversion operation and applying the posterior probability distribution to characterize a subsurface region of Earth.
A method includes receiving observed seismic data, determining an envelope or magnitude of the observed seismic data as a first observed value, generating a variable noise term based in part upon the first observed value, and utilizing the variable noise term to determine a likelihood function of a stochastic inversion operation. The method also includes utilizing the likelihood function to generate a posterior probability distribution in conjunction with the stochastic inversion operation and applying the posterior probability distribution to characterize a subsurface region of Earth.
G01V 1/28 - Traitement des données sismiques, p.ex. pour analyse, pour interprétation, pour correction
G01V 1/36 - Exécution de corrections statiques ou dynamiques sur des enregistrements, p.ex. correction de l'étalement; Etablissement d'une corrélation entre signaux sismiques; Elimination des effets produits par un excès d'énergie
3.
Method and Apparatus for Petrophysical Classification, Characterization, and Uncertainty Estimation
Techniques and systems to provide increases in accuracy of property determination of a formation. The techniques include receiving initial well log data, generating augmented well log data including the initial well log data and modeled well log data based on the initial well log data, modifying the augmented well log data to generate a training dataset, training a probabilistic classifier utilizing the training dataset, calculating a probability volume for each lithofluid class of a set of predetermined lithofluid classes utilizing the probabilistic classifier, outputting the probability volume for each lithofluid class of the set of predetermined lithofluid classes as a respective probability of an occurrence of a type of lithofluid class in a reservoir, calculating a posterior probability based on the probability volume for a first lithofluid class of the set of predetermined lithofluid classes, and outputting the posterior probability as a probability of a property of the reservoir.
G01V 99/00 - Matière non prévue dans les autres groupes de la présente sous-classe
E21B 49/00 - Test pour déterminer la nature des parois des trous de forage; Essais de couches; Procédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits
G01V 11/00 - Prospection ou détection par des méthodes combinant des techniques spécifiées dans les groupes
4.
METHOD AND APPARATUS FOR PETROPHYSICAL CLASSIFICATION, CHARACTERIZATION, AND UNCERTAINTY ESTIMATION
Techniques and systems to provide increases in accuracy of property determination of a formation. The techniques include receiving initial well log data, generating augmented well log data including the initial well log data and modeled well log data based on the initial well log data, modifying the augmented well log data to generate a training dataset, training a probabilistic classifier utilizing the training dataset, calculating a probability volume for each lithofluid class of a set of predetermined lithofluid classes utilizing the probabilistic classifier, outputting the probability volume for each lithofluid class of the set of predetermined lithofluid classes as a respective probability of an occurrence of a type of lithofluid class in a reservoir, calculating a posterior probability based on the probability volume for a first lithofluid class of the set of predetermined lithofluid classes, and outputting the posterior probability as a probability of a property of the reservoir.
A choke valve includes an inlet, an outlet, and a cage downstream of the inlet and upstream of the outlet. The cage includes a plurality of ports, and each port of the cage includes a converging-diverging profile.
E21B 34/02 - Aménagements des vannes pour les trous de forage ou pour les puits dans les têtes de puits
F16K 47/08 - Moyens incorporés aux soupapes pour absorber l'énergie d'un fluide pour diminuer la pression, l'organe régulateur étant distinct de l'élément de fermeture
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
6.
COMPOSITIONS AND METHODS FOR PRODUCING DIHYDROFURANS FROM KETO-SUGARS
Provided are compositions and methods for producing dihydrofurans by way of glycosyl hydrolases that can dehydrate 2-keto-3-deoxy-gluconate (KDG) to K4. Provided are also compositions and methods for further processing K4 to create HMFA (5-hydroxymethyl-2-furoic acid) and/or FDCA (2,5-furan dicarboxylic acid).
C12P 7/08 - Ethanol en tant que produit chimique et non en tant que boisson alcoolique préparé comme sous-produit, ou préparé à partir d'un substrat constitué par des déchets ou par des matières cellulosiques
C12P 7/38 - Produits contenant de la cyclopentanone ou de la cyclopentadione
C07D 307/42 - Atomes d'oxygène liés par des liaisons simples
C10L 1/18 - Composés organiques contenant de l'oxygène
C12N 1/21 - Bactéries; Leurs milieux de culture modifiés par l'introduction de matériel génétique étranger
A method of assessing the response of a reservoir rock to low salinity water includes obtaining a formation core sample of a reservoir rock from a reservoir. In addition, the method includes sequentially washing the formation core sample with a first series of solvents to form a first series of solvent extracts and an extracted formation core sample. Further, the method includes sequentially washing the extracted formation core sample with a second series of solvents to form a second series of solvent extracts and a cleaned formation core sample. The method also includes generating a series of mass spectra of the second series of solvent extracts. The relative abundance of the catecholamine-type structures (CTS) is determined using the series of mass spectra. Still further, the method includes subjecting the formation core sample to analysis by X-ray diffraction to generate a diffraction pattern. The relative abundance of kalonite is determined using the diffraction pattern. Moreover, the method includes assessing a response of the reservoir rock to low salinity water based on the percentage of kalonite and the relative abundance of CTS.
A method for modeling fluid flow within a subterranean formation includes (a) receiving a three-dimensional (3D) image of rock from the subterranean formation. In addition, the method includes (b) defining a chemical system for the subterranean formation, wherein the chemical system comprises a plurality of chemical reactions within the subterranean formation. Further, the method includes (c) determining a concentration change within the subterranean formation over time due to solute transport and the chemical reactions of the chemical system. Still further, the method includes (d) determining a change in pore space within the subterranean formation; and (e) determining an updated concentration within the subterranean formation as a result of the concentration change and the change in pore space.
Techniques to avoid a cycle skip in conjunction with a full waveform inversion are disclosed herein. A method includes selecting a first objective function of a full waveform inversion (FWI) from a set of objective functions, selecting a second objective function of the FWI from the set of objective functions, calculating a first misfit based upon the first objective function using modeled data with respect to observed data, calculating a first search direction based upon the first misfit between the modeled data and the observed data, calculating a second misfit based upon the second objective function using the modeled data with respect to the observed data, calculating a second search direction based upon the second misfit between the modeled data and the observed data, combining the first search direction with the second direction and computing an update to the modeled data based upon the first search direction and the second search direction combination.
A method for modeling fluid flow within a subterranean formation includes (a) receiving a three-dimensional (3D) image of rock from the subterranean formation. In addition, the method includes (b) defining a chemical system for the subterranean formation, wherein the chemical system comprises a plurality of chemical reactions within the subterranean formation. Further, the method includes (c) determining a concentration change within the subterranean formation over time due to solute transport and the chemical reactions of the chemical system. Still further, the method includes (d) determining a change in pore space within the subterranean formation; and (e) determining an updated concentration within the subterranean formation as a result of the concentration change and the change in pore space.
Techniques to avoid a cycle skip in conjunction with a full waveform inversion are disclosed herein. A method includes selecting a first objective function of a full waveform inversion (FWI) from a set of objective functions, selecting a second objective function of the FWI from the set of objective functions, calculating a first misfit based upon the first objective function using modeled data with respect to observed data, calculating a first search direction based upon the first misfit between the modeled data and the observed data, calculating a second misfit based upon the second objective function using the modeled data with respect to the observed data, calculating a second search direction based upon the second misfit between the modeled data and the observed data, combining the first search direction with the second direction and computing an update to the modeled data based upon the first search direction and the second search direction combination.
G01V 1/36 - Exécution de corrections statiques ou dynamiques sur des enregistrements, p.ex. correction de l'étalement; Etablissement d'une corrélation entre signaux sismiques; Elimination des effets produits par un excès d'énergie
G01V 1/28 - Traitement des données sismiques, p.ex. pour analyse, pour interprétation, pour correction
12.
GLUCONATE DEHYDRATASE ENZYMES AND RECOMBINANT CELLS
Abstract: Gluconate dehydratase enzymes and recombinant cells are provided, along with their use in the production of 2-ke-to-3-deoxy-D-gluconate (KDG).
A sand screen assembly for a subterranean wellbore includes a base pipe having a central axis and including a flow port extending radially therethrough. The sand screen assembly also includes a screen element disposed about the base pipe and radially spaced from the base pipe to define an annulus radially positioned between the screen element and the base pipe. In addition, the sand screen assembly includes a manifold formed about the based pipe. The flow port is in fluid communication with the manifold and axially overlaps with the manifold. Further, the sand screen assembly includes a phase change material disposed within the manifold. The phase change material is configured to melt at a temperature below a melting temperature of the base pipe and flow into the flow port.
E21B 36/00 - Aménagements pour le chauffage, le refroidissement, l'isolation, dans les trous de forage ou dans les puits, p.ex. pour être utilisés dans les zones de permagel
14.
SYSTEMS AND METHODS FOR WELLBORE LINER INSTALLATION UNDER MANAGED PRESSURE CONDITIONS
Casing installation assemblies for installing a casing within a borehole, as well as systems and methods related thereto are disclosed. In an embodiment, the casing installation assembly includes a tubular string, an isolation sub coupled to a downhole end of the tubular string, and a diverter sub coupled to and positioned downhole of the isolation sub. In addition, the casing installation assembly includes a landing string coupled to the diverter sub and configured to be coupled to the casing. The isolation sub includes a valve assembly that is configured to selectively prevent fluid communication between the tubular string and the diverter sub.
E21B 43/10 - Mise en place de tubages, filtres ou crépines dans les puits
E21B 21/08 - Commande ou surveillance de la pression ou de l'écoulement du fluide de forage, p.ex. remplissage automatique des trous de forage, commande automatique de la pression au fond
E21B 21/10 - Aménagements des vannes dans les systèmes de circulation des fluides de forage
Techniques to allow for increases in the accuracy of the determination of properties of a formation (e.g., a formation's fluid content, porosity, density, etc.) or seismic velocity, shear wave information, etc. The techniques include generating initial input data comprising based at least in part on initial seismic data, modeling the initial input data to generate synthetic seismic data based on different combinations of the initial input data, iteratively updating a value of each particle of a set of particles utilizing the synthetic seismic data to generate a final set of particles and outputting the final set of particles as a target distribution.
Techniques to allow for increases in the accuracy of the determination of properties of a formation (e.g., a formation's fluid content, porosity, density, etc.) or seismic velocity, shear wave information, etc. are disclosed herein. The techniques include generating initial input data comprising based at least in part on initial seismic data, modeling the initial input data to generate synthetic seismic data based on different combinations of the initial input data, iteratively updating a value of each particle of a set of particles utilizing the synthetic seismic data to generate a final set of particles and outputting the final set of particles as a target distribution.
Samples are collected from a first wellbore and a second wellbore. Genetic material is extracted from the samples and analyzed to determine microorganisms present in subsurface geological features through which the first wellbore and the second wellbore pass. Movement of microorganisms originating in subsurface geological features at the location of the first wellbore to subsurface geological features at the location of the second wellbore can indicate movement of a carbon-based gas between the first wellbore and the second wellbore.
C12Q 1/6888 - Produits d’acides nucléiques utilisés dans l’analyse d’acides nucléiques, p.ex. amorces ou sondes pour la détection ou l’identification d’organismes
C12Q 1/64 - Test géomicrobiologique, p.ex. pour la recherche du pétrole
A method is provided of preparing a compound of formula II:
A method is provided of preparing a compound of formula II:
A method is provided of preparing a compound of formula II:
where: R1 and R2 are independently selected from —CH2OR′, —CHO, —COOR′ and —H,
provided that R1 and R2 are not both —H; and
R′ is selected from —H and C1-6 hydrocarbyl groups,
from a compound of formula I:
A method is provided of preparing a compound of formula II:
where: R1 and R2 are independently selected from —CH2OR′, —CHO, —COOR′ and —H,
provided that R1 and R2 are not both —H; and
R′ is selected from —H and C1-6 hydrocarbyl groups,
from a compound of formula I:
A method is provided of preparing a compound of formula II:
where: R1 and R2 are independently selected from —CH2OR′, —CHO, —COOR′ and —H,
provided that R1 and R2 are not both —H; and
R′ is selected from —H and C1-6 hydrocarbyl groups,
from a compound of formula I:
the compounds of formulas I and II being optionally in the form of a salt. The method comprises dehydrating the compound of formula I at: a pH in the range of from 0 to 6 or 8 to 11.5; and a temperature in the range of from 10 to 80° C. The method is particularly useful for synthesizing substituted furans from compounds derived from sugars.
A method for planning a subject well includes receiving a well profile for the subject well, the well profile comprising a plurality of sets of attributes, each corresponding to one of a plurality of depths of the subject well; categorizing each of the sets of attributes as being in a first zone or in a second zone to generate a pivoted well profile, where the pivoted well profile includes a number of the sets of attributes in the first zone and a number of the sets of attributes in the second zone; comparing the pivoted well profile of the subject well to a library of well profiles; identifying, based on the comparison, an analog well from the library, where a difference between the analog well profile and the pivoted well profile is less than a threshold; and providing an indication of the identified analog well.
A method for planning a subject well includes receiving a well profile for the subject well, the well profile comprising a plurality of sets of attributes, each corresponding to one of a plurality of depths of the subject well; categorizing each of the sets of attributes as being in a first zone or in a second zone to generate a pivoted well profile, where the pivoted well profile includes a number of the sets of attributes in the first zone and a number of the sets of attributes in the second zone; comparing the pivoted well profile of the subject well to a library of well profiles; identifying, based on the comparison, an analog well from the library, where a difference between the analog well profile and the pivoted well profile is less than a threshold; and providing an indication of the identified analog well.
E21B 44/00 - Systèmes de commande automatique spécialement adaptés aux opérations de forage, c. à d. systèmes à fonctionnement autonome ayant pour rôle d'exécuter ou de modifier une opération de forage sans l'intervention d'un opérateur humain, p.ex. systèmes de ; Systèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
E21B 41/00 - Matériel ou accessoires non couverts par les groupes
21.
SEPARATION OF SEISMIC SOURCES BY JOINT INTERPOLATION AND DEBLENDING
Generally, seismic data may provide valuable information with regard to the description such as the location and/or change of hydrocarbon deposits within a subsurface region of the Earth. The present disclosure generally discusses techniques that may be used by a computing system to analyze a data set including weak-coherence signals (e.g., non-coherent blending noise). In particular, a computing system may detect portion of the weak-coherence signals of a gather due to the overlap of selected seismic source excitations and use a mask to isolate coherent signals and the other weak-coherence signals from the masked portion of weak-coherence signals. The coherent signals and other weak-coherence signals may be iteratively processed and used to predict values of the masked weak-coherence signals.
G01V 1/36 - Exécution de corrections statiques ou dynamiques sur des enregistrements, p.ex. correction de l'étalement; Etablissement d'une corrélation entre signaux sismiques; Elimination des effets produits par un excès d'énergie
G01V 1/00 - Séismologie; Prospection ou détection sismique ou acoustique
22.
Separation of Seismic Sources by Joint Interpolation and Deblending
Generally, seismic data may provide valuable information with regard to the description such as the location and/or change of hydrocarbon deposits within a subsurface region of the Earth. The present disclosure generally discusses techniques that may be used by a computing system to analyze a data set including weak-coherence signals (e.g., non-coherent blending noise). In particular, a computing system may detect portion of the weak-coherence signals of a gather due to the overlap of selected seismic source excitations and use a mask to isolate coherent signals and the other weak-coherence signals from the masked portion of weak-coherence signals. The coherent signals and other weak-coherence signals may be iteratively processed and used to predict values of the masked weak-coherence signals.
A method for generating a high-resolution pseudo-reflectivity image of a subsurface region includes receiving seismic data associated with a subsurface region and captured by one or more seismic receivers, constructing a velocity model of the subsurface region based on the received seismic data, performing a seismic migration of the received seismic data based on the constructed velocity model to obtain migrated seismic data, computing polarized normal vectors associated with one or more subsurface reflectors of the subsurface region based on the migrated seismic data, and generating a pseudo-reflectivity image of the subsurface region based on both the computed polarized normal vectors.
A method for generating a high-resolution pseudo-reflectivity image of a subsurface region includes receiving seismic data associated with a subsurface region and captured by one or more seismic receivers, constructing a velocity model of the subsurface region based on the received seismic data, performing a seismic migration of the received seismic data based on the constructed velocity model to obtain migrated seismic data, computing polarized normal vectors associated with one or more subsurface reflectors of the subsurface region based on the migrated seismic data, and generating a pseudo-reflectivity image of the subsurface region based on both the computed polarized normal vectors.
A method for generating a high-resolution pseudo-reflectivity image of a subsurface region includes receiving seismic data associated with a subsurface region and captured by one or more seismic receivers, constructing a velocity model of the subsurface region based on the received seismic data, performing a seismic migration of the received seismic data based on the constructed velocity model to obtain migrated seismic data, computing polarized normal vectors associated with one or more subsurface reflectors of the subsurface region based on the migrated seismic data, and generating a pseudo-reflectivity image of the subsurface region based on both the computed polarized normal vectors.
G01V 1/137 - Production d'énergie sismique en utilisant des fluides comme moyens d'entraînement hydrauliques, p.ex. en utilisant des fluides à haute pression dont les fluides s'échappent du générateur d'une manière pulsée, p.ex. pour produire des explosions
G01V 1/38 - Séismologie; Prospection ou détection sismique ou acoustique spécialement adaptées aux zones recouvertes d'eau
A method for a completion operation of a well includes performing, by a simulator, an initial simulation based on geological data and an input parameter, the initial simulation providing simulated net pressure values for the well; receiving an indication of an actual net pressure value in the well; adjusting, by an RL agent, the input parameter to the simulator based on a difference between the actual net pressure value and a corresponding simulated net pressure value; performing an updated simulation based on the geological data and the adjusted input parameter, the updated simulation providing updated simulated net pressure values; iteratively adjusting the input parameter to the simulator, with the corresponding simulated net pressure value being from the updated simulated net pressure values; and providing an indication of an event at the well based on the actual net pressure value and the corresponding simulated net pressure value.
A method for a completion operation of a well includes performing, by a simulator, an initial simulation based on geological data and an input parameter, the initial simulation providing simulated net pressure values for the well; receiving an indication of an actual net pressure value in the well; adjusting, by an RL agent, the input parameter to the simulator based on a difference between the actual net pressure value and a corresponding simulated net pressure value; performing an updated simulation based on the geological data and the adjusted input parameter, the updated simulation providing updated simulated net pressure values; iteratively adjusting the input parameter to the simulator, with the corresponding simulated net pressure value being from the updated simulated net pressure values; and providing an indication of an event at the well based on the actual net pressure value and the corresponding simulated net pressure value.
Techniques, systems and devices to generate a seismic wavefield solution. This includes receiving a velocity model corresponding to at least one attribute of seismic data, receiving source wavelet data corresponding to the seismic data, generating a guide image based upon at least one attribute of the velocity model, transmitting the velocity model, the source wavelet data, and the guide image to a machine learning system, and training the machine learning system into a trained machine learning system using the velocity model, the source wavelet data, and the guide image.
Techniques, systems and devices to generate a seismic wavefield solution. This includes receiving a velocity model corresponding to at least one attribute of seismic data, receiving source wavelet data corresponding to the seismic data, generating a guide image based upon at least one attribute of the velocity model, transmitting the velocity model, the source wavelet data, and the guide image to a machine learning system, and training the machine learning system into a trained machine learning system using the velocity model, the source wavelet data, and the guide image.
Techniques, systems and devices to generate a seismic wavefield solution. This includes receiving a velocity model corresponding to at least one attribute of seismic data, receiving source wavelet data corresponding to the seismic data, generating a guide image based upon at least one attribute of the velocity model, transmitting the velocity model, the source wavelet data, and the guide image to a machine learning system, and training the machine learning system into a trained machine learning system using the velocity model, the source wavelet data, and the guide image.
Methods include receiving a set of seismic data including a seismic signal generated over the course of a set period of time as a time scale, partitioning the seismic signal into a predetermined integer number greater than one of partitioned seismic signals each associated with a respective fixed position associated with a respective time interval as a portion of the time scale, applying a pulse compression technique to each partitioned seismic signal of the predetermined number of partitioned seismic signals to generate a compressed partitioned seismic signal corresponding to each partitioned seismic signal of the predetermined number of partitioned seismic signals, and inserting the compressed partitioned seismic signal corresponding to each partitioned seismic signal of the predetermined number of partitioned seismic signals in parallel into a velocity model builder. In addition, the methods include summing generated results therefrom to model the seismic signal for the time scale.
The present disclosure related generally to a process for removing chloride-containing organic compounds from renewable and bio-feedstocks. Accordingly, in one aspect, the present disclosure provides for a process for processing a liquid feed, the process comprising: providing a liquid feed that comprises one or more fatty acids and/or fatty acid esters, the liquid feed having a first chloride concentration by weight of chloride-containing organic compounds; and contacting the liquid feed with a solid treatment material to remove at least a fraction of the chloride-containing organic compounds to produce a treated liquid feed having a second chloride concentration that is less than the first chloride concentration, wherein the solid treatment material comprises an alkali metal or an alkaline earth metal in ionic form.
The present disclosure relates generally to processes for handling renewable hydrocarbon feeds and conventional hydrocarbon feeds. One aspect of the disclosure provides a process for co-processing a renewable feed and a petroleum feed, the process comprising: hydrotreating the petroleum feed in a first reaction zone, wherein the hydrotreating of the petroleum feed comprises one or more of hydrodesulfurization, hydrodenitrogenation, hydrodemetallization, isomerization, hydrogenation of olefins, and hydrocracking, to form a first reaction zone effluent; conducting the first reaction zone effluent to a second reaction zone; and in the second reaction zone hydrotreating a combination of the first reaction zone effluent and the renewable feed, wherein the hydrotreating of the combination comprises one or more of hydrodeoxygenation, decarboxylation, decarbonylation, isomerization and hydrogenation of olefins of the renewable feed, to form a second reaction zone effluent.
The present disclosure related generally to a process for removing chloride-containing organic compounds from renewable and bio-feedstocks. Accordingly, in one aspect, the present disclosure provides for a process for processing a liquid feed, the process comprising: providing a liquid feed that comprises one or more fatty acids and/or fatty acid esters, the liquid feed having a first chloride concentration by weight of chloride-containing organic compounds; and contacting the liquid feed with a solid treatment material to remove at least a fraction of the chloride-containing organic compounds to produce a treated liquid feed having a second chloride concentration that is less than the first chloride concentration, wherein the solid treatment material comprises an alkali metal or an alkaline earth metal in ionic form.
The present disclosure relates generally to processes for handling renewable hydrocarbon feeds and conventional hydrocarbon feeds. One aspect of the disclosure provides a process for co-processing a renewable feed and a petroleum feed, the process comprising: hydrotreating the petroleum feed in a first reaction zone, wherein the hydrotreating of the petroleum feed comprises one or more of hydrodesulfurization, hydrodenitrogenation, hydrodemetallization, isomerization, hydrogenation of olefins, and hydrocracking, to form a first reaction zone effluent; conducting the first reaction zone effluent to a second reaction zone; and in the second reaction zone hydrotreating a combination of the first reaction zone effluent and the renewable feed, wherein the hydrotreating of the combination comprises one or more of hydrodeoxygenation, decarboxylation, decarbonylation, isomerization and hydrogenation of olefins of the renewable feed, to form a second reaction zone effluent.
Seismic data may provide valuable information with regard to the description such as the location and/or change of hydrocarbon deposits within a subsurface region of the Earth. The present disclosure generally discusses techniques that may be used by a computing system to interpolate or deblend data utilizing a projection on convex sets (POCS) interpolation algorithm. The utilized POCS interpolation algorithm operates in parallel for frequency of a set of frequencies of a seismic frequency spectrum.
Techniques to reduce noise in seismic data by receiving a set of seismic data comprising a plurality of input volumes each inclusive of positional data and at least one additional attribute related to the seismic data, selecting a first input volume of the plurality of input volumes having a first additional attribute related to the seismic data, and generating a pilot volume by selecting a range of input volumes of the plurality of input volumes and stacking input volumes of the range of input volumes with the first input volume. Additionally, generating a trained dictionary based upon transformation of the pilot volume, transforming the first input volume into transformed data, imposing a sparse condition on the transformed data utilizing the trained dictionary to generate sparsified data, and inverse transforming the sparsified data to generate an output data volume as a portion of a set of modified seismic data.
G01V 1/36 - Exécution de corrections statiques ou dynamiques sur des enregistrements, p.ex. correction de l'étalement; Etablissement d'une corrélation entre signaux sismiques; Elimination des effets produits par un excès d'énergie
G01V 1/32 - Transformation d'un mode d'enregistrement en un autre
G01V 1/34 - Représentation des enregistrements sismiques
A synthetic molecule can be added to a sample at a specified concentration to accurately and/or precisely quantify target molecules included in the sample. The synthetic molecule can include a number of nucleotides. Some of the regions of the synthetic molecule can include sequences that correspond to primers used in an amplification process and other regions of the synthetic molecule can include sequences that are machine-generated. In implementations, an initial number of target molecules included in the sample can be determined based on a number of the target molecules included in an amplification product in relation to the number of synthetic molecules added to the sample.
C12Q 1/689 - Produits d’acides nucléiques utilisés dans l’analyse d’acides nucléiques, p.ex. amorces ou sondes pour la détection ou l’identification d’organismes pour les bactéries
39.
Noise Attenuation Methods Applied During Simultaneous Source Deblending and Separation
A device may include a processor that may separate or deblend signals acquired with simultaneous source shooting, in an environment with background noise or other types of noises. The processor may expand a receiver gather before the time of source excitation. The processor may use the expanded time window (e.g., negative time window) to allocate the background noise or other types of noises after removal. The processor may use signal recovery operations to reallocate leaked or misplaced signals created during the separation iterations, including the signals inside the expanded time window, to a correct source excitation and timing. Expanding a receiver gather time window and reallocating leaked or misplaced signals may improve a deblended output used in generating a seismic image.
G01V 1/36 - Exécution de corrections statiques ou dynamiques sur des enregistrements, p.ex. correction de l'étalement; Etablissement d'une corrélation entre signaux sismiques; Elimination des effets produits par un excès d'énergie
40.
METHOD AND APPARATUS FOR PERFORMING DE-ALIASING USING DEEP LEARNING
A method includes receiving modelled seismic data that is to be recognized by the at least one classification and/or segmentation processor. The modelled seismic data can be represented within a transform domain. The method includes generating an output via the at least one processor based on the received modelled seismic data. The method also includes comparing the output of the at least one processor with a desired output. The method also includes modifying the at least one processor so that the output of the processor corresponds to the desired output.
G01V 1/28 - Traitement des données sismiques, p.ex. pour analyse, pour interprétation, pour correction
G01V 1/36 - Exécution de corrections statiques ou dynamiques sur des enregistrements, p.ex. correction de l'étalement; Etablissement d'une corrélation entre signaux sismiques; Elimination des effets produits par un excès d'énergie
System and techniques to position a first source array at a fixed first inline distance from a vessel, position a second source array at a fixed second inline distance from a vessel, wherein the fixed second horizontal inline distance differs from the fixed first horizontal distance, generating a spatial coding, fire the first source array, and fire the second source array.
Estimation of velocity models inclusive of receiving seismic data inclusive of data that corresponds to a seismic image, adding a velocity perturbation to a current velocity model that represents a portion of the subsurface responsible for a distortion in the seismic image to generate a perturbed velocity model, generating an image via seismic migration of the seismic data and the perturbed velocity model, generating and assigning a measure of quality to the image, determining whether the measure of quality assigned to the image is an optimal measure of quality at a particular location of the current velocity model, and updating the current velocity model to generate a revised velocity model utilizing the measure of quality assigned to the image when the measure of quality assigned to the image is determined to be the optimal measure of quality at the particular location of the current velocity model.
BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
Inventeur(s)
Pacheco-Rodriguez, Jesus
Ellison, Joshua
Hickey, Greg
Ballard, Adam
Gonzalez, Martin, R.
Abrégé
A method for facilitating the management of one or more energy production or processing facilities includes receiving an alert corresponding to an operational anomaly associated with the process equipment, interrogating a data structure linking together and organizing a plurality of distinct data sources, selecting a subset of data sources from the plurality of data sources identified as associated with a potential cause of the alert based on the interrogation of the data structure, statistically analyzing data sourced from the selected subset of data sources, identifying the potential cause of the alert based on the statistical analysis, and recommending a corrective action to resolve the identified potential cause of the alert using the plurality of distinct data sources.
A method, and system to implement the process, of selecting a plurality of sets of source and receiver locations over a survey area, modeling on a subsurface attribute model of a subterranean region each source and receiver pair of the plurality of sets of source and receiver locations to generate low frequency seismic data, performing a reverse time migration on the low frequency seismic data to reposition diving wave energy of each source and receiver pair of the plurality of sets of source and receiver locations to generate a diving wave illumination image, extracting seismic amplitudes from the diving wave illumination image at a region of interest, and computing a contribution of a respective diving wave from each source and receiver pair of the plurality of sets of source and receiver locations to diving waves passing through the region of interest.
A method of determining cargo characteristics of a water-borne vessel includes obtaining a first Synthetic Aperture Radar (SAR) image of an area of interest, wherein the water-borne vessel is within the area of interest, and obtaining a second SAR image of the area of interest. In addition, the method includes generating an interferogram using the first SAR image and the second SAR image. Further, the method includes determining a height of the water-borne vessel above a surface of water using the interferogram. Still further, the method includes determining the cargo characteristics of the water-borne vessel based on the height.
G01S 13/90 - Radar ou systèmes analogues, spécialement adaptés pour des applications spécifiques pour la cartographie ou la représentation utilisant des techniques d'antenne synthétique
46.
DETERMINATION OF VESSEL CARGO CHARACTERISTICS USING INTERFEROMETRY
A method of determining cargo characteristics of a water-borne vessel includes obtaining a first Synthetic Aperture Radar (SAR) image of an area of interest, wherein the water-borne vessel is within the area of interest, and obtaining a second SAR image of the area of interest. In addition, the method includes generating an interferogram using the first SAR image and the second SAR image. Further, the method includes determining a height of the water-borne vessel above a surface of water using the interferogram. Still further, the method includes determining the cargo characteristics of the water-borne vessel based on the height.
G01S 13/90 - Radar ou systèmes analogues, spécialement adaptés pour des applications spécifiques pour la cartographie ou la représentation utilisant des techniques d'antenne synthétique
47.
METHODS AND COMPOSITIONS FOR LOW SALINITY ENHANCED OIL RECOVERY
A method of assessing the response of a reservoir rock to low salinity water includes obtaining a formation core sample of a reservoir rock from a reservoir. In addition, the method includes sequentially washing the formation core sample with a first series of solvents to form a first series of solvent extracts and an extracted formation core sample. Further, the method includes sequentially washing the extracted formation core sample with a second series of solvents to form a second series of solvent extracts and a cleaned formation core sample. The method also includes generating a series of mass spectra of the second series of solvent extracts. The relative abundance of the catecholamine-type structures (CTS) is determined using the series of mass spectra. Still further, the method includes subjecting the formation core sample to analysis by X-ray diffraction to generate a diffraction pattern. The relative abundance of kalonite is determined using the diffraction pattern. Moreover, the method includes assessing a response of the reservoir rock to low salinity water based on the percentage of kalonite and the relative abundance of CTS.
The Notice states that an abstract of the technical disclosure is required. In response, Applicant submits herewith a Preliminary Amendment including an abstract in compliance with 37 CFR § 1.72(b). The abstract is based on that submitted in parent U.S. application Ser. No. 15/556,084 (issued as U.S. Pat. No. 11,193,106) and international application no. PCT/US2016/020621, of which U.S. application Ser. No. 15/556,084 is the US national stage application. The submitted abstract differs from the abstract of the parent application only by a correction of “may further comprising” to “may further comprise”. Thus, the abstract contains no new matter.
C07D 307/56 - Composés hétérocycliques contenant des cycles à cinq chaînons comportant un atome d'oxygène comme unique hétéro-atome du cycle non condensés avec d'autres cycles comportant deux ou trois liaisons doubles entre chaînons cycliques ou entre chaînons cycliques et chaînons non cycliques avec des hétéro-atomes ou avec des atomes de carbone comportant trois liaisons à des hétéro-atomes, avec au plus une liaison à un halogène, p.ex. radicaux ester ou nitrile, liés directement aux atomes de carbone du cycle
C07H 19/01 - Composés contenant un hétérocycle partageant un hétéro-atome du cycle avec un radical saccharide; Nucléosides; Mononucléotides; Leurs anhydro-dérivés partageant un oxygène
C12N 9/24 - Hydrolases (3.) agissant sur les composés glycosyliques (3.2)
1-6 hydrocarbyl groups, from a compound of formula I: the compounds of formulas I and II being optionally in the form of a salt. The method comprises dehydrating the compound of formula I at: a pH in the range of from 0 to 6 or 8 to 11.5; and a temperature in the range of from 10 to 80° C. The method is particularly useful for synthesizing substituted furans from compounds derived from sugars.
Techniques to match a signature in seismic data with a seismic attribute space. A method includes automatically selecting a first plurality of seismic attributes corresponding to seismic data as first selected seismic attributes, combining the first selected seismic attributes into a first realization of attributes, performing a first cluster analysis on the first realization of attributes to generate a first clustered volume, selecting a region of interest (ROI) in the seismic data, projecting the ROI onto the first clustered volume to generate a first signature, determining a first level of correlation between the ROI and the first signature, and determining whether the first level of correlation between the ROI and the first signature exceeds a predetermined threshold and outputting a first correlation volume corresponding to the first signature when the first level of correlation between the ROI and the first signature exceeds the predetermined threshold.
Techniques to match a signature in seismic data with a seismic attribute space. A method includes automatically selecting a first plurality of seismic attributes corresponding to seismic data as first selected seismic attributes, combining the first selected seismic attributes into a first realization of attributes, performing a first cluster analysis on the first realization of attributes to generate a first clustered volume, selecting a region of interest (ROI) in the seismic data, projecting the ROI onto the first clustered volume to generate a first signature, determining a first level of correlation between the ROI and the first signature, and determining whether the first level of correlation between the ROI and the first signature exceeds a predetermined threshold and outputting a first correlation volume corresponding to the first signature when the first level of correlation between the ROI and the first signature exceeds the predetermined threshold.
Casing installation assemblies for installing a casing within a borehole, as well as systems and methods related thereto are disclosed. In an embodiment, the casing installation assembly includes a tubular string, an isolation sub coupled to a downhole end of the tubular string, and a diverter sub coupled to and positioned downhole of the isolation sub. In addition, the casing installation assembly includes a landing string coupled to the diverter sub and configured to be coupled to the casing. The isolation sub includes a valve assembly that is configured to selectively prevent fluid communication between the tubular string and the diverter sub.
E21B 43/10 - Mise en place de tubages, filtres ou crépines dans les puits
E21B 21/08 - Commande ou surveillance de la pression ou de l'écoulement du fluide de forage, p.ex. remplissage automatique des trous de forage, commande automatique de la pression au fond
53.
METHODS OF PERFORMING VELOCITY SURVEYS USING SPACED SOURCE ACTIVATION LINES
A method for performing a seismic survey of an earthen subterranean formation includes deploying a node patch including a plurality of seismic receivers to an offshore seabed in a survey area, deploying a surface vessel towing an array of seismic sources to the survey area located, and activating the array of seismic sources to generate seismic waves as the array of seismic sources are transported in an inline direction through the survey area whereby an imaging activation pattern and a velocity activation pattern are formed, wherein a lateral offset between the velocity activation pattern and the node patch is greater than a lateral offset between the imaging activation pattern and the node patch.
A method for performing a seismic survey of an earthen subterranean formation includes deploying a node patch including a plurality of seismic receivers to an offshore seabed in a survey area, deploying a surface vessel towing an array of seismic sources to the survey area located, and activating the array of seismic sources to generate seismic waves as the array of seismic sources are transported in an inline direction through the survey area whereby an imaging activation pattern and a velocity activation pattern are formed, wherein a lateral offset between the velocity activation pattern and the node patch is greater than a lateral offset between the imaging activation pattern and the node patch.
G01V 1/36 - Exécution de corrections statiques ou dynamiques sur des enregistrements, p.ex. correction de l'étalement; Etablissement d'une corrélation entre signaux sismiques; Elimination des effets produits par un excès d'énergie
G01V 1/28 - Traitement des données sismiques, p.ex. pour analyse, pour interprétation, pour correction
G01V 1/38 - Séismologie; Prospection ou détection sismique ou acoustique spécialement adaptées aux zones recouvertes d'eau
55.
METHODS OF PERFORMING VELOCITY SURVEYS USING SPACED SOURCE ACTIVATION LINES
A method for performing a seismic survey of an earthen subterranean formation includes deploying a node patch including a plurality of seismic receivers to an offshore seabed in a survey area, deploying a surface vessel towing an array of seismic sources to the survey area located, and activating the array of seismic sources to generate seismic waves as the array of seismic sources are transported in an inline direction through the survey area whereby an imaging activation pattern and a velocity activation pattern are formed, wherein a lateral offset between the velocity activation pattern and the node patch is greater than a lateral offset between the imaging activation pattern and the node patch.
There are provided methods, systems and processes for the utilization of microbial and related genetic information for use in the exploration, determination, production and recovery of natural resources, including energy sources, and the monitoring, control and analysis of processes and activities.
E21B 49/08 - Prélèvement d'échantillons de fluides ou test des fluides dans les trous de forage ou dans les puits
C12Q 1/6888 - Produits d’acides nucléiques utilisés dans l’analyse d’acides nucléiques, p.ex. amorces ou sondes pour la détection ou l’identification d’organismes
G16B 10/00 - TIC spécialement adaptées à la bio-informatique évolutive, p. ex. construction ou analyse d’arbre phylogénétique
G16B 20/00 - TIC spécialement adaptées à la génomique ou protéomique fonctionnelle, p. ex. corrélations génotype-phénotype
G16B 40/00 - TIC spécialement adaptées aux biostatistiques; TIC spécialement adaptées à l’apprentissage automatique ou à l’exploration de données liées à la bio-informatique, p.ex. extraction de connaissances ou détection de motifs
G16B 45/00 - TIC spécialement adaptées à la visualisation de données liées à la bio-informatique, p. ex. affichage de cartes ou de réseaux
E21B 43/00 - Procédés ou dispositifs pour l'extraction de pétrole, de gaz, d'eau ou de matériaux solubles ou fusibles ou d'une suspension de matières minérales à partir de puits
C09K 8/582 - Compositions pour les méthodes de récupération assistée pour l'extraction d'hydrocarbures, c. à d. pour améliorer la mobilité de l'huile, p.ex. fluides de déplacement caractérisées par l'utilisation de bactéries
C09K 8/62 - Compositions pour la formation de crevasses ou de fractures
E21B 47/11 - Localisation des fuites, intrusions ou mouvements du fluide utilisant la radioactivité
G16B 20/20 - Détection d’allèles ou de variantes, p. ex. détection de polymorphisme d’un seul nucléotide
C12Q 1/689 - Produits d’acides nucléiques utilisés dans l’analyse d’acides nucléiques, p.ex. amorces ou sondes pour la détection ou l’identification d’organismes pour les bactéries
E21B 49/00 - Test pour déterminer la nature des parois des trous de forage; Essais de couches; Procédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits
G01V 9/00 - Prospection ou détection par des procédés non prévus dans les groupes
C12Q 1/6874 - Méthodes de séquençage faisant intervenir des réseaux d’acides nucléiques, p.ex. séquençage par hybridation [SBH]
57.
SAND SCREEN ASSEMBLIES FOR A SUBTERRANEAN WELLBORE
A sand screen assembly for a subterranean wellbore includes a base pipe having a central axis and including a flow port extending radially therethrough. The sand screen assembly also includes a screen element disposed about the base pipe and radially spaced from the base pipe to define an annulus radially positioned between the screen element and the base pipe. In addition, the sand screen assembly includes a manifold formed about the based pipe. The flow port is in fluid communication with the manifold and axially overlaps with the manifold. Further, the sand screen assembly includes a phase change material disposed within the manifold. The phase change material is configured to melt at a temperature below a melting temperature of the base pipe and flow into the flow port.
E21B 36/00 - Aménagements pour le chauffage, le refroidissement, l'isolation, dans les trous de forage ou dans les puits, p.ex. pour être utilisés dans les zones de permagel
E21B 36/04 - Aménagements pour le chauffage, le refroidissement, l'isolation, dans les trous de forage ou dans les puits, p.ex. pour être utilisés dans les zones de permagel utilisant des réchauffeurs électriques
There are provided methods, systems and processes for the utilization of microbial and related genetic information for use in the exploration, determination, production and recovery of natural resources, including energy sources, and the monitoring, control and analysis of processes and activities.
E21B 49/08 - Prélèvement d'échantillons de fluides ou test des fluides dans les trous de forage ou dans les puits
C12Q 1/6888 - Produits d’acides nucléiques utilisés dans l’analyse d’acides nucléiques, p.ex. amorces ou sondes pour la détection ou l’identification d’organismes
G16B 10/00 - TIC spécialement adaptées à la bio-informatique évolutive, p. ex. construction ou analyse d’arbre phylogénétique
G16B 20/00 - TIC spécialement adaptées à la génomique ou protéomique fonctionnelle, p. ex. corrélations génotype-phénotype
G16B 40/00 - TIC spécialement adaptées aux biostatistiques; TIC spécialement adaptées à l’apprentissage automatique ou à l’exploration de données liées à la bio-informatique, p.ex. extraction de connaissances ou détection de motifs
G16B 45/00 - TIC spécialement adaptées à la visualisation de données liées à la bio-informatique, p. ex. affichage de cartes ou de réseaux
E21B 43/00 - Procédés ou dispositifs pour l'extraction de pétrole, de gaz, d'eau ou de matériaux solubles ou fusibles ou d'une suspension de matières minérales à partir de puits
C09K 8/582 - Compositions pour les méthodes de récupération assistée pour l'extraction d'hydrocarbures, c. à d. pour améliorer la mobilité de l'huile, p.ex. fluides de déplacement caractérisées par l'utilisation de bactéries
C09K 8/62 - Compositions pour la formation de crevasses ou de fractures
E21B 47/11 - Localisation des fuites, intrusions ou mouvements du fluide utilisant la radioactivité
G16B 20/20 - Détection d’allèles ou de variantes, p. ex. détection de polymorphisme d’un seul nucléotide
C12Q 1/689 - Produits d’acides nucléiques utilisés dans l’analyse d’acides nucléiques, p.ex. amorces ou sondes pour la détection ou l’identification d’organismes pour les bactéries
E21B 49/00 - Test pour déterminer la nature des parois des trous de forage; Essais de couches; Procédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits
G01V 9/00 - Prospection ou détection par des procédés non prévus dans les groupes
C12Q 1/6874 - Méthodes de séquençage faisant intervenir des réseaux d’acides nucléiques, p.ex. séquençage par hybridation [SBH]
A method for stimulating a well extending through a subterranean formation includes (a) introducing a first fracturing fluid into the subterranean formation, and (b) introducing a second fracturing fluid into the subterranean formation that is different in composition from the first fracturing fluid, wherein the second fracturing fluid comprises a temporary diverting agent.
There are provided methods, systems and processes for the utilization of microbial and related genetic information for use in industrial settings, such as the exploration, determination, and recovery of natural resources, minerals, and energy sources, the monitoring and analysis of processes, activities, and materials transmission.
C12Q 1/6888 - Produits d’acides nucléiques utilisés dans l’analyse d’acides nucléiques, p.ex. amorces ou sondes pour la détection ou l’identification d’organismes
G16B 10/00 - TIC spécialement adaptées à la bio-informatique évolutive, p. ex. construction ou analyse d’arbre phylogénétique
G16B 20/00 - TIC spécialement adaptées à la génomique ou protéomique fonctionnelle, p. ex. corrélations génotype-phénotype
C09K 8/582 - Compositions pour les méthodes de récupération assistée pour l'extraction d'hydrocarbures, c. à d. pour améliorer la mobilité de l'huile, p.ex. fluides de déplacement caractérisées par l'utilisation de bactéries
C12Q 1/689 - Produits d’acides nucléiques utilisés dans l’analyse d’acides nucléiques, p.ex. amorces ou sondes pour la détection ou l’identification d’organismes pour les bactéries
E21B 43/16 - Procédés de récupération assistée pour l'extraction d'hydrocarbures
E21B 47/11 - Localisation des fuites, intrusions ou mouvements du fluide utilisant la radioactivité
A method for analyzing a rock sample includes segmenting a digital image volume corresponding to an image of the rock sample, to associate voxels in the digital image volume with a plurality of rock fabrics of the rock sample. The method also includes performing image processing on the digital image volume to determine a material property of each of the rock fabrics and selecting, from a set of nomograms, a nomogram having an associated grid size. The selected nomogram associates the material property of each of the rock fabrics with a fractional bounceback parameter (FBP) value between a lower FBP threshold and an upper FBP threshold. The method further includes associating each voxel in the digital image volume with an FBP value based on the selected nomogram.
A method for analyzing a rock sample includes segmenting a digital image volume corresponding to an image of the rock sample, to associate voxels in the digital image volume with a plurality of rock fabrics of the rock sample. The method also includes identifying a set of digital planes through the digital image volume. The set of digital planes intersects with each of the plurality of rock fabrics. The method further includes machining the rock sample to expose physical faces that correspond to the identified digital planes, performing scanning electron microscope (SEM) imaging of the physical faces to generate two-dimensional (2D) SEM images of the physical faces, and performing image processing on the SEM images to determine a material property associated with each of the rock fabrics.
A method for analyzing a rock sample includes segmenting a digital image volume corresponding to an image of the rock sample, to associate voxels in the digital image volume with a plurality of rock fabrics of the rock sample. The method also includes identifying a set of digital planes through the digital image volume. The set of digital planes intersects with each of the plurality of rock fabrics. The method further includes machining the rock sample to expose physical faces that correspond to the identified digital planes, performing scanning electron microscope (SEM) imaging of the physical faces to generate two-dimensional (2D) SEM images of the physical faces, and performing image processing on the SEM images to determine a material property associated with each of the rock fabrics.
G01N 23/2251 - Recherche ou analyse des matériaux par l'utilisation de rayonnement [ondes ou particules], p.ex. rayons X ou neutrons, non couvertes par les groupes , ou en mesurant l'émission secondaire de matériaux en utilisant des microsondes électroniques ou ioniques en utilisant des faisceaux d’électrons incidents, p.ex. la microscopie électronique à balayage [SEM]
G06T 7/143 - Découpage; Détection de bords impliquant des approches probabilistes, p.ex. la modélisation à "champs aléatoires de Markov [MRF]"
A method for analyzing a rock sample includes segmenting a digital image volume corresponding to an image of the rock sample, to associate voxels in the digital image volume with a plurality of rock fabrics of the rock sample. The method also includes identifying a set of digital planes through the digital image volume. The set of digital planes intersects with each of the plurality of rock fabrics. The method further includes machining the rock sample to expose physical faces that correspond to the identified digital planes, performing scanning electron microscope (SEM) imaging of the physical faces to generate two-dimensional (2D) SEM images of the physical faces, and performing image processing on the SEM images to determine a material property associated with each of the rock fabrics.
G01N 23/2251 - Recherche ou analyse des matériaux par l'utilisation de rayonnement [ondes ou particules], p.ex. rayons X ou neutrons, non couvertes par les groupes , ou en mesurant l'émission secondaire de matériaux en utilisant des microsondes électroniques ou ioniques en utilisant des faisceaux d’électrons incidents, p.ex. la microscopie électronique à balayage [SEM]
A method for analyzing a rock sample includes segmenting a digital image volume corresponding to an image of the rock sample, to associate voxels in the digital image volume with a plurality of rock fabrics of the rock sample. The method also includes identifying a set of digital planes through the digital image volume. The set of digital planes intersects with each of the plurality of rock fabrics. The method further includes machining the rock sample to expose physical faces that correspond to the identified digital planes, performing scanning electron microscope (SEM) imaging of the physical faces to generate two-dimensional (2D) SEM images of the physical faces, and performing image processing on the SEM images to determine a material property associated with each of the rock fabrics.
A method for analyzing a rock sample includes performing scanning electron microscope (SEM) imaging of a plurality of physical faces of a rock sample to generate two-dimensional (2D) SEM images of the physical faces, applying a cross-correlation function to a first 2D SEM image and a second 2D SEM image to generate a three-dimensional (3D) digital model volume based on the first and second 2D SEM images, and determining a probability distribution of a pore size of the 3D digital model volume based on an image intensity value of a pixel in each of the first and second 2D SEM images.
A method for analyzing a rock sample includes segmenting a digital image volume corresponding to an image of the rock sample, to associate voxels in the digital image volume with a plurality of rock fabrics of the rock sample. The method also includes identifying a set of digital planes through the digital image volume. The set of digital planes intersects with each of the plurality of rock fabrics. The method further includes machining the rock sample to expose physical faces that correspond to the identified digital planes, performing scanning electron microscope (SEM) imaging of the physical faces to generate two-dimensional (2D) SEM images of the physical faces, and performing image processing on the SEM images to determine a material property associated with each of the rock fabrics.
G01N 23/2251 - Recherche ou analyse des matériaux par l'utilisation de rayonnement [ondes ou particules], p.ex. rayons X ou neutrons, non couvertes par les groupes , ou en mesurant l'émission secondaire de matériaux en utilisant des microsondes électroniques ou ioniques en utilisant des faisceaux d’électrons incidents, p.ex. la microscopie électronique à balayage [SEM]
G06T 7/143 - Découpage; Détection de bords impliquant des approches probabilistes, p.ex. la modélisation à "champs aléatoires de Markov [MRF]"
A method for analyzing a rock sample includes segmenting a digital image volume corresponding to an image of the rock sample, to associate voxels in the digital image volume with a plurality of rock fabrics of the rock sample. The method also includes performing image processing on the digital image volume to determine a material property of each of the rock fabrics and selecting, from a set of nomograms, a nomogram having an associated grid size. The selected nomogram associates the material property of each of the rock fabrics with a fractional bounceback parameter (FBP) value between a lower FBP threshold and an upper FBP threshold. The method further includes associating each voxel in the digital image volume with an FBP value based on the selected nomogram.
A method for analyzing a rock sample includes performing scanning electron microscope (SEM) imaging of a plurality of physical faces of a rock sample to generate two-dimensional (2D) SEM images of the physical faces, applying a cross-correlation function to a first 2D SEM image and a second 2D SEM image to generate a three-dimensional (3D) digital model volume based on the first and second 2D SEM images, and determining a probability distribution of a pore size of the 3D digital model volume based on an image intensity value of a pixel in each of the first and second 2D SEM images.
The system includes a washpipe (20), a screen (32), and a circulation sub (100) coupled to the washpipe. The circulation sub includes a central axis (115) and also includes an expansion switch (110) comprising an inner tubular member (112), an outer tubular member (114), and a switch (111) disposed between the inner tubular member and the outer tubular member. In addition, the circulation sub (100) includes a logging tool carrier (120) supporting a logging tool (150) therein. An axial expansion of the inner tubular member and the outer tubular member is configured to actuate the switch, and compression of the switch is configured to activate the logging tool.
E21B 23/00 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage
E21B 34/14 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par le mouvement des outils, p.ex. obturateurs à manchons actionnés par des pistons ou par des outils à câble
E21B 23/03 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage pour mettre en place des outils sur les supports ou dans les retraits ou poches excentrées ou pour les en retirer
71.
System and method for drilling rig state determination
A method for drilling a borehole in a subsurface formation includes receiving measured values indicative of operations performed by drilling equipment while drilling. The measured values include hookload values. The hookload values are analyzed to identify hookload values acquired while connecting a drill pipe, and a block weight value is set based on such a hookload value. The block weight value is subtracted from the hookload values to produce rebased hookload values. A rig state model produces a value for a state of the drilling equipment based on the measured values and the rebased hookload values. Responsive to the state of the drilling equipment, an operation performed to drill the subsurface formation is changed.
E21B 44/00 - Systèmes de commande automatique spécialement adaptés aux opérations de forage, c. à d. systèmes à fonctionnement autonome ayant pour rôle d'exécuter ou de modifier une opération de forage sans l'intervention d'un opérateur humain, p.ex. systèmes de ; Systèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
72.
METHOD AND APPARATUS FOR PERFORMING EFFICIENT MODELING OF EXTENDED-DURATION MOVING SEISMIC SOURCES
Methods include receiving a set of seismic data including a seismic signal generated over the course of a set period of time as a time scale, partitioning the seismic signal into a predetermined integer number greater than one of partitioned seismic signals each associated with a respective fixed position associated with a respective time interval as a portion of the time scale, applying a pulse compression technique to each partitioned seismic signal of the predetermined number of partitioned seismic signals to generate a compressed partitioned seismic signal corresponding to each partitioned seismic signal of the predetermined, number of partitioned seismic signals, and inserting the compressed partitioned seismic signal corresponding to each partitioned seismic signal of the predetermined number of partitioned seismic signals in parallel into a velocity model builder. In addition, the methods include summing generated results therefrom to model the seismic signal for the time scale.
A recombinant filamentous fungi that includes reduced 2-Keto-3-Deoxy-Gluconate (KDG) aldolase enzyme activity as compared to the filamentous fungi not transformed to have reduced KDG aldolase enzyme activity is provided. Also provided is a method of producing KDG.
A system for monitoring a condition of a component of a well system located proximate to a seabed includes a first sensor assembly to couple to a telescopic joint coupled to an upper end of a riser, wherein the first sensor assembly is configured to measure at least one of a vibration, an inclination, and a strain in the riser, and a data processing system in signal communication with the first sensor assembly, wherein the data processing system is configured to estimate the condition of a subsea stack system based on measurements provided by the first sensor assembly.
E21B 47/007 - Mesure des contraintes dans le cuvelage ou la tige de forage
E21B 47/001 - Relevés dans les trous de forage ou dans les puits pour des installations sous-marines
E21B 47/13 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage par énergie électromagnétique, p.ex. gammes de fréquence radio
E21B 17/01 - Colonnes montantes pour têtes de puits immergées
E21B 17/07 - Joints télescopiques permettant de faire varier les longueurs de trains de tiges; Amortisseurs
E21B 19/00 - Manipulation de tiges, tubages, tubes ou autre objets analogues à l'extérieur du trou de forage, p.ex. dans la tour de forage; Appareils pour faire avancer les tiges ou les câbles
G01M 5/00 - Examen de l'élasticité des structures ou ouvrages, p.ex. fléchissement de ponts ou d'ailes d'avions
75.
Tools for selecting and sequencing operating parameter changes to control a hydrocarbon production system
BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
Inventeur(s)
Dumenil, Jean-Charles
Heddle, Richard
Wang, Shaojun
Abrégé
A process for use in managing a hydrocarbon production system includes: selecting, from among a plurality of changes proposed to operating parameters of the hydrocarbon production system, the proposed change with the greatest estimated positive change in production; assessing whether the selected change violates an operating constraint; based on said assessment, producing a valid change based on at least the selected change or identifying the selected change as an unusable change, iterating the above steps, the iteration excluding the valid change from the plurality of proposed changes; and implementing at least one valid change, the number of implemented valid changes being less than the number of proposed changes.
Seismic data may provide valuable information with regard to the description such as the location and/or change of hydrocarbon deposits within a subsurface region of the Earth. The present disclosure generally discusses techniques that may be used by a computing system to interpolate or deblend data utilizing a projection on convex sets (POCS) interpolation algorithm. The utilized POCS interpolation algorithm operates in parallel for frequency of a set of frequencies of a seismic frequency spectrum.
G01V 1/36 - Exécution de corrections statiques ou dynamiques sur des enregistrements, p.ex. correction de l'étalement; Etablissement d'une corrélation entre signaux sismiques; Elimination des effets produits par un excès d'énergie
77.
NON-LINEAR SOLUTION TO SEISMIC DATA CONDITIONING USING TRAINED DICTIONARIES
Techniques to reduce noise in seismic data by receiving a set of seismic data comprising a plurality of input volumes each inclusive of positional data and at least one additional attribute related to the seismic data, selecting a first input volume of the plurality of input volumes having a first additional attribute related to the seismic data, and generating a pilot volume by selecting a range of input volumes of the plurality of input volumes and stacking input volumes of the range of input volumes with the first input volume. Additionally, generating a trained dictionary based upon transformation of the pilot volume, transforming the first input volume into transformed data, imposing a sparse condition on the transformed data utilizing the trained dictionary to generate sparsified data, and inverse transforming the sparsified data to generate an output data volume as a portion of a set of modified seismic data.
G01V 1/36 - Exécution de corrections statiques ou dynamiques sur des enregistrements, p.ex. correction de l'étalement; Etablissement d'une corrélation entre signaux sismiques; Elimination des effets produits par un excès d'énergie
G01V 1/32 - Transformation d'un mode d'enregistrement en un autre
78.
Seismic data filtering based on distances between seismic sources
Techniques for processing of seismic data. A seismic data set is received, wherein the seismic data set comprises a first data subset associated with a first seismic source and a second data subset associated with a second seismic source. An input is received indicating that a distance between the first seismic source and the second seismic source is greater than or equal to a threshold value. The second data set is filtered from the seismic data set to remove the second data subset from seismic data set to generate a filtered seismic data set in response to receiving the input and a coherence volume is generated based on the filtered seismic data set.
G01V 1/36 - Exécution de corrections statiques ou dynamiques sur des enregistrements, p.ex. correction de l'étalement; Etablissement d'une corrélation entre signaux sismiques; Elimination des effets produits par un excès d'énergie
G01V 1/38 - Séismologie; Prospection ou détection sismique ou acoustique spécialement adaptées aux zones recouvertes d'eau
G01V 1/34 - Représentation des enregistrements sismiques
The present disclosure relates generally to solid/liquid separation processes. One aspect of the disclosure is a process including filtering a solid/liquid mixture comprising a solid crude aromatic carboxylic acid, a monocarboxylic acid solvent, and minor amounts of an oxidation catalyst in a feed zone of a rotary filter (e.g., a rotary pressure filter), the feed zone having at least two filter zones to form a first feed filtrate comprising monocarboxylic acid solvent and solids; and a second feed filtrate separate from the first feed filtrate, the second feed filtrate comprising monocarboxylic acid solvent and solids, the second feed filtrate being lower in solids than the first feed filtrate; and transferring at least a portion of the first feed filtrate to the reactor zone as recycle.
C07C 51/265 - Préparation d'acides carboxyliques, de leurs sels, halogénures ou anhydrides par oxydation avec l'oxygène moléculaire de composés contenant des cycles aromatiques à six chaînons sans ouverture du cycle comportant des chaînes latérales alkylées qui sont oxydées en groupes carboxyle
C07C 51/43 - Séparation; Purification; Stabilisation; Emploi d'additifs par changement de l'état physique, p.ex. par cristallisation
A method includes receiving, via a processor, input data based upon received seismic data, migrating, via the processor, the input data via a pre-stack depth migration technique to generate migrated input data, encoding, via the processor, the input data via an encoding function as a migration attribute to generate encoded input data having a migration function that is non-monotonic versus an attribute related to the input data, migrating, via the processor, the encoded input data via the pre-stack depth migration technique to generate migrated encoded input data, and generating an estimated common image gather based upon the migrated input data and the migrated encoded input data. The method also includes generating a seismic image utilizing the estimated common image gather, wherein the seismic image represents hydrocarbons in a subsurface region of the Earth or subsurface drilling hazards.
G01V 1/34 - Représentation des enregistrements sismiques
G01V 1/137 - Production d'énergie sismique en utilisant des fluides comme moyens d'entraînement hydrauliques, p.ex. en utilisant des fluides à haute pression dont les fluides s'échappent du générateur d'une manière pulsée, p.ex. pour produire des explosions
A method includes receiving, via a processor, input data based upon received seismic data, migrating, via the processor, the input data via a pre-stack depth migration technique to generate migrated input data, encoding, via the processor, the input data via an encoding function as a migration attribute to generate encoded input data having a migration function that is non-monotonic versus an attribute related to the input data, migrating, via the processor, the encoded input data via the pre-stack depth migration technique to generate migrated encoded input data, and generating an estimated common image gather based upon the migrated input data and the migrated encoded input data. The method also includes generating a seismic image utilizing the estimated common image gather, wherein the seismic image represents hydrocarbons in a subsurface region of the Earth or subsurface drilling hazards.
A system for stimulating a well extending through a subterranean earthen formation includes a surface pump configured to pressurize a well stimulation fluid to a current surface pressure measurable by a surface sensor package, a well stimulation line extending between the surface pump and a wellhead positioned at an upper end of the well, wherein the well stimulation line is configured to flow the well stimulation fluid into the well, and a monitoring system in signal communication with the surface sensor package and including a screen-out predictor module stored in a memory of the monitoring system, wherein the screen-out predictor module is configured to predict a future surface pressure of the well stimulation fluid based on the current surface pressure measured by the surface sensor package, and wherein the monitoring system is configured to provide an indication of the predicted future surface pressure of the well stimulation fluid.
A system for stimulating a well extending through a subterranean earthen formation includes a surface pump configured to pressurize a well stimulation fluid to a current surface pressure measurable by a surface sensor package, a well stimulation line extending between the surface pump and a wellhead positioned at an upper end of the well, wherein the well stimulation line is configured to flow the well stimulation fluid into the well, and a monitoring system in signal communication with the surface sensor package and including a screen-out predictor module stored in a memory of the monitoring system, wherein the screen-out predictor module is configured to predict a future surface pressure of the well stimulation fluid based on the current surface pressure measured by the surface sensor package, and wherein the monitoring system is configured to provide an indication of the predicted future surface pressure of the well stimulation fluid.
E21B 47/06 - Mesure de la température ou de la pression
E21B 47/12 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage
G06K 9/62 - Méthodes ou dispositions pour la reconnaissance utilisant des moyens électroniques
A device may include a processor that may separate or deblend signals acquired with simultaneous source shooting, in an environment with background noise or other types of noises. The processor may expand a receiver gather before the time of source excitation. The processor may use the expanded time window (e.g., negative time window) to allocate the background noise or other types of noises after removal. The processor may use signal recovery operations to reallocate leaked or misplaced signals created during the separation iterations, including the signals inside the expanded time window, to a correct source excitation and timing. Expanding a receiver gather time window and reallocating leaked or misplaced signals may improve a deblended output used in generating a seismic image.
G01V 1/36 - Exécution de corrections statiques ou dynamiques sur des enregistrements, p.ex. correction de l'étalement; Etablissement d'une corrélation entre signaux sismiques; Elimination des effets produits par un excès d'énergie
System and techniques to position a first source array at a fixed first inline distance from a vessel, position a second source array at a fixed second inline distance from a vessel, wherein the fixed second inline distance differs from the fixed first inline distance, generating a spatial coding, fire the first source array, and fire the second source array.
System and techniques to position a first source array at a fixed first inline distance from a vessel, position a second source array at a fixed second inline distance from a vessel, wherein the fixed second inline distance differs from the fixed first inline distance, generating a spatial coding, fire the first source array, and fire the second source array.
BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
BP CORPORATION NORTH AMERICA INC. (USA)
Inventeur(s)
Thiruvenkatanathan, Pradyumna
Cao, Fei
Abrégé
A method of characterizing an inflow into a wellbore comprises obtaining an acoustic signal from a sensor within the wellbore, determining a plurality of frequency domain features from the acoustic signal, identifying at least one of a gas phase flow, an aqueous phase flow, or a hydrocarbon liquid phase flow using the plurality of the frequency domain features, and classifying a flow rate of the at least one of the gas phase flow, the aqueous phase flow, or the hydrocarbon liquid phase flow using the plurality of frequency domain features. The acoustic signal comprises acoustic samples across a portion of a depth of the wellbore.
G01F 1/66 - Mesure du débit volumétrique ou du débit massique d'un fluide ou d'un matériau solide fluent, dans laquelle le fluide passe à travers un compteur par un écoulement continu en mesurant la fréquence, le déphasage, le temps de propagation d'ondes électromagnétiques ou d'autres types d'ondes, p.ex. en utilisant des débitmètres à ultrasons
G01H 9/00 - Mesure des vibrations mécaniques ou des ondes ultrasonores, sonores ou infrasonores en utilisant des moyens sensibles aux radiations, p.ex. des moyens optiques
G01P 5/24 - Mesure de la vitesse des fluides, p.ex. d'un courant atmosphérique; Mesure de la vitesse de corps, p.ex. navires, aéronefs, par rapport à des fluides en mesurant l'influence directe du courant de fluide sur les propriétés d'une onde acoustique de détection
Estimation of velocity models inclusive of receiving seismic data inclusive of data that corresponds to a seismic image, adding a velocity perturbation to a current velocity model that represents a portion of the subsurface responsible for a distortion in the seismic image to generate a perturbed velocity model, generating an image via seismic migration of the seismic data and the perturbed velocity model, generating and assigning a measure of quality to the image, determining whether the measure of quality assigned to the image is an optimal measure of quality at a particular location of the current velocity model, and updating the current velocity model to generate a revised velocity model utilizing the measure of quality assigned to the image when the measure of quality assigned to the image is determined to be the optimal measure of quality at the particular location of the current velocity model.
G01V 1/36 - Exécution de corrections statiques ou dynamiques sur des enregistrements, p.ex. correction de l'étalement; Etablissement d'une corrélation entre signaux sismiques; Elimination des effets produits par un excès d'énergie
A hot tap assembly for accessing a subsea fluid system includes a landing structure configured to releasably attach to a subsea fluid conduit of the subsea fluid system, a clamp assembly positionable on the landing structure, where in the clamp assembly includes a hot tap clamp including a first jaw and a second jaw, wherein a first annular seal assembly and a second annular seal assembly are disposed on an engagement surface of the second jaw, and a drill assembly positionable on the landing structure, wherein the drill assembly includes a drill disposed in a central conduit that is insertable through a central passage formed in the second jaw of the clamp assembly, wherein the hot tap clamp is configured to actuate between an open position configured to receive the subsea fluid conduit and a closed position configured to sealingly engage the subsea fluid conduit with the first seal assembly and the second seal assembly of the clamp assembly.
F16L 41/06 - Installation de prises de branchement sur les parois de tuyaux, c. à d. établissement de dérivations sur tuyaux pendant qu'ils transportent des fluides; Accessoires à cet effet utilisant des moyens de fixation qui embrassent le tuyau
F16L 1/26 - Réparation ou assemblage des tuyaux sur ou sous l'eau
E21B 37/00 - Procédés ou appareils pour nettoyer les trous de forage ou les puits
90.
Systems and methods for identifying blockages in subsea conduits
A system for remediating a blockage in a subsea a subsea fluid system includes a hot tap system connected to an outer surface of a subsea fluid conduit of the subsea fluid system, a first flowpath extending from a fluid source, through the first coiled tubing and the hot tap system, and into the subsea fluid conduit, and a second flowpath extending from the subsea fluid conduit and through the hot tap system, wherein the second flowpath is separate from the first flowpath, wherein the hot tap system is configured to inject a first fluid into the subsea fluid conduit along the first flowpath and receive a second fluid from the subsea fluid conduit along the second flowpath.
B08B 9/032 - Nettoyage de conduites ou de tubes ou des systèmes de conduites ou de tubes Élimination des bouchons par l'action mécanique d'un fluide en mouvement, p.ex. par effet de chasse d'eau
E21B 41/00 - Matériel ou accessoires non couverts par les groupes
E21B 41/04 - Manipulateurs pour opérations sous l'eau, p.ex. reliés temporairement aux têtes de puits
A hot tap assembly for accessing a subsea fluid system includes a landing structure configured to releasably attach to a subsea fluid conduit of the subsea fluid system, a clamp assembly positionable on the landing structure, where in the clamp assembly includes a hot tap clamp including a first jaw and a second jaw, wherein a first annular seal assembly and a second annular seal assembly are disposed on an engagement surface of the second jaw, and a drill assembly positionable on the landing structure, wherein the drill assembly includes a drill disposed in a central conduit that is insertable through a central passage formed in the second jaw of the clamp assembly, wherein the hot tap clamp is configured to actuate between an open position configured to receive the subsea fluid conduit and a closed position configured to sealingly engage the subsea fluid conduit with the first seal assembly and the second seal assembly of the clamp assembly.
F16L 1/26 - Réparation ou assemblage des tuyaux sur ou sous l'eau
F16L 41/04 - Installation de prises de branchement sur les parois de tuyaux, c. à d. établissement de dérivations sur tuyaux pendant qu'ils transportent des fluides; Accessoires à cet effet
F16L 41/06 - Installation de prises de branchement sur les parois de tuyaux, c. à d. établissement de dérivations sur tuyaux pendant qu'ils transportent des fluides; Accessoires à cet effet utilisant des moyens de fixation qui embrassent le tuyau
12121-61-6 hydrocarbyl groups, from a compound of formula I: the compounds of formulas I and II being optionally in the form of a salt. The method comprises dehydrating the compound of formula I at: a pH in the range of from 0 to 6 or 8 to 11.5; and a temperature in the range of from 10 to 80 °C. The method is particularly useful for synthesizing substituted furans from compounds derived from sugars.
A system for remediating a blockage in a subsea a subsea fluid system includes a hot tap system connected to an outer surface of a subsea fluid conduit of the subsea fluid system, a first flowpath extending from a fluid source, through the first coiled tubing and the hot tap system, and into the subsea fluid conduit, and a second flowpath extending from the subsea fluid conduit and through the hot tap system, wherein the second flowpath is separate from the first flowpath, wherein the hot tap system is configured to inject a first fluid into the subsea fluid conduit along the first flowpath and receive a second fluid from the subsea fluid conduit along the second flowpath.
F16L 1/26 - Réparation ou assemblage des tuyaux sur ou sous l'eau
F16L 41/04 - Installation de prises de branchement sur les parois de tuyaux, c. à d. établissement de dérivations sur tuyaux pendant qu'ils transportent des fluides; Accessoires à cet effet
F16L 41/06 - Installation de prises de branchement sur les parois de tuyaux, c. à d. établissement de dérivations sur tuyaux pendant qu'ils transportent des fluides; Accessoires à cet effet utilisant des moyens de fixation qui embrassent le tuyau
94.
Microbiome based systems, apparatus and methods for the exploration and production of hydrocarbons
There are provided methods, systems and processes for the utilization of microbial and related genetic information for use in the exploration, determination, production and recovery of natural resources, including energy sources, and the monitoring, control and analysis of processes and activities.
E21B 49/08 - Prélèvement d'échantillons de fluides ou test des fluides dans les trous de forage ou dans les puits
C12Q 1/6888 - Produits d’acides nucléiques utilisés dans l’analyse d’acides nucléiques, p.ex. amorces ou sondes pour la détection ou l’identification d’organismes
G16B 10/00 - TIC spécialement adaptées à la bio-informatique évolutive, p. ex. construction ou analyse d’arbre phylogénétique
G16B 20/00 - TIC spécialement adaptées à la génomique ou protéomique fonctionnelle, p. ex. corrélations génotype-phénotype
G16B 40/00 - TIC spécialement adaptées aux biostatistiques; TIC spécialement adaptées à l’apprentissage automatique ou à l’exploration de données liées à la bio-informatique, p.ex. extraction de connaissances ou détection de motifs
G16B 45/00 - TIC spécialement adaptées à la visualisation de données liées à la bio-informatique, p. ex. affichage de cartes ou de réseaux
E21B 43/00 - Procédés ou dispositifs pour l'extraction de pétrole, de gaz, d'eau ou de matériaux solubles ou fusibles ou d'une suspension de matières minérales à partir de puits
C09K 8/582 - Compositions pour les méthodes de récupération assistée pour l'extraction d'hydrocarbures, c. à d. pour améliorer la mobilité de l'huile, p.ex. fluides de déplacement caractérisées par l'utilisation de bactéries
C09K 8/62 - Compositions pour la formation de crevasses ou de fractures
E21B 47/11 - Localisation des fuites, intrusions ou mouvements du fluide utilisant la radioactivité
G16B 20/20 - Détection d’allèles ou de variantes, p. ex. détection de polymorphisme d’un seul nucléotide
C12Q 1/689 - Produits d’acides nucléiques utilisés dans l’analyse d’acides nucléiques, p.ex. amorces ou sondes pour la détection ou l’identification d’organismes pour les bactéries
E21B 49/00 - Test pour déterminer la nature des parois des trous de forage; Essais de couches; Procédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits
G01V 9/00 - Prospection ou détection par des procédés non prévus dans les groupes
C12Q 1/6874 - Méthodes de séquençage faisant intervenir des réseaux d’acides nucléiques, p.ex. séquençage par hybridation [SBH]
E21B 43/26 - Procédés pour activer la production par formation de crevasses ou de fractures
A method includes receiving modelled seismic data that is to be recognized by the at least one classification and/or segmentation processor. The modelled seismic data can be represented within a transform domain. The method includes generating an output via the at least one processor based on the received modelled seismic data. The method also includes comparing the output of the at least one processor with a desired output. The method also includes modifying the at least one processor so that the output of the processor corresponds to the desired output.
G01V 1/28 - Traitement des données sismiques, p.ex. pour analyse, pour interprétation, pour correction
G01V 1/36 - Exécution de corrections statiques ou dynamiques sur des enregistrements, p.ex. correction de l'étalement; Etablissement d'une corrélation entre signaux sismiques; Elimination des effets produits par un excès d'énergie
97.
SYSTEMS AND METHODS FOR PERFORMING INSPECTIONS WITH A HEAD-WORN DISPLAY DEVICE
A method for performing an inspection includes (a) concurrently viewing a real object through a display screen of a head-worn display device worn by a user and a virtual object projected on the display screen of the head-worn display device. In addition, the method includes (b) comparing the virtual object to the real object. Further, the method includes (c) generating an inspection result in response to the comparison in (b).
A method of performing single trace inversion to characterize changes in a subsurface region includes obtaining a base seismic trace and a monitor seismic trace of the subsurface region at different respective times. The method includes generating a predicted monitor seismic trace from the base seismic trace by a process including applying a time shift to the base seismic trace, the time shift being derived from estimated velocity perturbations occurring between the base seismic trace and the monitor seismic trace, compensating for amplitude changes between the base seismic trace and the monitor seismic trace, wherein the time shift is applied to the amplitude changes, and minimizing a difference between the predicted monitor seismic trace and the monitor seismic trace by iteratively estimating the velocity perturbations to obtain final estimated velocity perturbations. Changes of at least part of the subsurface region may be characterized using the final estimated velocity perturbations.
A method of performing single trace inversion to characterize changes in a subsurface region includes obtaining a base seismic trace and a monitor seismic trace of the subsurface region at different respective times. The method includes generating a predicted monitor seismic trace from the base seismic trace by a process including applying a time shift to the base seismic trace, the time shift being derived from estimated velocity perturbations occurring between the base seismic trace and the monitor seismic trace, compensating for amplitude changes between the base seismic trace and the monitor seismic trace, wherein the time shift is applied to the amplitude changes, and minimizing a difference between the predicted monitor seismic trace and the monitor seismic trace by iteratively estimating the velocity perturbations to obtain final estimated velocity perturbations. Changes of at least part of the subsurface region may be characterized using the final estimated velocity perturbations.
A method of performing single trace inversion to characterize changes in a subsurface region includes obtaining a base seismic trace and a monitor seismic trace of the subsurface region at different respective times. The method includes generating a predicted monitor seismic trace from the base seismic trace by a process including applying a time shift to the base seismic trace, the time shift being derived from estimated velocity perturbations occurring between the base seismic trace and the monitor seismic trace, compensating for amplitude changes between the base seismic trace and the monitor seismic trace, wherein the time shift is applied to the amplitude changes, and minimizing a difference between the predicted monitor seismic trace and the monitor seismic trace by iteratively estimating the velocity perturbations to obtain final estimated velocity perturbations. Changes of at least part of the subsurface region may be characterized using the final estimated velocity perturbations.