Disclosed herein are nucleic acids comprising systems for expression of sequences of interest in fungus, comprising the following operably linked components: (a) promoters inducible by low oxygen conditions; (b) sequences of interest; and (c) Kozak upstream regions and/or transcription terminators, wherein the Kozak upstream regions and/or the transcription terminators are not native to the promoters. Such expression cassettes can provide increased expression of sequences of interest under low oxygen conditions, such as may prevail during later stages of fungal fermentations.
Disclosed are expression systems comprising sequences of interest operably linked to regulatory elements inducible by gluconate. Nucleic acids comprising the expression systems can be incorporated into recombinant microorganisms. The recombinant microorganisms can be used in methods for expressing sequences of interest and in methods for producing products by pathways comprising catalysis by proteins of interest encoded by sequences of interest.
The disclosure relates to recombinant microorganisms configured for improved sucrose uptake and/or production of produce 2-keto-3-deoxygluconic acid (KDG) from glucose. In some various embodiments, the recombinant microorganisms are engineered to (a) to non-phosphorylatively transport sucrose and/or (b) produce 2-keto-3-deoxygluconic acid (KDG) from glucose and/or (c) hydrolyze sucrose to glucose and fructose intracellularly and/or (d) isomerize fructose and glucose. The disclosure further relates to methods of non-phosphorylatively transporting sucrose and/or producing KDG using the recombinant microorganisms of the disclosure.
The disclosure relates to polypeptides having the activity to isomerize fructose and glucose, such as at mesophilic temperatures. Recombinant microorganisms can be engineered to express the polypeptides. The recombinant microorganisms can be used in methods of isomerizing fructose and glucose, comprising culturing the recombinant microorganisms in a production medium comprising sucrose, fructose, and/or glucose. The culturing can be at mesophilic temperatures.
System and techniques to fire a first source array at a first time of a first shot timing distribution comprising first time values according to a firing schedule and fire a second source array at a second time of a second shot timing distribution comprising second time values subsequent to firing the first source array and prior to another firing of the first source array according to the firing schedule. Additionally, at least a portion of the second shot timing distribution overlaps with the first shot timing distribution or the at least a portion of the second shot timing distribution is separated from the first shot timing distribution by less than a predetermined period of time and the first time and the second time of the firing schedule are separated by at least the predetermined period of time.
System and techniques to fire a first source array at a first time of a first shot timing distribution comprising first time values according to a firing schedule and fire a second source array at a second time of a second shot timing distribution comprising second time values subsequent to firing the first source array and prior to another firing of the first source array according to the firing schedule. Additionally, at least a portion of the second shot timing distribution overlaps with the first shot timing distribution or the at least a portion of the second shot timing distribution is separated from the first shot timing distribution by less than a predetermined period of time and the first time and the second time of the firing schedule are separated by at least the predetermined period of time.
A method includes generating an initial subsurface model having an initial dimensionality and based at least in part on initial seismic data, compressing the initial model subsurface model to reduce a dimensionality of the initial subsurface model and form a compressed subsurface model having a compressed dimensionality that is less than the initial dimensionality, producing an initial plurality of particles from the compressed subsurface model at the compressed dimensionality, selecting particles from the initial plurality of particles, expanding the selected particles to return the selected particles to the initial dimensionality, iteratively updating a value of each particle of the selected particles utilizing synthetic seismic data produced from the initial subsurface model to generate a posterior set of particles, and outputting the posterior set of particles as a target distribution.
A method includes generating an initial subsurface model having an initial dimensionality and based at least in part on initial seismic data, compressing the initial model subsurface model to reduce a dimensionality of the initial subsurface model and form a compressed subsurface model having a compressed dimensionality that is less than the initial dimensionality, producing an initial plurality of particles from the compressed subsurface model at the compressed dimensionality, selecting particles from the initial plurality of particles, expanding the selected particles to return the selected particles to the initial dimensionality, iteratively updating a value of each particle of the selected particles utilizing synthetic seismic data produced from the initial subsurface model to generate a posterior set of particles, and outputting the posterior set of particles as a target distribution.
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 one, 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.
C10G 65/12 - Treatment of hydrocarbon oils by two or more hydrotreatment processes only plural serial stages only including cracking steps and other hydrotreatment steps
C10G 3/00 - Production of liquid hydrocarbon mixtures from oxygen-containing organic materials, e.g. fatty oils, fatty acids
C10G 45/02 - Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbonsHydrofinishing
C10G 45/44 - Hydrogenation of the aromatic hydrocarbons
C10G 45/58 - Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to change the structural skeleton of some of the hydrocarbon content without cracking the other hydrocarbons present, e.g. lowering pour pointSelective hydrocracking of normal paraffins
C10G 47/22 - Non-catalytic cracking in the presence of hydrogen
11.
METHOD AND APPARATUS FOR ESTIMATING UNCERTAINTY OF A VELOCITY MODEL OF A SUBSURFACE REGION
A method for estimating uncertainty of an output of a velocity model 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, generating a semblance panel from the migrated seismic data, and estimating an uncertainty of the output of the velocity model based on the generated semblance panel.
A method for estimating uncertainty of an output of a velocity model 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, generating a semblance panel from the migrated seismic data, and estimating an uncertainty of the output of the velocity model based on the generated semblance panel.
A computer implemented method for providing access to documents across a plurality of separate document repositories includes: providing an index containing a plurality of documents sourced from a plurality of separate document repositories; providing a search result to a user in response to a search query, the search result referencing one or more documents sourced from the plurality of document repositories; extracting content from a plurality of documents sourced from the plurality of document repositories and constructing a data visualization based on one or more user prompts, where, the data visualization includes tabular or graphical data contained in the documents referenced in the search result; and extracting metadata from the documents referenced in the search result. Additionally, the method includes automatically detecting the presence of sensitive information in the extracted content, and allowing the user to select and download the one or more documents referenced by the search result.
A method for implementing a full waveform inversion (FWI) process using angle gathers includes; receiving observed seismic data associated with a subsurface region and captured by one or more seismic receivers, constructing based on the observed seismic data, a scalar velocity model and one or more vector velocity model partitions, where the one or more vector velocity model partitions correspond to one or more unique seismic angles. The method further includes determining one or more vector gradients using the scalar velocity model and the observed seismic data, and updating the one or more vector velocity model partitions using the one or more vector gradients. Additionally, the method also includes determining residual data by comparing synthetic data produced by the scalar velocity model with the observed seismic data, migrating the residual data backwards through time to determine one or more vector gradients, and determining the one or more unique seismic angles as the residual data is migrated backwards through time.
A method for implementing a full waveform inversion (FWI) process using angle gathers includes; receiving observed seismic data associated with a subsurface region and captured by one or more seismic receivers, constructing based on the observed seismic data, a scalar velocity model and one or more vector velocity model partitions, where the one or more vector velocity model partitions correspond to one or more unique seismic angles. The method further includes determining one or more vector gradients using the scalar velocity model and the observed seismic data, and updating the one or more vector velocity model partitions using the one or more vector gradients. Additionally, the method also includes determining residual data by comparing synthetic data produced by the scalar velocity model with the observed seismic data, migrating the residual data backwards through time to determine one or more vector gradients, and determining the one or more unique seismic angles as the residual data is migrated backwards through time.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
16.
SYSTEMS AND METHODS FOR FACILITATING THE MANAGEMENT OF ENERGY PRODUCTION OR PROCESSING FACILITIES
BP EXPLORATION OPERATING COMPANY LIMITED (United Kingdom)
Inventor
Pacheco-Rodriguez, Jesus
Ellison, Joshua
Hickey, Greg
Ballard, Adam
Gonzalez, Martin R.
Abstract
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 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 - Processing seismic data, e.g. for interpretation or for event detection
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
19.
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 - Subject matter not provided for in other groups of this subclass
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
G01V 11/00 - Prospecting or detecting by methods combining techniques covered by two or more of main groups
20.
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.
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).
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.
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.
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 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
30.
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.
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.
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. 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.
04 - Industrial oils and greases; lubricants; fuels
37 - Construction and mining; installation and repair services
Goods & Services
Fuels; industrial and automotive oils; industrial and automotive greases; lubricants; lubricating grease; cutting fluids. Vehicle service station services, vehicle washing services; vehicle maintenance and repair services; vehicle lubrication; anti-rust treatment for vehicles; vehicle tire re-fitting and repair; pump repair and maintenance; vehicle fueling station services.
37.
ANALYZING GENETIC MATERIAL OF MICROORGANISMS TO DETERMINE THE MOVEMENT OF CARBON-BASED GAS
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.
A method is provided of preparing a compound of formula II:
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 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 41/00 - Equipment or details not covered by groups
41.
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 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
G01V 1/00 - SeismologySeismic or acoustic prospecting or detecting
42.
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 - Generating seismic energy using fluidic driving means, e.g. using highly pressurised fluids which fluids escape from the generator in a pulsating manner, e.g. for generating bursts
G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas
G01V 1/18 - Receiving elements, e.g. seismometer, geophone
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
46.
SYSTEMS AND METHODS FOR CALIBRATING WELL-COMPLETION TECHNIQUES
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 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
G01V 1/32 - Transforming one recording into another
A 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 - Nucleic acid products used in the analysis of nucleic acids, e.g. primers or probes for detection or identification of organisms for bacteria
59.
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 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
60.
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 - Processing seismic data, e.g. for interpretation or for event detection
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
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 (United Kingdom)
Inventor
Pacheco-Rodriguez, Jesus
Ellison, Joshua
Hickey, Greg
Ballard, Adam
Gonzalez, Martin, R.
Abstract
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.
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.
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.
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.
The present invention provides a method of preparing a furan derivative comprising the steps of (a) converting a monosaccharide to provide a keto-intermediate product; and (b) dehydrating the keto-intermediate product to provide a furan derivative; wherein the keto-intermediate product is pre-disposed to forming keto-furanose tautomers in solution. The method may further comprise a step of oxidizing the furan derivative to provide a furandicarboxylic acid or a furandicarboxylic acid derivative.
C07D 307/56 - Heterocyclic compounds containing five-membered rings having one oxygen atom as the only ring hetero atom not condensed with other rings having two or three double bonds between ring members or between ring members and non-ring members with hetero atoms or with carbon atoms having three bonds to hetero atoms with at the most one bond to halogen, e.g. ester or nitrile radicals, directly attached to ring carbon atoms
C07H 19/01 - Compounds containing a hetero ring sharing one ring hetero atom with a saccharide radicalNucleosidesMononucleotidesAnhydro derivatives thereof sharing oxygen
C12N 9/24 - Hydrolases (3.) acting on glycosyl compounds (3.2)
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.
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 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas
75.
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 - Obtaining fluid samples or testing fluids, in boreholes or wells
C12Q 1/6888 - Nucleic acid products used in the analysis of nucleic acids, e.g. primers or probes for detection or identification of organisms
G16B 10/00 - ICT specially adapted for evolutionary bioinformatics, e.g. phylogenetic tree construction or analysis
G16B 20/00 - ICT specially adapted for functional genomics or proteomics, e.g. genotype-phenotype associations
G16B 40/00 - ICT specially adapted for biostatisticsICT specially adapted for bioinformatics-related machine learning or data mining, e.g. knowledge discovery or pattern finding
G16B 45/00 - ICT specially adapted for bioinformatics-related data visualisation, e.g. displaying of maps or networks
E21B 43/00 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
C09K 8/582 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of bacteria
C09K 8/62 - Compositions for forming crevices or fractures
E21B 47/11 - Locating fluid leaks, intrusions or movements using tracersLocating fluid leaks, intrusions or movements using radioactivity
G16B 20/20 - Allele or variant detection, e.g. single nucleotide polymorphism [SNP] detection
C12Q 1/689 - Nucleic acid products used in the analysis of nucleic acids, e.g. primers or probes for detection or identification of organisms for bacteria
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
G01V 9/00 - Prospecting or detecting by methods not provided for in groups
C12Q 1/6874 - Methods for sequencing involving nucleic acid arrays, e.g. sequencing by hybridisation [SBH]
77.
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.
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 - Obtaining fluid samples or testing fluids, in boreholes or wells
C12Q 1/6888 - Nucleic acid products used in the analysis of nucleic acids, e.g. primers or probes for detection or identification of organisms
G16B 10/00 - ICT specially adapted for evolutionary bioinformatics, e.g. phylogenetic tree construction or analysis
G16B 20/00 - ICT specially adapted for functional genomics or proteomics, e.g. genotype-phenotype associations
G16B 40/00 - ICT specially adapted for biostatisticsICT specially adapted for bioinformatics-related machine learning or data mining, e.g. knowledge discovery or pattern finding
G16B 45/00 - ICT specially adapted for bioinformatics-related data visualisation, e.g. displaying of maps or networks
E21B 43/00 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
C09K 8/582 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of bacteria
C09K 8/62 - Compositions for forming crevices or fractures
E21B 47/11 - Locating fluid leaks, intrusions or movements using tracersLocating fluid leaks, intrusions or movements using radioactivity
G16B 20/20 - Allele or variant detection, e.g. single nucleotide polymorphism [SNP] detection
C12Q 1/689 - Nucleic acid products used in the analysis of nucleic acids, e.g. primers or probes for detection or identification of organisms for bacteria
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
G01V 9/00 - Prospecting or detecting by methods not provided for in groups
C12Q 1/6874 - Methods for sequencing involving nucleic acid arrays, e.g. sequencing by hybridisation [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 - Nucleic acid products used in the analysis of nucleic acids, e.g. primers or probes for detection or identification of organisms
G16B 10/00 - ICT specially adapted for evolutionary bioinformatics, e.g. phylogenetic tree construction or analysis
G16B 20/00 - ICT specially adapted for functional genomics or proteomics, e.g. genotype-phenotype associations
C09K 8/582 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of bacteria
C12Q 1/689 - Nucleic acid products used in the analysis of nucleic acids, e.g. primers or probes for detection or identification of organisms for bacteria
E21B 43/16 - Enhanced recovery methods for obtaining hydrocarbons
E21B 47/11 - Locating fluid leaks, intrusions or movements using tracersLocating fluid leaks, intrusions or movements using radioactivity
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 - Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups , or by measuring secondary emission from the material using electron or ion microprobes using incident electron beams, e.g. scanning electron microscopy [SEM]
G06T 7/143 - SegmentationEdge detection involving probabilistic approaches, e.g. Markov random field [MRF] modelling
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.
G06K 9/00 - Methods or arrangements for reading or recognising printed or written characters or for recognising patterns, e.g. fingerprints
G01N 23/2251 - Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups , or by measuring secondary emission from the material using electron or ion microprobes using incident electron beams, e.g. scanning electron microscopy [SEM]
A method for 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.
G01N 15/08 - Investigating permeability, pore volume, or surface area of porous materials
G01N 23/2251 - Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups , or by measuring secondary emission from the material using electron or ion microprobes using incident electron beams, e.g. scanning electron microscopy [SEM]
A method for 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 - Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups , or by measuring secondary emission from the material using electron or ion microprobes using incident electron beams, e.g. scanning electron microscopy [SEM]
G06T 7/143 - SegmentationEdge detection involving probabilistic approaches, e.g. Markov random field [MRF] modelling
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 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
E21B 23/03 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting the tools into, or removing the tools from, laterally offset landing nipples or pockets
91.
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 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
92.
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.
BP EXPLORATION OPERATING COMPANY LIMITED (United Kingdom)
Inventor
Dumenil, Jean-Charles
Heddle, Richard
Wang, Shaojun
Abstract
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 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
96.
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 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
G01V 1/32 - Transforming one recording into another
97.
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 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas
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 - Preparation of carboxylic acids or their salts, halides, or anhydrides by oxidation with molecular oxygen of compounds containing six-membered aromatic rings without ring-splitting having alkyl side chains which are oxidised to carboxyl groups
C07C 51/43 - SeparationPurificationStabilisationUse of additives by change of the physical state, e.g. crystallisation
C07C 51/47 - SeparationPurificationStabilisationUse of additives by solid-liquid treatmentSeparationPurificationStabilisationUse of additives by chemisorption
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 1/137 - Generating seismic energy using fluidic driving means, e.g. using highly pressurised fluids which fluids escape from the generator in a pulsating manner, e.g. for generating bursts
G01V 1/18 - Receiving elements, e.g. seismometer, geophone
G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas
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.
