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.
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 walls; Formation testing; Methods 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
3.
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.
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 spread; Correlating seismic signals; Eliminating effects of unwanted energy
G01V 1/28 - Processing seismic data, e.g. analysis, for interpretation, for correction
6.
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. 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.
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.
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 systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 41/00 - Equipment or details not covered by groups
13.
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.
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 - Seismology; Seismic 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. analysis, for interpretation, for correction
15.
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.
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.
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 spread; Correlating seismic signals; Eliminating 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
21.
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 spread; Correlating seismic signals; Eliminating effects of unwanted energy
22.
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. analysis, for interpretation, for correction
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spread; Correlating seismic signals; Eliminating 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.
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.
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 - 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 radical; Nucleosides; Mononucleotides; Anhydro derivatives thereof sharing oxygen
C12N 9/24 - Hydrolases (3.) acting on glycosyl compounds (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.
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 spread; Correlating seismic signals; Eliminating effects of unwanted energy
G01V 1/28 - Processing seismic data, e.g. analysis, for interpretation, for correction
G01V 1/38 - Seismology; Seismic or acoustic prospecting or detecting specially adapted for water-covered areas
31.
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 - 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 biostatistics; ICT 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 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 walls; Formation testing; Methods 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]
32.
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 - 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 biostatistics; ICT 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 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 walls; Formation testing; Methods 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 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 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 - Segmentation; Edge 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.
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 - Segmentation; Edge detection involving probabilistic approaches, e.g. Markov random field [MRF] modelling
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 systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
39.
Production of 2-keto-3-deoxy-d-gluconic acid in filamentous fungi
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 - Measuring stresses in a pipe string or casing
E21B 47/001 - Survey of boreholes or wells for underwater installations
E21B 47/13 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range
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.
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 spread; Correlating seismic signals; Eliminating effects of unwanted energy
G01V 1/38 - Seismology; Seismic 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.
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 - Seismology; Seismic or acoustic prospecting or detecting specially adapted for water-covered areas
44.
Systems and methods for predicting a screen-out condition in an earthen formation
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 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
G06K 9/62 - Methods or arrangements for recognition using electronic means
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 - Tapping pipe walls, i.e. making connections through the walls of pipes while they are carrying fluids; Fittings therefor making use of attaching means embracing the pipe
F16L 1/26 - Repairing or joining pipes on or under water
E21B 37/00 - Methods or apparatus for cleaning boreholes or wells
46.
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.
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 biostatistics; ICT 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 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 walls; Formation testing; Methods 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]
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
E21B 43/267 - Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
E21B 21/06 - Arrangements for treating drilling fluids outside the borehole
48.
4D time shift and amplitude joint inversion for velocity perturbation
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 device may include a processor that may recover the signals misallocated in the deblending process of seismic data acquired with simultaneous sources. The processor may update the primary signal estimate based at least in part on a separation operation that separates coherence signals from noise signals in an output associated with the residual determined to be remaining energy for separation. The processor may be incorporated into the iterative primary signal estimate of the deblending process or be applied towards preexisting deblending output. In response to satisfying an end condition, the processor may transmit a deblended output that includes the weak coherence signals recovered from the misallocation or error in the primary signal estimate. The processor may also transmit the deblended output for use in generating a seismic image. The seismic image may represent hydrocarbons in a subsurface region of Earth or subsurface drilling hazards.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spread; Correlating seismic signals; Eliminating effects of unwanted energy
A compact seismic source for seismic acquisition generating a humming signal includes a casing and a low-frequency reciprocating drive. The casing defines a fluid tight chamber and comprises a first casing section and a second casing section of roughly equal mass. The drive is disposed within the fluid tight chamber and, in operation, reinforces the natural reciprocating oscillation of the first and second casing sections relative to one another at a low seismic frequency. In one aspect, this action omni-directionally radiates the low frequency, humming seismic signal. On another aspect, the compact seismic source is substantially smaller than the wavelength of the low seismic frequency. Such a compact source may be deployed to omni-directionally radiate a low frequency, humming seismic signal during a seismic survey.
G01V 1/00 - Seismology; Seismic or acoustic prospecting or detecting
G01V 1/135 - Generating seismic energy using fluidic driving means, e.g. using highly pressurised fluids by deforming or displacing surfaces of enclosures
G01V 1/38 - Seismology; Seismic or acoustic prospecting or detecting specially adapted for water-covered areas
G01V 1/145 - Generating seismic energy using mechanical driving means by deforming or displacing surfaces
A method includes receiving a first transition probability matrix (TPM) of a subsurface region, wherein the TPM defines, for a given lithology at a current depth sample (or micro-layer), a probability of particular lithologies at a next depth sample (or micro-layer), receiving seismic data for the subsurface region, utilizing the first TPM and the seismic data to generate first pseudo wells, calculating a second TPM from the first pseudo wells, determining whether the second TPM is consistent with the first TPM, and utilizing the first pseudo wells to characterize a reservoir in the subsurface region when the second TPM is determined to be consistent with the first TPM.
According to one embodiment, there is provided a method of correcting recorded seismic data where each receiver clock is potentially inaccurate. Since the seismic wave field is not random, and contains coherent events that are recorded by all receivers in a local area, it is possible to estimate the differences in the time reference by comparing the recordings of different receivers in a local area. With no external time reference, time signal, or pilot trace, an entire seismic data itself can be used to determine how each receiver's clock is drifting from true time.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spread; Correlating seismic signals; Eliminating effects of unwanted energy
G01V 1/00 - Seismology; Seismic or acoustic prospecting or detecting
53.
Systems and methods for measuring the positions of fluids in a well
A method for cementing a borehole includes pumping a collection of fluids into the borehole through a tubular string in the borehole and flowing the collection of fluids up an annulus positioned between the tubular string and a sidewall of the borehole. The method additionally includes monitoring a volume of the fluids pumped into the borehole, and performing a first estimation of a position of the fluids based on the volume of the collection of fluids pumped into the borehole, and an initial estimate of an average diameter of the sidewall of at least a portion of the borehole. The method further includes calculating a corrected estimate of the average diameter based on the first estimation and a pressure of the fluids measured at an inlet of the tubular string, and performing a second estimation of the position of the fluids based on the corrected estimate of the average diameter.
A method of seismic exploration above a region of the subsurface of the earth containing structural or stratigraphic features conducive to the presence, migration, or accumulation of hydrocarbons comprises setting a tow depth of a resonant seismic source, producing a resonant frequency at a first amplitude with the resonant seismic source at the tow depth, detecting a depth excursion from the tow depth, reducing an amplitude of the mass from the first amplitude to a second amplitude, preventing the mass from contacting at least one of the first end stop or the second end stop based on reducing the amplitude to the second amplitude, correcting the depth excursion to return the resonant seismic source to the tow depth, and increasing the amplitude from the second amplitude to produce the resonant frequency with the resonant seismic source at the tow depth.
A system for remediating a blockage in a subsea component including a riser extending from a surface vessel, a flexible jumper having an upper end coupled to the riser and a lower end coupled to a subsea component, and a surface system disposed on the surface vessel and including flexible tubing configured to be inserted and advanced through the tubular string and flexible jumper to the blockage.
E21B 19/22 - Handling reeled pipe or rod units, e.g. flexible drilling pipes
E21B 19/24 - Guiding or centralising devices for drilling rods or pipes
E21B 37/06 - Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting the deposition of paraffins or like substances
A method of detecting corrosion in a conduit or container comprises measuring the thickness of a wall of the conduit or container with one or more pulse-echo ultrasound devices, wherein the method comprises the following steps: (i) receiving signals indicative of A-scan data from the one or more pulse-echo ultrasound devices, wherein the A-scan data comprises a plurality of A-scan spectra; (ii) determining which of the A-scan spectra have a distorted waveform such that a reliable wall thickness measurement cannot be determined; (iii) analysing the A-scan spectra identified in step (ii) as having a distorted waveform to determine one or more A-scan spectral characteristics of each spectrum that are causing the distortion; (iv) resolving the waveform characteristics based on the determined spectral characteristics causing the waveform distortion so as to produce modified A-scan spectra; (v) determining thickness measurements of the wall based on the modified A-scan spectra; and (vi) determining the extent to which the wall has been corroded based on the thickness measurements determined in step (v) and additional thickness determined from A-scan spectra.
Methods and associated systems are disclosed for performing a logging operation within a subterranean wellbore extending within a subterranean reservoir. In an embodiment, the method includes (a) emitting neutrons into the subterranean wellbore or the subterranean reservoir, and (b) detecting gamma rays emitted from atoms disposed within the subterranean wellbore or the subterranean reservoir. In addition, the method includes (c) determining a first gamma ray count within a first energy window of the gamma rays detected at (b), and (d) determining a second gamma ray count within a second energy window of the gamma rays detected at (b). The second energy window is different than the first energy window. Further, the method includes (e) calculating a ratio of the first gamma ray count to the second gamma ray count.
G01V 5/10 - Prospecting or detecting by the use of nuclear radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using neutron sources
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
58.
Systems and methods for mitigating an uncontrolled fluid flow from a target wellbore using a relief wellbore
A method for mitigating a fluid flow from a target wellbore using a relief wellbore includes receiving wellbore geometry information of the target wellbore, receiving an initial interception point of the target wellbore, simulating a change in a three-dimensional flow characteristic of a kill fluid flow from a simulated relief wellbore and a target fluid flow from a simulated target wellbore resulting from an interaction between the kill fluid flow and the target fluid flow at the initial interception point, the simulated target wellbore designed using the received wellbore geometry information, and determining a final interception point of the target wellbore based on the simulation.
A process for optimising the removal of calcium from a hydrocarbon feedstock in a refinery desalting process, the refinery desalting process comprising the following steps: (a) mixing one or more wash water streams with one or more hydrocarbon feedstock streams; (b) at least partially separating the wash water from the hydrocarbons in a refinery desalter; and (c) removing the separated water and hydrocarbons from the refinery desalter as one or more desalted hydrocarbon streams and one or more effluent water streams; the process optimisation comprising: (i) providing at least one x-ray fluorescence analyser at at least one point in the refinery desalting process; (ii) measuring the concentration of calcium at the at least one point in the process using the at least one x-ray fluorescence analyser; and (iii) optionally adjusting at least one process condition of the refinery desalting process in response to the calcium concentration measurement in step (ii). An apparatus comprises a desalter; a line through which one or more hydrocarbon feedstock streams are passed to the desalter; optionally a line through which one or more wash water streams are passed to the desalter; and one or more x-ray fluorescence analysers configured so as to measure the concentration of calcium in water or hydrocarbons at one or more positions within the apparatus.
C10G 31/08 - Refining of hydrocarbon oils, in the absence of hydrogen, by methods not otherwise provided for by treating with water
C10G 17/04 - Liquid-liquid treatment forming two immiscible phases
C10G 33/02 - De-watering or demulsification of hydrocarbon oils with electrical or magnetic means
G01N 23/223 - Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups , or by measuring secondary emission from the material by irradiating the sample with X-rays or gamma-rays and by measuring X-ray fluorescence
A process for manufacturing a carboxylic acid is provided, in one aspect, the process comprises oxidizing a feedstock comprising a substituted aromatic hydrocarbon to form a liquid-phase aromatic carboxylic acid; crystallizing at least a portion of the liquid-phase aromatic carboxylic acid in the presence of oxygen and an oxidation catalyst in a first crystallizer to form solid aromatic carboxylic acid, under reaction conditions suitable to oxidize unreacted feedstock to form additional aromatic carboxylic acid; and crystallizing at least a portion of the first crystallization effluent in the presence of oxygen and an oxidation catalyst in a second crystallizer to form additional solid aromatic carboxylic acid, under reaction conditions suitable to oxidize unreacted feedstock to form additional aromatic carboxylic acid, wherein the oxygen is present in a gaseous phase inside the second crystallizer in an amount of no more than 11% by volume on a dry basis.
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 - Separation; Purification; Stabilisation; Use of additives by change of the physical state, e.g. crystallisation
61.
Separation of multiple seismic sources of different types by inversion
A method of seismic exploration above a region of the subsurface containing structural or stratigraphic features conducive to the presence, migration, or accumulation of hydrocarbons comprises accessing at least a portion of a blended seismic source survey, separating the at least two interfering seismic source excitations using inversion separation, producing one or more source gathers based on the separating, and using the one or more source gathers to explore for hydrocarbons within said region of the subsurface. The blended source seismic survey contains at least two interfering seismic source excitations therein, and the seismic source excitations can be produced by seismic source types having different signatures or frequency characteristics.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spread; Correlating seismic signals; Eliminating effects of unwanted energy
Systems and methods are disclosed that include generating reservoir property profiles corresponding to reservoir properties for pseudo wells based on reservoir data, generating seismic attributes for the pseudo wells, and training a machine learning model by comparing the reservoir property profiles against the seismic attributes. In this manner, the machine learning model may be used to predict reservoir properties for use with seismic exploration above a region of a subsurface that contains structural or stratigraphic features conducive to a presence, migration, or accumulation of hydrocarbons.
A remotely operated device for inspecting and/or cleaning a subsea flexible pipe joint comprises a support assembly. In addition, the device comprises a tool positioning assembly coupled to the support assembly. The tool positioning assembly includes a rotating member disposed about a central axis. The tool positioning assembly is rotatable relative to the support assembly about the central axis. Further, the device comprises a cleaning assembly including a cleaning device adapted to clean the flexible pipe joint. The cleaning device is axially moveable relative to the rotating member. Still further, the device comprises a clamping assembly coupled to the support assembly. The clamping assembly has an open position disengaged with the section of the flexible pipe joint and a closed position engaging the section of the flexible pipe joint.
A method for analyzing a rock sample to determine a mechanical property of the rock sample includes (a) segmenting a digital image volume corresponding to an image of the rock sample. In addition, the method includes (b) partitioning the digital image volume to associate a plurality of voxels in the digital image volume with a plurality of grains of the rock sample. Further, the method includes (c) determining the voxels of the plurality of voxels that are adjacent to each other to identify a plurality of contact interfaces between the grains. Still further, the method includes (d) determining a contact area of each of the contact interfaces using adjacent voxels at the corresponding grain-grain interface. The method also includes (e) determining a number of contact interfaces that each grain of the plurality of grains has with each adjacent grain. Moreover, the method includes (f) determining the one or more mechanical properties of the rock sample based on the number of the contact interfaces of each of the plurality of grains and the contact area of each of the contact interfaces.
Bypass devices are disclosed for providing alternative flow paths within an annulus formed around a production string of a subterranean wellbore. In some embodiments, the bypass devices include inlet flow paths and outlet flow paths in fluid communication with the annulus so that fluids may flow through the inlet and outlet flow paths to bypass a blockage in the annulus. The bypass devices are also configured to avoid internal blockages within the internal flow paths defined by the inlet flow paths and outlet flow paths.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
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
A tangible, non-transitory computer-readable medium configured to store instructions executable by a processor of an electronic device to access a beam migration image of a subsurface target. In addition, the computer-readable medium is configured to store instructions executable by a processor of an electronic device to determine a decomposition criteria based on at least one of subsurface dip inclinations, subsurface dip azimuths, or a combination thereof. Further, the computer-readable medium is configured to store instructions executable by a processor of an electronic device to decompose the beam migration image into a plurality of partial images according to the decomposition criteria to provide various views of the subsurface target. The plurality of partial images are usable by seismic interpreters in exploration for hydrocarbons within the subsurface target.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spread; Correlating seismic signals; Eliminating effects of unwanted energy
G01V 1/28 - Processing seismic data, e.g. analysis, for interpretation, for correction
A velocity model is generated based upon seismic waveforms via any seismic model building method, such as full waveform inversion or tomography. Data representative of a measurement of a physical attribute of an area surrounding a well is received and an attribute model is generated based upon the velocity model and the data. An image is rendered based upon the attribute model for use with seismic exploration above a region of a subsurface comprising a hydrocarbon reservoir and containing structural or stratigraphic features conducive to a presence, migration, or accumulation of hydrocarbons.
Systems and methods that include receiving reservoir data of a hydrocarbon reservoir, receive an indication related to selection of a wavefield propagator, application of the wavefield propagator utilizing Fourier Finite Transforms and Finite Differences to model a wavefield associated with a Tilted Orthorhombic media representative of a region of a subsurface comprising the hydrocarbon reservoir, and processing the reservoir data in conjunction the wavefield propagator to generate an output for use with seismic exploration above a region of a subsurface comprising the hydrocarbon reservoir and containing structural or stratigraphic features conducive to a presence, migration, or accumulation of hydrocarbons.
A method includes receiving, via a processor, a first seismic dataset generated using a first type of survey system. The method further includes receiving, via the processor, a second seismic dataset generated using a second type of survey system. The method additionally includes determining a frequency band in which to combine the first seismic dataset with the second seismic dataset to generate a combined dataset and generating a seismic image based upon the combined dataset, wherein the seismic image represents hydrocarbons in a subsurface region of the Earth or subsurface drilling hazards.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spread; Correlating seismic signals; Eliminating effects of unwanted energy
A method for producing hydrocarbons within a reservoir includes (a) injecting an aqueous solution into the reservoir. The aqueous solution includes water and a thermally activated chemical species. The thermally activated chemical species is urea, a urea derivative, or a carbamate. The thermally activated chemical agent is thermally activated at or above a threshold temperature less than 200° C. In addition, the method includes (b) thermally activating the thermally activated chemical species in the aqueous solution during or after (a) at a temperature equal to or greater than the threshold temperature to produce carbon-dioxide and at least one of ammonia, amine, and alkanolamine within the reservoir. Further, the method includes (c) increasing the water wettability of the subterranean formation in response to the thermally activation in (b). Still further, the method includes (d) waterflooding the reservoir with water after (a), (b) and (c).
Provided herein are methods for producing cyclic and acyclic ketones from trimerization and dimerization of alkyl ketones, including for example methyl ketones. Such cyclic and acyclic ketones may be suitable for use as fuel and lubricant precursors, and may be hydrodeoxygenated to form their corresponding cycloalkanes and alkanes. Such cycloalkanes and alkanes may be suitable for use as fuels, including jet fuels, and lubricants.
C07C 1/22 - Preparation of hydrocarbons from one or more compounds, none of them being a hydrocarbon starting from organic compounds containing only oxygen atoms as hetero atoms by reduction
C07C 13/00 - Cyclic hydrocarbons containing rings other than, or in addition to, six-membered aromatic rings
C07C 45/74 - Preparation of compounds having C=O groups bound only to carbon or hydrogen atoms; Preparation of chelates of such compounds by reactions not involving the formation of C=O groups by change of size of the carbon skeleton by increase in the number of carbon atoms by reaction of compounds containing C=O groups with the same or other compounds containing C=O groups combined with dehydration
C07D 307/46 - Doubly bound oxygen atoms, or two oxygen atoms singly bound to the same carbon atom
C07C 1/207 - Preparation of hydrocarbons from one or more compounds, none of them being a hydrocarbon starting from organic compounds containing only oxygen atoms as hetero atoms from carbonyl compounds
C10L 1/04 - Liquid carbonaceous fuels essentially based on blends of hydrocarbons
C10G 3/00 - Production of liquid hydrocarbon mixtures from oxygen-containing organic materials, e.g. fatty oils, fatty acids
C07C 13/18 - Monocyclic hydrocarbons or acyclic hydrocarbon derivatives thereof with a six-membered ring with a cyclohexane ring
C07C 15/113 - Monocyclic hydrocarbons having a saturated side-chain containing at least six carbon atoms, e.g. detergent alkylates having at least two saturated side-chains, each containing at least six carbon atoms
C07C 49/203 - Unsaturated compounds containing keto groups bound to acyclic carbon atoms with only carbon-to-carbon double bonds as unsaturation
C07C 49/603 - Unsaturated compounds containing a keto group being part of a ring of a six-membered ring
C07C 49/613 - Unsaturated compounds containing a keto group being part of a ring polycyclic
C07C 49/657 - Unsaturated compounds containing a keto group being part of a ring containing six-membered aromatic rings
72.
Systems and methods for colocation of high performance computing operations and hydrocarbon production facilities
A hydrocarbon production system includes a well at a remote location. The well is configured to produce hydrocarbon production fluids comprising natural gas. The system also includes a turbo-generator coupled to the well and configured to receive the natural gas and produce electricity from the natural gas. In addition, the system includes a high performance computing (HPC) data center coupled to the turbo-generator and configured to be powered by the electricity from the turbo-generator.
Systems and methods process a measured ultrasonic response waveform to determine a well casing thickness and an acoustic impedance of a sealing medium surrounding the well casing. An array of simulated response waveforms corresponding to a set of candidate acoustic impedances for the sealing medium surrounding the well casing and a set of candidate well casing thicknesses is generated. A simulated response waveform from the array of simulated response waveforms is identified that best matches the measured response waveform so as to determine the sealing medium acoustic impedance.
The presently disclosed seismic acquisition technique employs a receiver array and a processing methodology that are designed to attenuate the naturally occurring seismic background noise recorded along with the seismic data during the acquisition. The approach leverages the knowledge that naturally occurring seismic background noise moves with a slower phase velocity than the seismic signals used for imaging and inversion and, in some embodiments, may arrive from particular preferred directions. The disclosed technique comprises two steps: 1) determining from the naturally occurring seismic background noise in the preliminary seismic data a range of phase velocities and amplitudes that contain primarily noise and the degree to which that noise needs to be attenuated, and 2) designing an acquisition and processing method to attenuate that noise relative to the desired signal.
G01V 1/28 - Processing seismic data, e.g. analysis, for interpretation, for correction
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spread; Correlating seismic signals; Eliminating effects of unwanted energy
G01V 1/38 - Seismology; Seismic or acoustic prospecting or detecting specially adapted for water-covered areas
A refinery built around a slurry phase hydrocracking process unit, such as a Veba Combi-Cracker (VCC), is simpler, produces more liquid product as transportation fuels and has much higher net cash margin than a refinery built around a coker or other bottoms upgrading processes. The VCC unit replaces one or more processing steps normally included in refineries as separate and distinct processing units including heavy distillate/gas oil cracking and optionally bottoms upgrading and deep desulfurization of diesel and gasoline range cuts. The refinery design is especially suited for heavy crude upgrading and can be tuned to provide a wide range of gasoline to distillate production ratios. The refinery design is “bottomless” in the sense that it produces no heavy fuel oil or asphalt as product and no solid fuel (e.g., petroleum coke).
C10G 67/02 - Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one process for refining in the absence of hydrogen only plural serial stages only
C10G 47/26 - Cracking of hydrocarbon oils, in the presence of hydrogen or hydrogen-generating compounds, to obtain lower boiling fractions with moving solid particles suspended in the oil, e.g. slurries
C10G 65/10 - Treatment of hydrocarbon oils by two or more hydrotreatment processes only plural serial stages only including only cracking steps
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
A technique for use in geophysical surveying includes imparting a plurality of humming seismic signals and a plurality of low-frequency seismic signals into a geological formation. The technique also includes receiving returned seismic energy of the plurality of humming seismic signals and the plurality of low-frequency seismic signals after interacting with the geological formation and recording the returned seismic energy.
A compact seismic source for seismic acquisition generating a humming signal includes a casing and a low-frequency reciprocating drive. The casing defines a fluid tight chamber and comprises a first casing section and a second casing section of roughly equal mass. The drive is disposed within the fluid tight chamber and, in operation, reinforces the natural reciprocating oscillation of the first and second casing sections relative to one another at a low seismic frequency. In one aspect, this action omni-directionally radiates the low frequency, humming seismic signal. On another aspect, the compact seismic source is substantially smaller than the wavelength of the low seismic frequency. Such a compact source may be deployed to omni-directionally radiate a low frequency, humming seismic signal during a seismic survey.
G01V 1/00 - Seismology; Seismic or acoustic prospecting or detecting
G01V 1/135 - Generating seismic energy using fluidic driving means, e.g. using highly pressurised fluids by deforming or displacing surfaces of enclosures
G01V 1/38 - Seismology; Seismic or acoustic prospecting or detecting specially adapted for water-covered areas
G01V 1/145 - Generating seismic energy using mechanical driving means by deforming or displacing surfaces
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.
Provided herein are methods for producing cyclic and acyclic ketones from trimerization and dimerization of alkyl ketones, including for example methyl ketones. Such cyclic and acyclic ketones may be suitable for use as fuel and lubricant precursors, and may be hydrodeoxygenated to form their corresponding cycloalkanes and alkanes. Such cycloalkanes and alkanes may be suitable for use as fuels, including jet fuels, and lubricants.
C07C 1/22 - Preparation of hydrocarbons from one or more compounds, none of them being a hydrocarbon starting from organic compounds containing only oxygen atoms as hetero atoms by reduction
C07C 13/00 - Cyclic hydrocarbons containing rings other than, or in addition to, six-membered aromatic rings
C07C 45/74 - Preparation of compounds having C=O groups bound only to carbon or hydrogen atoms; Preparation of chelates of such compounds by reactions not involving the formation of C=O groups by change of size of the carbon skeleton by increase in the number of carbon atoms by reaction of compounds containing C=O groups with the same or other compounds containing C=O groups combined with dehydration
C07D 307/46 - Doubly bound oxygen atoms, or two oxygen atoms singly bound to the same carbon atom
C07C 1/207 - Preparation of hydrocarbons from one or more compounds, none of them being a hydrocarbon starting from organic compounds containing only oxygen atoms as hetero atoms from carbonyl compounds
C10L 1/04 - Liquid carbonaceous fuels essentially based on blends of hydrocarbons
C10G 3/00 - Production of liquid hydrocarbon mixtures from oxygen-containing organic materials, e.g. fatty oils, fatty acids
C07C 13/18 - Monocyclic hydrocarbons or acyclic hydrocarbon derivatives thereof with a six-membered ring with a cyclohexane ring
C07C 15/113 - Monocyclic hydrocarbons having a saturated side-chain containing at least six carbon atoms, e.g. detergent alkylates having at least two saturated side-chains, each containing at least six carbon atoms
C07C 49/203 - Unsaturated compounds containing keto groups bound to acyclic carbon atoms with only carbon-to-carbon double bonds as unsaturation
C07C 49/603 - Unsaturated compounds containing a keto group being part of a ring of a six-membered ring
C07C 49/613 - Unsaturated compounds containing a keto group being part of a ring polycyclic
C07C 49/657 - Unsaturated compounds containing a keto group being part of a ring containing six-membered aromatic rings
VisRes, which, in turn, is calculated from the P-value of the visbroken residue stream. The methods may be used to predict the stability of a fuel oil containing the visbroken residue.
A method for use in seismic exploration includes: obtaining a diving wave illumination image of a subterranean region from a set of seismic data representative of the subterranean region using a selected acquisition geometry; clipping an inverse of the diving wave illumination image to a range of values; and performing a weighted full-waveform inversion. The weighted full-waveform inversion further includes: weighting a full-waveform inversion gradient with the clipped inverse of the diving wave illumination image; and performing the full-waveform inversion using the weighted gradient.
A technique for estimating a depth of investigation of a seismic survey includes in various aspects a method and an apparatus. The method is for use in seismic exploration and includes: forward modeling on a subsurface attribute model of a subterranean region to generate a set of low frequency seismic data, the subsurface attribute model being generated from data representative of the subterranean region; performing a reverse time migration on the low frequency seismic data to obtain a plurality of gathers with large opening angles; stacking the gathers to yield a diving wave illumination image; and estimating a full-waveform inversion depth of investigation from the diving wave illumination image. The apparatus may include a computing apparatus programmed to perform the method and/or a program storage medium encoded with computing instructions that, when executed, perform the method.
An automatic batch sequence computer control system is configured to automatically operate process valves in a delayed coker for a complete coke drum cycle. Double verification of the movement of the process valves is used to confirm advancing to the next step. Primary verification is achieved by using position sensors on the valves. Secondary verification is achieved by using monitored process conditions and confirming the measured conditions correlate with expected process conditions for an arrangement of valve positions at a given sequence in the coke drum cycle. A safety interlock system may be integrated with the control system.
A method for analyzing a rock sample includes segmenting a digital image volume corresponding to the rock sample, to associate voxels in the digital image volume with pore space or solid material. A distance transform is applied to each pore space voxel. The distance transform assigns a distance value to the pore space voxel specifying distance from the pore space voxel to a solid material voxel. Drainage is numerically simulated by, for a pore space, selecting each distance value assigned to a pore space voxel that is greater than a predetermined threshold value to represent a radius of a sphere of a non-wetting fluid introduced into the pore space. The sphere is centered at the pore space voxel corresponding to the distance value. The digital image volume is numerically analyzed to characterize a material property of the rock sample at a non-wetting fluid saturation produced by the drainage.
A method comprises correlating—in a system which comprises a non-aqueous phase comprising a hydrocarbon fluid, and an aqueous phase—partitioning levels of a basic contaminant and/or an acid of interest into the aqueous phase with the pH of the aqueous phase. The partitioning levels of the basic contaminant and the acid of interest, as well as the pH of the aqueous phase, are obtained under conditions which are representative of those used in a partitioning process in which a basic contaminant is removed from a hydrocarbon fluid.
The correlations may be used in a method for selecting an acidic environment for use in a partitioning process, for estimating corrosion risk downstream of a partitioning process, or for controlling a partitioning process.
C10G 17/04 - Liquid-liquid treatment forming two immiscible phases
C10G 31/08 - Refining of hydrocarbon oils, in the absence of hydrogen, by methods not otherwise provided for by treating with water
C10G 33/00 - De-watering or demulsification of hydrocarbon oils
C10G 17/00 - Refining of hydrocarbon oils, in the absence of hydrogen, with acids, acid-forming compounds, or acid-containing liquids, e.g. acid sludge
C10G 21/06 - Refining of hydrocarbon oils, in the absence of hydrogen, by extraction with selective solvents characterised by the solvent used
C10G 17/06 - Liquid-liquid treatment forming two immiscible phases using acids derived from sulfur or acid sludge thereof
A process for analyzing a hydrocarbon stream comprises: withdrawing a hydrocarbon sample from a hydrocarbon stream; passing the hydrocarbon sample to an analysis device at a target temperature of greater than 120° C. and a target flow rate of greater than 20 liters per minute; and returning the hydrocarbon sample to the hydrocarbon stream. The process may be used for the on-line analysis of crude oil, in order to optimize a refinery operation.
A method for producing hydrocarbons within a reservoir includes (a) injecting an aqueous solution into the reservoir. The aqueous solution includes water and a thermally activated chemical species. The thermally activated chemical species is urea, a urea derivative, or a carbamate. The thermally activated chemical agent is thermally activated at or above a threshold temperature less than 200 C. In addition, the method includes (b) thermally activating the thermally activated chemical species in the aqueous solution during or after (a) at a temperature equal to or greater than the threshold temperature to produce carbon-dioxide and at least one of ammonia, amine, and alkanolamine within the reservoir. Further, the method includes (c) increasing the water wettability of the subterranean formation in response to the thermally activation in (b). Still further, the method includes (d) waterflooding the reservoir with water after (a), (b) and (c).
A system for producing hydrocarbons from a subterranean well including a wellbore extending from a surface into a subterranean formation includes a wellhead disposed at the surface. In addition, the system includes a production tree coupled to the wellhead and a casing coupled to the wellhead and extending into the wellbore. Still further, the system includes a first production tubing string extending into the casing from the wellhead to a first production zone and a second production tubing string extending into the casing from the wellhead to the first production zone. The first production tubing string and the second production tubing string are each configured to provide a fluid flow path for gases from the first production zone. The second production tubing string is radially spaced from the first production tubing string. The first production tubing string has an inner diameter D1 that is larger than an inner diameter D2 of the second production tubing string.
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 biostatistics; ICT 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 radioactivity
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 walls; Formation testing; Methods 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]
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
E21B 43/267 - Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
E21B 21/06 - Arrangements for treating drilling fluids outside the borehole
90.
Methods for producing fuels, gasoline additives, and lubricants using amine catalysts
Provided herein are methods for producing α,β-unsaturated ketones from the condensation of methyl ketones in the presence of an amine catalyst. Such amine catalysts may be supported, for example, on a silica-alumina support. Such amine catalysts may be used in the presence of an additional acid. The α,β-unsaturated ketones may be produced by dimerization and/or timerization of the methyl ketones. Such α,β-unsaturated ketones may be suitable for use in producing fuels, gasoline additives, and/or lubricants, or precursors thereof. The methyl ketones may be obtained from renewable sources, such as by the fermentation of biomass.
C07C 45/74 - Preparation of compounds having C=O groups bound only to carbon or hydrogen atoms; Preparation of chelates of such compounds by reactions not involving the formation of C=O groups by change of size of the carbon skeleton by increase in the number of carbon atoms by reaction of compounds containing C=O groups with the same or other compounds containing C=O groups combined with dehydration
B01J 31/02 - Catalysts comprising hydrides, coordination complexes or organic compounds containing organic compounds or metal hydrides
C10L 1/02 - Liquid carbonaceous fuels essentially based on components consisting of carbon, hydrogen, and oxygen only
C10G 3/00 - Production of liquid hydrocarbon mixtures from oxygen-containing organic materials, e.g. fatty oils, fatty acids
B01J 31/04 - Catalysts comprising hydrides, coordination complexes or organic compounds containing organic compounds or metal hydrides containing carboxylic acids or their salts
C07C 1/207 - Preparation of hydrocarbons from one or more compounds, none of them being a hydrocarbon starting from organic compounds containing only oxygen atoms as hetero atoms from carbonyl compounds
C07C 49/203 - Unsaturated compounds containing keto groups bound to acyclic carbon atoms with only carbon-to-carbon double bonds as unsaturation
A method for aligning a plurality of seismic images associated with a subsurface region of the Earth may include receiving the seismic images and determining a first respective relative shift volume between a first seismic image and a second seismic image, a second respective relative shift volume between the first seismic image and a third seismic image, and a third respective relative shift volume between the second seismic image and the third seismic image. The method may include determining a first shift volume associated with the first seismic image and a second shift volume associated with the second seismic image based on the first, second, and third respective relative shift volumes. The method may then apply the first shift volume to the first seismic image and the second shift volume to the second seismic image.
G06K 9/00 - Methods or arrangements for reading or recognising printed or written characters or for recognising patterns, e.g. fingerprints
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spread; Correlating seismic signals; Eliminating effects of unwanted energy
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
A process is provided for recovering a heavy metal from a waste stream resulting from a process for producing aromatic carboxylic acid by liquid-phase oxidation of an aromatic feedstock compound in the presence of a heavy metal catalyst. The process comprises: (a) producing a carbonate salt precipitate of the heavy metal by adding a source of metal ions and carbonate or bicarbonate ions into the waste stream; (b) separating the precipitate from the waste stream; (c) washing the precipitate with an alkali solution having metal ions therein, wherein at least a portion of the metal ions in the alkali solution are the same as at least a portion of metal ions in the source of metal ions and carbonate or bicarbonate ions; and, (d) recovering the washed precipitate wherein the washed precipitate comprises the heavy metal ions. In one embodiment, the aromatic carboxylic acid comprises terephthalic acid.
C07C 51/41 - Preparation of salts of carboxylic acids by conversion of the acids or their salts into salts with the same carboxylic acid part
C02F 1/52 - Treatment of water, waste water, or sewage by flocculation or precipitation of suspended impurities
C22B 3/12 - Extraction of metal compounds from ores or concentrates by wet processes by leaching in inorganic alkaline solutions
C22B 3/22 - Treatment or purification of solutions, e.g. obtained by leaching by physical processes, e.g. by filtration, by magnetic means
C07C 51/00 - Preparation of carboxylic acids or their salts, halides, or anhydrides
C07C 51/487 - Separation; Purification; Stabilisation; Use of additives by treatment giving rise to chemical modification
C02F 101/20 - Heavy metals or heavy metal compounds
C02F 103/36 - Nature of the water, waste water, sewage or sludge to be treated from the chemical industry not provided for in groups from the manufacture of organic compounds
A method for use in marine seismic surveying includes: towing at least a portion of a marine seismic survey spread; imparting a composite swept seismic signal from the marine seismic survey spread, the composite swept seismic signal including a plurality of randomized subsweeps having different frequencies relative to one another and being emitted in parallel; and receiving a respective return for each of the subsweeps.
A process for the hydrocracking of heavy oils and/or oil residues, the process comprising the step of contacting the heavy oils and/or oil residues with a non-metallised carbonaceous additive in the presence of a hydrogen-containing gas at a temperature of from 250° C. to 600° C. wherein the non-metallised carbonaceous additive has an average pore size of at least 2 nm.
C10G 45/00 - Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds
C10G 45/04 - 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 hydrocarbons; Hydrofinishing characterised by the catalyst used
C10G 45/46 - Hydrogenation of the aromatic hydrocarbons characterised by the catalyst used
C10G 45/60 - 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 point; Selective hydrocracking of normal paraffins characterised by the catalyst used
C10G 47/02 - Cracking of hydrocarbon oils, in the presence of hydrogen or hydrogen-generating compounds, to obtain lower boiling fractions characterised by the catalyst used
C10G 1/08 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by destructive hydrogenation with moving catalysts
A method may involve positioning a fixture over a portion of a tube portion of a gasket, where the gasket includes a first lip portion joined to a second lip portion by a weld of the gasket and the first lip portion joined to the second lip portion defines the tube portion, where the fixture comprises a housing and an injection port; positioning an ultrasonic probe in the housing; filling, by the injection port, coupling fluid between the ultrasonic probe and the tube portion of the gasket; and scanning at least a portion of the weld with the ultrasonic probe, where scanning the at least a portion of the weld may involve transmitting, by the ultrasonic probe, a plurality of ultrasonic waves through the coupling fluid into the tube portion, and translating the fixture in a longitudinal direction along the tube portion of the gasket.
G01N 29/07 - Analysing solids by measuring propagation velocity or propagation time of acoustic waves
G01N 29/22 - Investigating or analysing materials by the use of ultrasonic, sonic or infrasonic waves; Visualisation of the interior of objects by transmitting ultrasonic or sonic waves through the object - Details
(LO recalculated), according to the following formula:
x is 1 where a titrant is present, and otherwise is 0.
The recalculated solvent power may be used in methods for preventing asphaltene precipitation during processing of crude oils in a refinery.
G01N 31/16 - Investigating or analysing non-biological materials by the use of the chemical methods specified in the subgroups; Apparatus specially adapted for such methods using titration
97.
Predicting high temperature asphaltene precipitation
C10G 75/00 - Inhibiting corrosion or fouling in apparatus for treatment or conversion of hydrocarbon oils, in general
C10G 75/04 - Inhibiting corrosion or fouling in apparatus for treatment or conversion of hydrocarbon oils, in general by addition of antifouling agents
G01N 17/00 - Investigating resistance of materials to the weather, to corrosion or to light
The instant invention is designed to provide an adaptive approach to removing short-period time/phase distortions within a downward-continuation process that is a key component of seismic migration algorithms. Using techniques analogous to residual statics corrections that are used in standard seismic processing, one inventive approach estimates and removes the effects of short wavelength velocity disruptions, thereby creating clearer seismic images of the subsurface of the earth. Additionally, the instant method will provide an updated velocity model that can be used to obtain further image improvement.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spread; Correlating seismic signals; Eliminating effects of unwanted energy
99.
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 - Obtaining fluid samples or testing fluids, in boreholes or wells
G06F 19/26 - for data visualisation, e.g. graphics generation, display of maps or networks or other visual representations
C12Q 1/68 - Measuring or testing processes involving enzymes, nucleic acids or microorganisms; Compositions therefor; Processes of preparing such compositions involving nucleic acids
G06F 19/24 - for machine learning, data mining or biostatistics, e.g. pattern finding, knowledge discovery, rule extraction, correlation, clustering or classification
G06F 19/18 - for functional genomics or proteomics, e.g. genotype-phenotype associations, linkage disequilibrium, population genetics, binding site identification, mutagenesis, genotyping or genome annotation, protein-protein interactions or protein-nucleic acid interactions
G06F 19/14 - for phylogeny or evolution, e.g. evolutionarily conserved regions determination or phylogenetic tree construction
E21B 47/10 - Locating fluid leaks, intrusions or movements
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 49/00 - Testing the nature of borehole walls; Formation testing; Methods 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
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
E21B 43/267 - Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
E21B 21/06 - Arrangements for treating drilling fluids outside the borehole
100.
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.
C12Q 1/6888 - Nucleic acid products used in the analysis of nucleic acids, e.g. primers or probes for detection or identification of organisms
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
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 biostatistics; ICT 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 radioactivity
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods 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]
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 43/26 - Methods for stimulating production by forming crevices or fractures
E21B 43/267 - Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
E21B 21/06 - Arrangements for treating drilling fluids outside the borehole
patents
