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.
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.
The present disclosure related generally to a process for removing chloride-containing organic compounds from renewable and bio-feedstocks. Accordingly, in one aspect, the present disclosure provides for a process for processing a liquid feed, the process comprising: providing a liquid feed that comprises one or more fatty acids and/or fatty acid esters, the liquid feed having a first chloride concentration by weight of chloride-containing organic compounds; and contacting the liquid feed with a solid treatment material to remove at least a fraction of the chloride-containing organic compounds to produce a treated liquid feed having a second chloride concentration that is less than the first chloride concentration, wherein the solid treatment material comprises an alkali metal or an alkaline earth metal in ionic form.
The present disclosure relates generally to processes for handling renewable hydrocarbon feeds and conventional hydrocarbon feeds. One aspect of the disclosure provides a process for co-processing a renewable feed and a petroleum feed, the process comprising: hydrotreating the petroleum feed in a first reaction zone, wherein the hydrotreating of the petroleum feed comprises one or more of hydrodesulfurization, hydrodenitrogenation, hydrodemetallization, isomerization, hydrogenation of olefins, and hydrocracking, to form a first reaction zone effluent; conducting the first reaction zone effluent to a second reaction zone; and in the second reaction zone hydrotreating a combination of the first reaction zone effluent and the renewable feed, wherein the hydrotreating of the combination comprises one or more of hydrodeoxygenation, decarboxylation, decarbonylation, isomerization and hydrogenation of olefins of the renewable feed, to form a second reaction zone effluent.
A method for performing a seismic survey of an earthen subterranean formation includes deploying a node patch including a plurality of seismic receivers to an offshore seabed in a survey area, deploying a surface vessel towing an array of seismic sources to the survey area located, and activating the array of seismic sources to generate seismic waves as the array of seismic sources are transported in an inline direction through the survey area whereby an imaging activation pattern and a velocity activation pattern are formed, wherein a lateral offset between the velocity activation pattern and the node patch is greater than a lateral offset between the imaging activation pattern and the node patch.
A method for analyzing a rock sample includes segmenting a digital image volume corresponding to an image of the rock sample, to associate voxels in the digital image volume with a plurality of rock fabrics of the rock sample. The method also includes performing image processing on the digital image volume to determine a material property of each of the rock fabrics and selecting, from a set of nomograms, a nomogram having an associated grid size. The selected nomogram associates the material property of each of the rock fabrics with a fractional bounceback parameter (FBP) value between a lower FBP threshold and an upper FBP threshold. The method further includes associating each voxel in the digital image volume with an FBP value based on the selected nomogram.
A method for analyzing a rock sample includes segmenting a digital image volume corresponding to an image of the rock sample, to associate voxels in the digital image volume with a plurality of rock fabrics of the rock sample. The method also includes identifying a set of digital planes through the digital image volume. The set of digital planes intersects with each of the plurality of rock fabrics. The method further includes machining the rock sample to expose physical faces that correspond to the identified digital planes, performing scanning electron microscope (SEM) imaging of the physical faces to generate two-dimensional (2D) SEM images of the physical faces, and performing image processing on the SEM images to determine a material property associated with each of the rock fabrics.
A method for analyzing a rock sample includes performing scanning electron microscope (SEM) imaging of a plurality of physical faces of a rock sample to generate two-dimensional (2D) SEM images of the physical faces, applying a cross-correlation function to a first 2D SEM image and a second 2D SEM image to generate a three-dimensional (3D) digital model volume based on the first and second 2D SEM images, and determining a probability distribution of a pore size of the 3D digital model volume based on an image intensity value of a pixel in each of the first and second 2D SEM images.
System and techniques to position a first source array at a fixed first inline distance from a vessel, position a second source array at a fixed second inline distance from a vessel, wherein the fixed second inline distance differs from the fixed first inline distance, generating a spatial coding, fire the first source array, and fire the second source array.
A method of performing single trace inversion to characterize changes in a subsurface region includes obtaining a base seismic trace and a monitor seismic trace of the subsurface region at different respective times. The method includes generating a predicted monitor seismic trace from the base seismic trace by a process including applying a time shift to the base seismic trace, the time shift being derived from estimated velocity perturbations occurring between the base seismic trace and the monitor seismic trace, compensating for amplitude changes between the base seismic trace and the monitor seismic trace, wherein the time shift is applied to the amplitude changes, and minimizing a difference between the predicted monitor seismic trace and the monitor seismic trace by iteratively estimating the velocity perturbations to obtain final estimated velocity perturbations. Changes of at least part of the subsurface region may be characterized using the final estimated velocity perturbations.
A method 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.
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 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 - Exécution de corrections statiques ou dynamiques sur des enregistrements, p.ex. correction de l'étalement; Etablissement d'une corrélation entre signaux sismiques; Elimination des effets produits par un excès d'énergie
G01V 1/38 - Séismologie; Prospection ou détection sismique ou acoustique spécialement adaptées aux zones recouvertes d'eau
14.
MACHINE LEARNING-BASED ANALYSIS OF SEISMIC ATTRIBUTES
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 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.
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 - Exécution de corrections statiques ou dynamiques sur des enregistrements, p.ex. correction de l'étalement; Etablissement d'une corrélation entre signaux sismiques; Elimination des effets produits par un excès d'énergie
A 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 measurements determined from A-scan spectra.
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 - Raffinage des huiles d'hydrocarbures, en l'absence d'hydrogène, par des méthodes non prévues ailleurs par traitement à l'eau
G01N 23/223 - Recherche ou analyse des matériaux par l'utilisation de rayonnement [ondes ou particules], p.ex. rayons X ou neutrons, non couvertes par les groupes , ou en mesurant l'émission secondaire de matériaux en irradiant l'échantillon avec des rayons X ou des rayons gamma et en mesurant la fluorescence X
21.
A METHOD OF PREDICTING THE CRITICAL SOLVENT POWER OF A VISBROKEN RESIDUE STREAM OF INTEREST
A method for predicting the critical solvent power of a visbroken residue stream of interest, CSPVisRes(OI) comprises predicting CSPVisRes(OI) from the critical percentage titrant of an atmospheric residue stream, CPTAR, the atmospheric residue stream being derived from the same crude oil as the visbroken residue stream of interest. A method for predicting the solvent power of a visbroken residue stream of interest, SPVisRes(OI), comprises predicting SPVisRes(OI) from the critical solvent power of the visbroken residue stream, CSPVisRes, and the critical percentage titrant of the visbroken residue stream, CPTVisRes. CPTVisRes is derived from the critical percentage cetane of the visbroken residue stream, CPCVisRes, 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 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.
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 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 31/08 - Raffinage des huiles d'hydrocarbures, en l'absence d'hydrogène, par des méthodes non prévues ailleurs par traitement à l'eau
C10G 17/00 - Raffinage des huiles d'hydrocarbures, en l'absence d'hydrogène, avec des acides, des composés libérant un acide ou des liquides contenant un acide, p.ex. avec une boue acide
C10G 21/06 - Raffinage des huiles d'hydrocarbures, en l'absence d'hydrogène, par extraction au moyen de solvants sélectifs caractérisé par le solvant utilisé
C10G 33/00 - Déshydratation ou désémulsification des huiles d'hydrocarbures
26.
CONDITIONING A SAMPLE TAKEN FROM A HYDROCARBON STREAM
A process for analysing a hydrocarbon stream comprises: withdrawing a hydrocarbon sample from a hydrocarbon stream (12); passing the hydrocarbon sample to an analysis device (16) at a target temperature of greater than 120 °C and a target flow rate of greater than 20 litres per minute; and returning the hydrocarbon sample to the hydrocarbon stream (12). The process may be used for the on-line analysis of crude oil, in order to optimise a refinery operation.
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 - Exécution de corrections statiques ou dynamiques sur des enregistrements, p.ex. correction de l'étalement; Etablissement d'une corrélation entre signaux sismiques; Elimination des effets produits par un excès d'énergie
A 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 method for screening a candidate for efficacy as an asphaltene stabilizer comprises: forming a reconstituted oil by dispersing an asphaltene-containing solid in a hydrocarbon fluid; adding an asphaltene stabilizer candidate to the reconstituted oil to give an additized oil; and analyzing the stability of the asphaltenes in the additized oil. The method may be used to select a candidate for use as an asphaltene stabilizer during crude oil production, transportation or processing.
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 29/22 - Recherche ou analyse des matériaux par l'emploi d'ondes ultrasonores, sonores ou infrasonores; Visualisation de l'intérieur d'objets par transmission d'ondes ultrasonores ou sonores à travers l'objet - Détails
F16J 15/08 - Joints d'étanchéité entre surfaces immobiles entre elles avec garniture solide comprimée entre les surfaces à joindre exclusivement par garniture métallique
F28F 9/18 - Dispositions pour obturer des éléments dans les boîtes de distribution ou plaques d'extrémité par joints permanents, p.ex. par dudgeonnage par soudage
G01N 29/26 - Dispositions pour l'orientation ou le balayage
G01N 29/265 - Dispositions pour l'orientation ou le balayage en déplaçant le capteur par rapport à un matériau fixe
G01N 29/28 - Recherche ou analyse des matériaux par l'emploi d'ondes ultrasonores, sonores ou infrasonores; Visualisation de l'intérieur d'objets par transmission d'ondes ultrasonores ou sonores à travers l'objet - Détails pour établir le couplage acoustique
A method for recalculating the solvent power of a light oil, SP(LO recalculated), is provided. The method comprises: titrating the light oil against a reference oil, optionally in the presence of a titrant, to determine a volume fraction of the light oil at the onset of asphaltene recipitation, V(onset fraction LO), a volume fraction of the reference oil at the onset of asphaltene precipitation, V(Onset fraction RO), and, where a titrant is present, a volume fraction of the titrant at the onset of asphaltene precipitation, V(Onset fraction RO), and determining the recalculated solvent power of the light oil, SP(LO recalculated), according to the following formula:(I) wherein: CSP(RO) is the critical solvent power of the reference oil, SP(RO) is the solvent power of the reference oil, SP(T) is the solvent power of the titrant, and 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.
A method for determining a relationship between the ratio of solvent power to critical solvent power and the threshold light paraffin content of a hydrocarbon fluid is provided. The method comprises: dividing the plurality of hydrocarbon fluids into subgroups, based on the ratio of solvent power to critical solvent power; for each of the subgroups, determining the threshold light paraffin content, said threshold light paraffin content being the light paraffin content of the hydrocarbon fluids at the point at which the fouling tendency of the hydrocarbon fluids exceeds a fouling threshold; and determining a relationship between the ratio of solvent power to critical solvent power and the threshold light paraffin content.
A method for optimizing a desalting process in which a hydrocarbon feedstock is passed to a desalter through a line under a set of conditions, the hydrocarbon feedstock containing a hydrocarbon fluid, water and a salt, said method comprising: obtaining spectra of the hydrocarbon feedstock under a plurality of environments in the line; comparing the spectra; and based on the comparison of the spectra, either modifying or maintaining the set of conditions under which the hydrocarbon feedstock is passed to the desalter; wherein the spectra are obtained using neutron backscattering.
C10G 31/08 - Raffinage des huiles d'hydrocarbures, en l'absence d'hydrogène, par des méthodes non prévues ailleurs par traitement à l'eau
C10G 32/04 - Raffinage des huiles d'hydrocarbures par des moyens électriques ou magnétiques, par irradiation ou par utilisation de micro-organismes par des radiations particulaires
G01N 23/204 - Recherche ou analyse des matériaux par l'utilisation de rayonnement [ondes ou particules], p.ex. rayons X ou neutrons, non couvertes par les groupes , ou en utilisant la réflexion de la radiation par les matériaux en mesurant la rétrodiffusion en utilisant des neutrons
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).
Methods and systems for estimating conductivity of clay mineral systems, and for applying the estimates in larger-scale analysis. Conductivity of the clay may be estimated by constructing a molecular model of an anhydrous charge-neutral clay, and then assigning a charge density by substitution of ions in the model of the clay structure. Counterions are inserted for charge neutrality, and water molecules are added to the model to reflect a selected level of hydration. Following assignment of force-field coefficients, molecular dynamics simulation provides data from which diffusion coefficients can be estimated. Application of the Nernst-Einstein relationship to the diffusion coefficients of the counterions provides the ion conductivity of the clay system. This conductivity can be used to derive a formation factor, and can be applied in direct numerical simulation analysis.
36.
ESTIMATION OF CONDUCTIVITY FOR NANOPOROUS MATERIALS
Methods and systems for estimating conductivity of clay mineral systems, and for applying the estimates in larger-scale analysis. Conductivity of the clay may be estimated by constructing a molecular model of an anhydrous charge-neutral clay, and then assigning a charge density by substitution of ions in the model of the clay structure. Counterions are inserted for charge neutrality, and water molecules are added to the model to reflect a selected level of hydration. Following assignment of force-field coefficients, molecular dynamics simulation provides data from which diffusion coefficients can be estimated. Application of the Nernst-Einstein relationship to the diffusion coefficients of the counterions provides the ion conductivity of the clay system. This conductivity can be used to derive a formation factor, and can be applied in direct numerical simulation analysis.
G01N 27/04 - Recherche ou analyse des matériaux par l'emploi de moyens électriques, électrochimiques ou magnétiques en recherchant l'impédance en recherchant la résistance
G01N 15/08 - Recherche de la perméabilité, du volume des pores ou de l'aire superficielle des matériaux poreux
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.
A technique for use in geophysical surveying includes imparting a plurality of humming seismic signals (620, 630) and a plurality of swept seismic signals (610) into a geological formation. The technique also includes receiving returned seismic energy of the plurality of humming seismic signals (620, 630) and the plurality of swept seismic signals (610) after interacting with the geological formation and recording the returned seismic energy.
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.
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.
A technique for use in geophysical surveying acquires seismic data at low seismic frequencies to generate better starting models for subsurface attributes rather than enhancing the bandwidth of airguns for broadband imaging as in conventional practice.
A method for use in vertical seismic profiling includes: independently shooting a plurality of seismic sources in a plurality of shooting areas to impart seismic signals into a water bottom where the sources are shot simultaneously within a common time window; receiving reflections of the seismic signals from a subterranean formation beneath the water bottom at a plurality of seismic receivers; and recording the received reflections; wherein the seismic receivers are disposed in a wellbore in the water bottom.
G01V 1/40 - Séismologie; Prospection ou détection sismique ou acoustique spécialement adaptées au carottage
G01V 1/42 - Séismologie; Prospection ou détection sismique ou acoustique spécialement adaptées au carottage en utilisant des générateurs dans un puits et des récepteurs dans un autre endroit ou vice versa
A method for use in seismic exploration comprises: accessing a set of seismic data representative of a subterranean geological formation and a subsurface attribute model of the subterranean geological formation; performing a wavefield extrapolation on the seismic data in the subsurface attribute model; applying the time-shift extended imaging condition to the extrapolated wavefields; forming shot-indexed, time shift gathers for each image pixel of the subsurface attribute model from the conditioned extrapolated wavefields; adaptively focusing the gathers; and stacking the adaptively focused gathers; and imaging the subterranean geological formation from the stacked, adaptively focused gathers. The method may, in some aspects, be realized by a computing apparatus programmed to perform the method or as a set of instructions encoded on a non-transitory program storage medium that, when executed by a computing apparatus, perform the method.
So-called "Popcorn shooting", and especially continuous Popcorn shooting, combined with simultaneous source shooting allows considerable flexibility in producing high-resolution data and in creating source arrays. Using a combination of simultaneous source de-blending and Popcorn reconstruction it is possible to construct using post acquisition processing arrays of any desired length by constructing a popcorn pattern that takes into account the vessel speed and physical arrangement of guns behind the towing vessel.
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.
A method for controlling trajectory in a resonant marine seismic source comprises: controlling the source frequency and controlling the motion trajectory. Controlling the source frequency includes: estimating the source frequency from its internal state and the state of its environment; deriving a frequency error as the difference between the estimated frequency and the frequency of the desired trajectory; and driving the frequency error to zero. Controlling the motion trajectory includes: detecting a motion trajectory of the source; deriving a motion trajectory error as the difference between the desired motion trajectory and detected motion trajectory; and driving the motion trajectory error to zero.
G01V 1/04 - Production d'énergie sismique - Détails
G01V 1/133 - Production d'énergie sismique en utilisant des fluides comme moyens d'entraînement hydrauliques, p.ex. en utilisant des fluides à haute pression
47.
ANALYTICALLY GENERATED SHOOTING SCHEDULES FOR USE WITH PATTERNED AND SIMULTANEOUS SOURCE ACQUISITION
According to an embodiment, there is provided a system and method of collecting seismic data using a predetermined pattern of source activations that is intended to control the properties of the resulting seismic signal. One embodiment utilizes a seismic source anay (or, more generally, any collection of controllable sources) to create a series of spaced apart in time source activations, with the spacing and number of such activations being used to shape the resulting signal. In one method of building sweeps, the guns are fired at an increasing rate (decreasing time separation) as time goes by. Other patterns may be generated by decreasing the firing rate as time goes by, or some combination of the foregoing. In an embodiment, the rate of the increase or decrease in the firing rate will change from pattern to pattern.
A sample preparation apparatus and method of preparing a rock sample using such an apparatus, as useful in connection with the digital numerical simulation of properties of the rock. The disclosed apparatus includes a fixably mounted diamond wire cutter. Three linear translation stages are coupled to a specimen holder. One of the translation stages moves the specimen in a direction parallel to the plane of the cutting wire. The other two translation stages move the specimen in different directions from one another, and when actuated together, advance the specimen into the wire for short distances in a direction out of the plane of the cutting wire. Short piecewise linear cuts are made in the specimen, to provide a sample of the desired shape with a small cross-section.
B23D 57/00 - Machines à scier ou dispositifs de sciage non couverts par l'un des groupes
B28D 5/04 - Travail mécanique des pierres fines, pierres précieuses, cristaux, p.ex. des matériaux pour semi-conducteurs; Appareillages ou dispositifs à cet effet par outils autres que ceux du type rotatif, p.ex. par des outils animés d'un mouvement alternatif
49.
SYSTEM AND METHOD FOR RESONATOR FREQUENCY CONTROL BY ACTIVE FEEDBACK
There is taught herein a system and method for creating an improved seismic source signal by applying a feedback mechanism, active adaptive control, to perturb a resonator device configuration on the fly so as to ensure that the overall trajectory of the sweep is correctly produced, even though the precise details of each oscillation of the source are still not constrained. An embodiment teaches a method for adjusting the squeeze piston or tow depth of a resonant piston seismic source to bring the resonant frequency to a desired value. As a consequence, the resulting seismic signal is improved as compared with seismic signals acquired via resonators that do not utilize the instant teachings.
G01V 1/00 - Séismologie; Prospection ou détection sismique ou acoustique
G01V 1/133 - Production d'énergie sismique en utilisant des fluides comme moyens d'entraînement hydrauliques, p.ex. en utilisant des fluides à haute pression
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.
The output spectrum of a controllable swept- frequency acoustic source at a given frequency can be controlled by making the rate of change of frequency equal to the desired output power spectrum divided by the squared envelope amplitude of the source output signal, both measured at the time after the start of its frequency sweep at which the sweep frequency passes through the given frequency. The system and method can also be used to correct for propagation effects outside the source by dividing the desired spectrum by the propagation effect. The method can further be used either to obtain an output spectrum of a desired shape from a source operating at maximum output or to design a sweep of a minimum feasible duration that will result in an output spectrum of a specified shape and with a specified amplitude.
G01V 1/00 - Séismologie; Prospection ou détection sismique ou acoustique
G01V 1/04 - Production d'énergie sismique - Détails
G01V 1/135 - Production d'énergie sismique en utilisant des fluides comme moyens d'entraînement hydrauliques, p.ex. en utilisant des fluides à haute pression déformant ou déplaçant des surfaces d'enceintes
G01V 1/38 - Séismologie; Prospection ou détection sismique ou acoustique spécialement adaptées aux zones recouvertes d'eau
52.
IMAGE-BASED DIRECT NUMERICAL SIMULATION OF PETROPHYSICAL PROPERTIES UNDER SIMULATED STRESS AND STRAIN CONDITIONS
A testing system for performing image based direct numerical simulation to characterize petrophysical properties of a rock sample under the simulated deformation condition, for example as representative of subsurface conditions. A digital image volume corresponding to x-ray tomographic images of a rock sample is segmented into its significant elastic phases, such as pore space, clay fraction, grain contacts and mineral type, and overlaid with an unstructured finite element mesh. A simulated deformation is applied to the segmented image volume, and the resulting deformed unstructured mesh is numerically analyzed, for example by way of direct numerical simulation, to determine the desired petrophysical properties.
One aspect of the invention is a method for building geologic / stratigraphic models of the earth for the purposes of numerical simulations of phenomena of interest, such as seismic wave propagation, or fluid flow, reservoir simulation, etc. An embodiment of the invention uses stochastic methods to create material property models that have desired statistical properties by numerically simulating deposition of geological layers. The method can create multiple material parameter models from numerical implementations of a variety of geological processes.
54.
SYSTEMS AND METHODS FOR IMPROVING DIRECT NUMERICAL SIMULATION OF MATERIAL PROPERTIES FROM ROCK SAMPLES AND DETERMINING UNCERTAINTY IN THE MATERIAL PROPERTIES
A testing system for analyzing a 3D digital volume of a material sample. The testing system defines several test volume sizes with each test volume size including a different numbers of voxels, defining the size of portions of the 3D digital volume to analyze. For each test volume size, the testing system acquires two adjacent portions of 3D digital volume at the test volume size currently being analyzed. The testing system calculates a material property value for the two adjacent portions of the 3D digital volume, and a difference value between the two adjacent portions of the 3D digital volume. The process is repeated over the different test volume sizes. The testing system calculates mean difference values for the different test volume sizes, from which it determines a representative elementary volume.
G01N 15/08 - Recherche de la perméabilité, du volume des pores ou de l'aire superficielle des matériaux poreux
G16C 60/00 - Science informatique des matériaux, c. à d. TIC spécialement adaptées à la recherche des propriétés physiques ou chimiques de matériaux ou de phénomènes associés à leur conception, synthèse, traitement, caractérisation ou utilisation
A method for mobilizing viscous hydrocarbons in a reservoir includes (a) injecting an aqueous solution into the reservoir with the reservoir at the reservoir ambient temperature. The aqueous solution includes water and a water-soluble chemical agent that is substantially non-decomposable and substantially non reactive in the reservoir at the reservoir ambient temperature. In addition, the method includes (b) adding thermal energy to the reservoir at any time after (a) to increase the temperature of at least a portion of the reservoir to an elevated temperature greater than the ambient temperature of the reservoir. Further, the method includes (c) in response to the elevated temperature in (b), mobilizing at least a portion of the hydrocarbons in the reservoir by reducing the viscosity of the hydrocarbons and allowing the chemical agent to enhance mobilization of the hydrocarbons.
There is provided herein a method of seismic acquisition that utilizes an arrangement of marine sources where each source is positioned at a water depth shallow enough for the surface ghost notch to fall at a frequency greater than or equal to the maximum radiated frequency of interest. If the marine seismic source has a ratio of signal bandwidth to maximum frequency that is less than one half, then it is possible to deploy it at a greater depth at which ghost notches fall below and above its frequency band but not in it. Further, by placing two or more sources at different depths for the same frequency, any undesired nulls in the radiation pattern caused by the deeper tow can be filled in.
A system and method for three-dimensional measurement of surfaces. In one embodiment, a measurement system includes a laser projector, a first camera, and a processor. The laser projector is configured to emit a laser projection onto a surface for laser triangulation. The first camera is configured to provide images of the surface, and is disposed at an oblique angle with respect to the laser projector. The processor is configured to apply photogrammetric processing to the images, to compute calibrations for laser triangulation based on a result of the photogrammetric processing, and to compute, based on the calibrations, coordinates of points of the surface illuminated by the laser projection via laser triangulation.
G01B 11/245 - Dispositions pour la mesure caractérisées par l'utilisation de techniques optiques pour mesurer des contours ou des courbes en utilisant plusieurs transducteurs fixes fonctionnant simultanément
G06T 7/521 - Récupération de la profondeur ou de la forme à partir de la projection de lumière structurée
G06T 7/80 - Analyse des images capturées pour déterminer les paramètres de caméra intrinsèques ou extrinsèques, c. à d. étalonnage de caméra
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.
C10B 41/00 - Dispositifs de sécurité, p.ex. dispositifs de signalisation ou de commande utilisés lors du défournement
C10B 55/00 - Cokéfaction des huiles minérales, bitumes, goudrons ou analogues, ou de leurs mélanges, avec des matières carbonées solides
G05B 19/042 - Commande à programme autre que la commande numérique, c.à d. dans des automatismes à séquence ou dans des automates à logique utilisant des processeurs numériques
59.
SYSTEMS AND METHODS FOR OPTIMAL STACKING OF SEISMIC DATA
Systems and methods include seismic data stacking derived from a set of image volumes. Stacking includes finding a sub-set of seismic image volumes (and in some implementations their respective stacking weights) or multiple realizations of sub-set of seismic image volumes from a given set that are consistent and similar to each other. Some or all of the input seismic image volumes can be stacked together as they would be with a conventional stack. However, the signal-to-noise ratio can be enhanced by only stacking those volumes that contain consistent and relevant information. Optimal stacking can utilize an algorithm that can be implemented in a moving window fashion.
There is provided herein a method of passive seismic acquisition that utilizes real time or near real time computation to reduce the volume of data that must be moved from the field to the processing center. Much of the computation that is traditionally applied to passive source data can be done in a streaming fashion. The raw data that passes through a field system can be processed in manageable pieces, after which the original data can be discarded and the intermediate results accumulated and periodically saved. These saved intermediate results are at least two, more likely three, orders of magnitude smaller than the raw data they are derived from. Such a volume of data is trivial to store, transport or transmit, allowing passive seismic acquisition to be practically used for continuous near-real-time seismic surveillance.
G01V 1/36 - Exécution de corrections statiques ou dynamiques sur des enregistrements, p.ex. correction de l'étalement; Etablissement d'une corrélation entre signaux sismiques; Elimination des effets produits par un excès d'énergie
G01V 1/22 - Transmission des signaux sismiques aux appareils d'enregistrement ou de traitement
G01V 1/28 - Traitement des données sismiques, p.ex. pour analyse, pour interprétation, pour correction
61.
SHOT SCHEDULING LIMITS FOR SEISMIC ACQUISITION WITH SIMULTANEOUS SOURCE SHOOTING
According to an embodiment of the instant invention there is provided a method for collecting a blended source seismic survey that utilizes new approach to determining; a random time separation between successive shots. The random time separation may be drawn in some embodiments from a distribution of uniformly distributed numbers, with t > 1/ (2 f), where t is the half-width of the uniform distribution and f is the lowest frequency of interest in the survey.
62.
CYCLONIC SEPARATORS AND METHODS FOR SEPARATING PARTICULATE MATTER AND SOLIDS FROM WELL FLUIDS
A downhole separator for separating solids from downhole well fluids comprises a cyclonic separation assembly. The assembly comprises a housing with at least one inlet port and an intake member disposed within the housing. The intake member includes a feed tube, a guide member disposed about the feed tube, and a vortex tube coaxially disposed within the feed tube. The assembly also comprises a cyclone body coaxially disposed within the housing and extending axially from the feed tube. In addition, the separator comprises an upper solids collection assembly coupled to the housing and configured to receive the separated solids from the cyclone body. Further, the separator comprises a lower solids collection assembly coupled to the housing and configured to receive the separated solids from the first solids collection assembly.
A new approach is disclosed for measuring the pressure of tight gas reservoirs, using information obtain from continuous injection prior to hydraulic fracture stimulation. The technique can be obtained utilizing either bottom-hole or surface pressure gauges and properly instrumented surface injection pumps. The analysis is completed by plotting injection and rate data in a specialized form from terms arranged in Darcy's radial flow equation to obtain a curve or trend. The key component to proper application of this technique is to obtain both baseline and one or more calibration data sets. These calibration data sets are obtained by either increasing or decreasing the injection pressure and / or rate from the baseline data. Initial reservoir pressure is assumed, but the calibration data indicates if the guess was too high or low. Accurate estimates of reservoir pressure may be obtained in a few iterations.
There is provided herein a system and method of seismic data collection for land and marine data that utilizes narrowband to monochromatic low-frequency non- impulsive sources designed to optimize the ability of migration / inversion algorithms to image the subsurface of the Earth, in particular, full-waveform inversion.
The maximum output of a seismic source array (110) may be reduced by activating the individual seismic sources (112) within these seismic source array in a pattern that is extended in time rather than by the presently employed conventional simultaneous activation of a large number of individual seismic sources. Methods are disclosed which take data shot with patterned sources and may use a sparse inversion method to create data with the about same image quality as that of conventional sources. In this manner the output of the maximum impulse of a seismic source array may be reduced by an amplitude factor of about 10 in the examples shown here, corresponding to a reduction of about 20 dB while maintaining virtually the same seismic image quality. The disclosed methods may be used in combination with any simultaneous sourcing technique. In addition, the disclosed methods may be used with a plurality of source arrays.
This is a method of separating simultaneous sources that uses an inversion-type approach. Each source will preferably activated at a random time with respect to the others. These random delays tend to make the interference between sources incoherent while the reflections create coherent events within a series of shots. The shot separation is performed via a numerical inversion process that utilizes the sweeps for each shot, the start times of each shot, and the coherence of reflection events between nearby shots. Implementation of this method will allow seismic surveys to be acquired faster and cheaper.
G01V 1/28 - Traitement des données sismiques, p.ex. pour analyse, pour interprétation, pour correction
G01V 1/00 - Séismologie; Prospection ou détection sismique ou acoustique
G01V 1/36 - Exécution de corrections statiques ou dynamiques sur des enregistrements, p.ex. correction de l'étalement; Etablissement d'une corrélation entre signaux sismiques; Elimination des effets produits par un excès d'énergie
A marine seismic source comprises a housing having a central axis, an open end, and a closed end opposite the open end, in addition, the source comprises a piston coaxially disposed within the housing, In addition, the source comprises a flywheel disposed within the housing and axially positioned between the closed end and the piston. The flywheel is configured to rotate about a rotational axis. Further, the source comprises a connecting rod moveably coupling the piston to the flywheel. The connecting rod has a first end pivotally coupled to the piston and a second end pivotally coupled to the flywheel. The second end of the connecting rod has a first position at a first distance measured radially from the rotational axis, and a second position at a second distance measured radially from the rotational axis. The first distance is less than the second distance.
A deliquification pump for deliquifying a well comprises a fluid end pump adapted to pump a fluid from a wellbore. In addition, the deliquification pump comprises a hydraulic pump adapted to drive the fluid end pump. The hydraulic pump includes a first internal pump chamber and a first pump assembly disposed in the first chamber. The first pump assembly includes a piston having a first end, a second end, and a throughbore extending between the first end and the second end. In addition, the first pump assembly includes a first wobble plate including a planar end face axially adjacent the second end of the piston and a slot extending axially through the first wobble plate. The first wobble plate is adapted to rotate about the central axis relative to the housing to axially reciprocate the piston and cyclically place the throughbore of the piston in fluid communication with the slot.
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
E21B 19/00 - Manipulation de tiges, tubages, tubes ou autre objets analogues à l'extérieur du trou de forage, p.ex. dans la tour de forage; Appareils pour faire avancer les tiges ou les câbles
E21B 19/08 - Appareils pour faire avancer les tiges ou les câbles; Appareils pour augmenter ou diminuer la pression sur l'outil de forage; Appareils pour compenser le poids des tiges
E21B 19/22 - Manipulation de tubes ou de tiges enroulés, p.ex. de tubes de forage flexibles
69.
MIGRATION-BASED ILLUMINATION DETERMINATION FOR AVA RISK ASSESSMENT
According to a preferred aspect of the instant invention, there is provided herein a system and method for extending zero-offset or stacked wave-equation illumination analysis into the angle-gather domain, where it becomes an appropriate tool for assessing the effects of complex overburden on AVA response. A preferred method for doing this involves first creating an angle gather that has a perfect AVA response (i.e. a constant amplitude as a function of angle). This gather is then preferably used as a reflectivity map that is fed into a demigration process which creates modeled data that by construction carries with it a completely flat reflectivity signature. Remigration of such a data set then results in a gather on which any amplitude variation is more likely to be a measure of illumination effects alone. The resulting AVA signature on the gather can then be used to assess the validity of the AVA response on modeled or actual data, resulting in a useful AVA risk analysis.
Methods and systems for drilling subsea wells bores (12) with dual - gradient mud systems include drilling the subsea well bore while employing a subsea pumping system (22), a subsea choke manifold (24) and one or more mud return risers (26) to implement the dual gradient mud system. When a well bore influx is detected, the well bore is shut in, and components determine if pressure control may be used to circulate the influx out of the well bore, the size of the influx, and how much the mud system weight will need to be reduced to match the dual gradient hydrostatic head before the influx reaches the subsea pump take point. The subsea pumping system, subsea choke manifold, and mud risers are isolated while the influx is circulated up one or more fluid passages in the drilling riser package (8) using the surface pump (18), through the wellhead (10), and out the surface choke manifold (20).
E21B 21/08 - Commande ou surveillance de la pression ou de l'écoulement du fluide de forage, p.ex. remplissage automatique des trous de forage, commande automatique de la pression au fond
Disclosed is a process for producing a hydrocarbon fraction rich in components boiling in the range typical for diesel fuel comprising contacting a feedstock comprising one or more C2 to C10 alkenes with a modified zeolite catalyst having a one-dimensional micropore structure consisting of channels made from rings containing between 8 and 12 silicon/aluminium atoms at a temperature in the range 100 to 5000C and pressure in the range 0.1 to 200 bar characterised in that the modified zeolite catalyst is one which has been prepared by treating a corresponding zeolite precursor with an alkaline solution. The alkaline solution used to treat the zeolite precursor can be for example aqueous sodium hydroxide solution. Relative to equivalent untreated zeolites the modified zeolite catalysts described show improved catalyst life and selectivity to hydrocarbons boiling in the range 250 to 3500C.
C10G 50/00 - Production de mélanges d'hydrocarbures liquides à partir d'hydrocarbures à nombre inférieur d'atomes de carbone, p.ex. par oligomérisation
B01J 29/70 - Zéolites aluminosilicates cristallines; Leurs composés isomorphes de types caractérisés par leur structure spécifique non prévus dans les groupes
72.
APPARATUS AND METHOD FOR A WIRELESS SENSOR TO MONITOR BARRIER SYSTEM INTEGRITY
This invention relates to an apparatus and a method for a wireless sensor to monitor barrier system integrity, such as used or employed during sequestration of greenhouse gases. This invention includes an apparatus for integrity monitoring of a borehole suitable for sequestration of greenhouse gases. The apparatus includes one or more sensors for placement outside of a casing to monitor a borehole, and a tool for movement within the casing to power and interrogate the one or more sensors. This invention also includes a method for monitoring integrity of a borehole suitable for sequestration of greenhouse gases or other types of well. The method includes the step of disposing one or more sensors outside a casing and the step of powering the one or more sensors with a tool inside the casing. The method also includes the step of interrogating the one or more sensors with the tool to monitor an engineered borehole and/or a natural caprock seal.
E21B 47/10 - Localisation des fuites, intrusions ou mouvements du fluide
E21B 47/12 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage
73.
METHOD FOR SEPARATING INDEPENDENT SIMULTANEOUS SOURCES
This is a method of separating simultaneous sources that uses an inversion-type approach. Each source will preferably activated at a random time with respect to the others. These random delays tend to make the interference between sources incoherent while the reflections create coherent events within a series of shots. The shot separation is performed via a numerical inversion process that utilizes the sweeps for each shot, the start times of each shot, and the coherence of reflection events between nearby shots. This method will allow seismic surveys to be acquired faster and cheaper.
G01V 1/28 - Traitement des données sismiques, p.ex. pour analyse, pour interprétation, pour correction
G01V 1/36 - Exécution de corrections statiques ou dynamiques sur des enregistrements, p.ex. correction de l'étalement; Etablissement d'une corrélation entre signaux sismiques; Elimination des effets produits par un excès d'énergie
74.
GLUCANASES, NUCLEIC ACIDS ENCODING THEM AND METHODS FOR MAKING AND USING THEM
The invention relates to polypeptides having glucanase, e.g., endoglucanase, mannanase, xylanase activity or a combination of these activities, and polynucleotides encoding them. In one aspect, the glucanase activity is an endoglucanase activity (e.g., endo-1,4-beta-D-glucan 4-glucano hydrolase activity) and comprises hydrolysis of 1,4-beta-D-glycosidic linkages in cellulose, cellulose derivatives (e.g., carboxy methyl cellulose and hydroxy ethyl cellulose) lichenin, beta- 1,4 bonds in mixed beta- 1,3 glucans, such as cereal beta-D-glucans or xyloglucans and other plant material containing cellulosic parts. In addition, methods of designing new enzymes and methods of use thereof are also provided. In alternative aspects, the new glucanases e.g., endoglucanases, mannanases, xylanases have increased activity and stability, including thermotolerance or thermostability, at increased or decreased pHs and temperatures.
A61K 38/47 - Hydrolases (3) agissant sur des composés glycosyliques (3.2), p.ex. cellulases, lactases
C07H 21/00 - Composés contenant au moins deux unités mononucléotide comportant chacune des groupes phosphate ou polyphosphate distincts liés aux radicaux saccharide des groupes nucléoside, p.ex. acides nucléiques
C07K 16/40 - Immunoglobulines, p.ex. anticorps monoclonaux ou polyclonaux contre des enzymes
C12N 9/24 - Hydrolases (3.) agissant sur les composés glycosyliques (3.2)
C12N 9/42 - Hydrolases (3.) agissant sur les composés glycosyliques (3.2) agissant sur les liaisons bêta-glucosidiques-1, 4, p.ex. cellulase
C12N 11/00 - Enzymes fixées sur un support ou immobilisées; Cellules microbiennes fixées sur un support ou immobilisées; Leur préparation
C12N 15/00 - Techniques de mutation ou génie génétique; ADN ou ARN concernant le génie génétique, vecteurs, p.ex. plasmides, ou leur isolement, leur préparation ou leur purification; Utilisation d'hôtes pour ceux-ci
C12N 15/11 - Fragments d'ADN ou d'ARN; Leurs formes modifiées
C12N 15/62 - Séquences d'ADN codant pour des protéines de fusion
C12N 15/63 - Introduction de matériel génétique étranger utilisant des vecteurs; Vecteurs; Utilisation d'hôtes pour ceux-ci; Régulation de l'expression
C12N 15/82 - Vecteurs ou systèmes d'expression spécialement adaptés aux hôtes eucaryotes pour cellules végétales
C12P 19/00 - Préparation de composés contenant des radicaux saccharide
C12Q 1/34 - Procédés de mesure ou de test faisant intervenir des enzymes, des acides nucléiques ou des micro-organismes; Compositions à cet effet; Procédés pour préparer ces compositions faisant intervenir une hydrolase
C40B 50/06 - Procédés biochimiques, p.ex. utilisant des enzymes ou des micro-organismes viables entiers
BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
BP CORPORATION NORTH AMERICA INC. (USA)
Inventeur(s)
Collins, Ian Ralph
Jerauld, Gary Russell
Lager, Arnaud
Mcguire, Patrick Lee
Webb, Kevin
Abrégé
Hydrocarbons are recovered from subterranean formations by waterflooding. The method comprises passing an aqueous displacement fluid via an injection well through a porous and permeable sandstone formation to release oil and recovering said released oil from a production well spaced from said injection well, wherein (a) the sandstone formation comprises at least one mineral having a negative zeta potential under the formation conditions; (b) oil and connate water are present in the pores of the formation; and (c) the fraction of the divalent cation content of the said aqueous displacement fluid to the divalent cation content of said connate water is less than 1.
E21B 43/16 - Procédés de récupération assistée pour l'extraction d'hydrocarbures
C09K 8/58 - Compositions pour les méthodes de récupération assistée pour l'extraction d'hydrocarbures, c. à d. pour améliorer la mobilité de l'huile, p.ex. fluides de déplacement
The invention relates to enzymes having xylanase, mannanase and/or glucanase activity, e.g., catalyzing hydrolysis of .beta.-xylosidic linkages or endo-.beta.-1,4- ghicanase linkages; and/or degrading a linear polysaccharide beta-1,4-xylan into xylose. Thus, the invention provides methods and processes for breaking down hemicellulose, which is a major component of the cell wall of plants, including methods and processes for hydrolyzing hemicelluloses in any plant or wood or wood product, wood waste, paper pulp, paper product or paper waste or byproduct. In addition, methods of designing new xylanases, mannanases and/or glucanases and methods of use thereof are also provided. The xylanases, mannanases and/or glucanases have increased activity and stability at increased pll and temperature.
A21D 13/062 - Produits à valeur nutritive modifiée, p.ex. à teneur en amidon modifiée à teneur en sucre modifiée; Produits sans sucre
A01H 5/00 - Angiospermes, c. à d. plantes à fleurs, caractérisées par leurs parties végétales; Angiospermes caractérisées autrement que par leur taxonomie botanique
A61K 38/47 - Hydrolases (3) agissant sur des composés glycosyliques (3.2), p.ex. cellulases, lactases
A61L 12/14 - Procédés ou appareils pour la désinfection ou la stérilisation des lentilles de contact; Accessoires à cet effet utilisant des substances chimiques des composés organiques non couverts par les groupes ou
C12N 9/00 - Enzymes, p.ex. ligases (6.); Proenzymes; Compositions les contenant; Procédés pour préparer, activer, inhiber, séparer ou purifier des enzymes
C12N 9/24 - Hydrolases (3.) agissant sur les composés glycosyliques (3.2)
C12N 9/96 - Stabilisation d'une enzyme par formation d'un adduct ou d'une composition; Formation de conjugaisons d'enzymes
C12N 9/98 - Préparation de compositions contenant des enzymes sous forme de granulés ou de matériaux solides fluides
C12N 11/00 - Enzymes fixées sur un support ou immobilisées; Cellules microbiennes fixées sur un support ou immobilisées; Leur préparation
C12N 15/56 - Hydrolases (3) agissant sur les composés glycosyliques (3.2), p.ex. amylase, galactosidase, lysozyme
C12N 15/63 - Introduction de matériel génétique étranger utilisant des vecteurs; Vecteurs; Utilisation d'hôtes pour ceux-ci; Régulation de l'expression
C12N 15/82 - Vecteurs ou systèmes d'expression spécialement adaptés aux hôtes eucaryotes pour cellules végétales
C12Q 1/34 - Procédés de mesure ou de test faisant intervenir des enzymes, des acides nucléiques ou des micro-organismes; Compositions à cet effet; Procédés pour préparer ces compositions faisant intervenir une hydrolase
C40B 50/06 - Procédés biochimiques, p.ex. utilisant des enzymes ou des micro-organismes viables entiers
G01N 33/573 - Tests immunologiques; Tests faisant intervenir la formation de liaisons biospécifiques; Matériaux à cet effet pour enzymes ou isoenzymes
77.
XYLANASES, NUCLEIC ACIDS ENCODING THEM AND METHODS FOR MAKING AND USING THEM
The invention relates to enzymes having xylanase, mannanase and/or glucanase activity, e.g., catalyzing hydrolysis of internal .beta.-l,4-xylosidic linkages or endo- .beta.-1,4- ghicanase linkages; and/or degrading a linear polysaccharide beta-l ,4-xylan into xylose. Thus, the invention provides methods and processes for breaking down hemicellulose, which is a major component of the cell wall of plants, including methods and processes for hydrolyzing hemicelluloses in any plant or wood or wood product, wood waste, paper pulp, paper product or paper waste or byproduct. In addition, methods of designing new xylanases, mannanases and/or glucanases and methods of use thereof are also provided. The xylanases, mannanases and/or glucanases have increased activity and stability at increased pH and temperature.
A61L 12/14 - Procédés ou appareils pour la désinfection ou la stérilisation des lentilles de contact; Accessoires à cet effet utilisant des substances chimiques des composés organiques non couverts par les groupes ou
C02F 3/00 - Traitement biologique de l'eau, des eaux résiduaires ou des eaux d'égout
C07H 21/04 - Composés contenant au moins deux unités mononucléotide comportant chacune des groupes phosphate ou polyphosphate distincts liés aux radicaux saccharide des groupes nucléoside, p.ex. acides nucléiques avec le désoxyribosyle comme radical saccharide
C07K 16/40 - Immunoglobulines, p.ex. anticorps monoclonaux ou polyclonaux contre des enzymes
C12N 9/24 - Hydrolases (3.) agissant sur les composés glycosyliques (3.2)
C12N 9/42 - Hydrolases (3.) agissant sur les composés glycosyliques (3.2) agissant sur les liaisons bêta-glucosidiques-1, 4, p.ex. cellulase
C12N 11/00 - Enzymes fixées sur un support ou immobilisées; Cellules microbiennes fixées sur un support ou immobilisées; Leur préparation
C12N 15/00 - Techniques de mutation ou génie génétique; ADN ou ARN concernant le génie génétique, vecteurs, p.ex. plasmides, ou leur isolement, leur préparation ou leur purification; Utilisation d'hôtes pour ceux-ci
C12N 15/11 - Fragments d'ADN ou d'ARN; Leurs formes modifiées
C12N 15/63 - Introduction de matériel génétique étranger utilisant des vecteurs; Vecteurs; Utilisation d'hôtes pour ceux-ci; Régulation de l'expression
C12P 7/10 - Ethanol en tant que produit chimique et non en tant que boisson alcoolique préparé comme sous-produit, ou préparé à partir d'un substrat constitué par des déchets ou par des matières cellulosiques d'un substrat constitué par des matières cellulosiques
C12P 19/00 - Préparation de composés contenant des radicaux saccharide
C12P 19/14 - Préparation de composés contenant des radicaux saccharide préparés par action d'une carbohydrase, p.ex. par action de l'alpha-amylase
C12Q 1/34 - Procédés de mesure ou de test faisant intervenir des enzymes, des acides nucléiques ou des micro-organismes; Compositions à cet effet; Procédés pour préparer ces compositions faisant intervenir une hydrolase
C40B 40/08 - Bibliothèques comprenant de l'ARN ou de l'ADN codant des protéines, p.ex. bibliothèques de gènes
C40B 40/10 - Bibliothèques comprenant des peptides ou des polypeptides ou leurs dérivés
C40B 50/06 - Procédés biochimiques, p.ex. utilisant des enzymes ou des micro-organismes viables entiers
A method for the detection of a fluid leak from a plugged well extending from a surface of the earth to penetrate a subterranean formation which contains fluid by logging a collection chamber positioned in the plugged well.
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