BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
Inventeur(s)
Manning, Ted
Stone, Johnathan
Abrégé
An offshore node deployment system includes a control system, a surface vessel including a deck, and a propulsion system in signal communication with the control system, a node storage container supported by the deck of the surface vessel, wherein the node storage container is configured to store a plurality of nodes which are physically disconnected from each other, and a node deployment system supported by the deck of the surface vessel and controllable by the control system, wherein the node deployment system is configured to retrieve the nodes from the node storage container and deploy the nodes to a subsea location.
B63B 27/22 - Aménagement des équipements de bord pour l'embarquement ou le débarquement des cargaisons ou des passagers des convoyeurs, p.ex. à courroie sans fin ou du type à vis
BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
Inventeur(s)
Crosby, Alistair George
Abrégé
In some examples, the disclosure provides a method for determining a drift in clock data that is provided by a clock of a seismic sensor. The sensor is exposed to an ambient temperature that varies over time. The method includes obtaining temperature data associated with the ambient temperature as a function of time. The method also includes obtaining the clock data. The method also includes obtaining timestamp data provided by a global navigation satellite system. The method also includes determining drift data which minimizes a difference of a temporal drift in the clock data, based on the timestamp data and the temperature data. The method also includes outputting corrective data based on the determined drift data.
BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
Inventeur(s)
Couves, John William
Day, Stuart William
Gibson, Chris
Rashid, Bilal
Williams, John Dale
Abrégé
An integrated system comprising a desalination plant comprising a reverse osmosis (RO) array configured to produce an RO permeate blending stream, a blending system comprising a flow line for a fines stabilizing additive blending stream and configured to blend the RO permeate blending stream with the fines stabilizing additive blending stream to produce a blended low salinity water stream having a salinity of less than or equal to 5,000, 4,000, 3,000, 2,000, 1,000, 500, 400, or 300 ppm and a molar ratio of divalent cations to monovalent cations of greater than about 0.2, 0.3, or 0.4, a control unit configured to control operation of the blending system, and an injection system for one or more injection wells, wherein the one or more injection wells penetrate an oil-bearing layer of a reservoir. A method is also provided.
BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
Inventeur(s)
Ourabah, Amine
Abrégé
In some examples, the disclosure provides a method for deploying a plurality N of seismic sensors, wherein each seismic sensor is adapted to measure seismic energy with at least one gain, within a survey area, the method comprising: obtaining a plurality M of gains from which the at least one gain may be selected; configuring the plurality N of seismic sensors such that, for each given gain of the obtained plurality M of gains, at least N/M seismic sensors are adapted to measure the seismic energy with at least one corresponding gain; and deploying the plurality N of configured seismic sensors on the survey area.
BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
LYTT LIMITED (Royaume‑Uni)
Inventeur(s)
Thiruvenkatanathan, Pradyumna
Abrégé
A method of identifying events includes obtaining an acoustic signal from a sensor, determining one or more frequency domain features from the acoustic signal, providing the one or more frequency domain features as inputs to a plurality of event detection models, and determining the presence of one or more events using the plurality of event detection models. The one or more frequency domain features are obtained across a frequency range of the acoustic signal, and at least two of the plurality of event detection models are different.
G01H 17/00 - Mesure des vibrations mécaniques ou des ondes ultrasonores, sonores ou infrasonores non prévue dans les autres groupes de la présente sous-classe
E21B 47/135 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage par énergie électromagnétique, p.ex. gammes de fréquence radio utilisant des ondes lumineuses, p.ex. ondes infrarouges ou ultraviolettes
E21B 47/10 - Localisation des fuites, intrusions ou mouvements du fluide
E21B 47/14 - 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 utilisant des ondes acoustiques
6.
DAS DATA PROCESSING TO IDENTIFY FLUID INFLOW LOCATIONS AND FLUID TYPE
BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
Inventeur(s)
Thiruvenkatanathan, Pradyumna
Abrégé
A method of identifying inflow locations along a wellbore comprises obtaining an acoustic signal from a sensor within the wellbore, determining a plurality of frequency domain features from the acoustic signal, and identifying, using a plurality of fluid flow models, a presence of at least one of a gas phase inflow, an aqueous phase inflow, or a hydrocarbon liquid phase inflow at one or more fluid flow locations. The acoustic signal comprises acoustic samples across a portion of a depth of the wellbore, and the plurality of frequency domain features are obtained across a plurality of depth intervals within the portion of the depth of the wellbore. Each fluid flow model of the plurality of fluid inflow models uses one or more frequency domain features of the plurality of the frequency domain features, and at least two of the plurality of fluid flow models are different.
E21B 47/10 - Localisation des fuites, intrusions ou mouvements du fluide
E21B 47/135 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage par énergie électromagnétique, p.ex. gammes de fréquence radio utilisant des ondes lumineuses, p.ex. ondes infrarouges ou ultraviolettes
E21B 41/00 - Matériel ou accessoires non couverts par les groupes
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
7.
SYSTEMS AND METHODS FOR SUPPLYING LOW SALINITY INJECTION WATER
BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
Inventeur(s)
Crouch, John Henry
Williams, John Dale
Abrégé
A desalination system includes a desalination platform, a first skid disposed on a first deck of the desalination platform, the first skid including at least one of a first filtration unit configured to produce a first filtrate stream, and a first permeate unit configured to produce a first permeate stream, a first interconnecting pipework coupled to the first skid, and a first pipework support disposed on the first deck, wherein the first interconnecting pipework is disposed on the first pipework support.
BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
Inventeur(s)
Song, Zhongmin
Zheng, York
Abrégé
A virtual seismic shot record is generated based at least in part on seismic interferometry of the passive seismic data. Then, a frequency bandwidth of the virtual seismic shot record is determined, wherein the frequency bandwidth comprises a plurality of frequencies. The virtual seismic shot record is transformed into a frequency- dependent seismic shot record based on a first frequency of the plurality of frequencies. Further, a phase shift is applied to the frequency-dependent seismic shot record. A first velocity model is generated from the phase shifted frequency-dependent seismic shot record. A second velocity model may be generated using full-waveform inversion (FWI). One or more depth slices are identified from the second velocity model. A seismic image is generated based on the one or more depth slices for use with seismic exploration above a region of subsurface including a hydrocarbon reservoir and containing structural features conducive to a presence, migration, or accumulation of hydrocarbons.
BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
Inventeur(s)
Crouch, John Henry
Abrégé
A control system configured to control operation of reverse osmosis (RO) array(s), nanofiltration (NF) array(s) and/or a blending system including a control panel (CP), regulatory controllers (RCs), and a supervisory controller (SC), wherein the SC is in signal communication with the CP, and with the RCs, wherein the SC is configured to: receive user inputs from the CP, and receive inputs from RCs regarding data from sensors, wherein the RCs are in signal communication with the plurality of sensors, wherein the RCs are configured to: receive data from the sensors, provide outputs to and receive permissions from the SC, and instruct devices in response to the received permissions from the SC, and wherein the SC is configured to: monitor trends in the inputs regarding and/or predict outcomes from data received from the RCs and determine the permissions for RCs based on the monitored trends and/or user inputs from the CP.
BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
Inventeur(s)
Cunningham, George Leslie
Abrégé
A predictive system for monitoring fouling of membranes of a desalination or water softening plant comprising ultrafiltration (UF) membranes, reverse osmosis (RO) membranes, and/or nanofiltration (NF) membranes, the system including one or more UF skids comprising a plurality of UF units, each UF unit containing therein a plurality of UF membranes; one or more RO/NF skids comprising one or more RO/NF arrays, wherein each of the one or more RO/NF arrays comprises a plurality of RO units, with each RO unit containing therein a plurality of RO membranes, a plurality of NF units, with each NF unit containing therein a plurality of NF membranes; or a combination thereof; UF sensors and/or RO/NF sensors; and a controller comprising a processor in signal communication with the UF sensors and/or the RO/NF sensors.
BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
Inventeur(s)
Day, Stuart
Mair, Christopher
Abrégé
A method of dynamically allocating a total amount of produced water (PW) from a reservoir during enhanced oil recovery (EOR) via a low salinity or softened water EOR floodby receiving measurement data; receiving reservoir configuration information comprising: an EOR injection rate associated with one or more EOR injection zones, a disposal zone injection rate associated with one or more disposal injection zones, and a non-reinjection disposal rate associated with one or more non-reinjection disposal routes; determining a blending rate comprising at least a portion of the PW production rate and at least a portion of the low salinity or softened water injection rate to provide a blended injection fluid; blending at least a portion of the PW with at least a portion of the low salinity or softened water at the blending rate; and dynamically allocating the PW production rate among injection and/or non-reinjection routes.
BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
Inventeur(s)
Lakshtanov, Dmitry
Abrégé
Embodiments relate generally to methods for extracting a core (114) from a percussion side wall core bullet (100) for a digital tomographic description and direct numerical simulations. A method for extracting a core (114) from a percussion side wall core bullet (100) for a digital tomographic description and direct numerical simulations includes pushing a free end (112) of a wire (110) of a wire saw (108) through the core (114). The core (114) is positioned within the percussion side wall core bullet (100). In addition, the method includes attaching the free end (112) to a locking mechanism (113) of the wire saw (108). Further, the method includes cutting the core (114) from the percussion side wall core bullet (100). The method also includes removing the core (114) from the percussion side wall core bullet (100).
E21B 25/00 - Appareils pour recueillir ou retirer des carottes intactes, p.ex. tubes carottiers, extracteurs de carottes
B23D 49/00 - Machines à scier ou dispositifs de sciage à lames animées d'un mouvement rectiligne alternatif
B28D 1/00 - Travail de la pierre ou des matériaux analogues p.ex. briques, béton, non prévu ailleurs; Machines, dispositifs, outils à cet effet
E21B 49/04 - Test pour déterminer la nature des parois des trous de forage; Essais de couches; Procédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits par prélèvements mécaniques d'échantillons du terrain au moyen de projectiles pénétrant dans la paroi
E21B 49/06 - Test pour déterminer la nature des parois des trous de forage; Essais de couches; Procédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits par prélèvements mécaniques d'échantillons du terrain au moyen d'outils de forage latéral ou de dispositifs de raclage
13.
DETECTING EVENTS USING ACOUSTIC FREQUENCY DOMAIN FEATURES
BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
Inventeur(s)
Langnes, Tommy
Thiruvenkatanathan, Pradyumna
Abrégé
A system for processing acoustic data to identify an event comprises a receiver unit comprising a processor (168) and a memory (170), where the receiver unit is configured to receive a signal from a sensor (164) disposed along a sensor path or across a sensor area, wherein a processing application is stored in the memory. The processing application, when executed on the processor, configures the processor to: receive the signal from the sensor (164), where the signal comprises an indication of an acoustic signal received at one or more lengths along the sensor path or across a portion of the sensor area, wherein the signal is indicative of the acoustic signal across a frequency spectrum; determine a plurality of frequency domain features of the signal across the frequency spectrum; and generate an output comprising the plurality of frequency domain features.
BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
Inventeur(s)
Langnes, Tommy
Thiruvenkatanathan, Pradyumna
Abrégé
A method of detecting sand ingress within a wellbore includes obtaining a sample data set, determining a plurality of frequency domain features of the sample data set over a plurality of depth ranges, determining a presence of sand ingress at a first depth range of the plurality of depth ranges within the wellbore based on determining that the plurality of frequency domain features over the first depth range match a sand ingress signature, and determining a presence of sand migration along a second depth range of the plurality of depths within the wellbore based on determining that the plurality of frequency domain features over the second depth range match a sand migration signature. The sample data set is a sample of an acoustic signal originating within a wellbore comprising a fluid, and wherein the sample data set is representative of the acoustic signal across a frequency spectrum.
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
E21B 47/00 - Relevés dans les trous de forage ou dans les puits
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
15.
WELL AND OVERBURDEN MONITORING USING DISTRIBUTED ACOUSTIC SENSORS
BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
Inventeur(s)
Thiruvenkatanathan, Pradyumna
Langnes, Tommy
Abrégé
A method of detecting a leak event within a wellbore can include inducing a pressure differential within a wellbore comprising a fluid, obtaining a sample data set representative of the acoustic signal across a frequency spectrum while inducing the pressure differential, determining a plurality of frequency domain features of the sample data set, determining a presence of a leak event at one or more depths within the wellbore based on determining that the plurality of frequency domain features match a leak event signature, correlating the leak event with the induced pressure differential, and determining a presence and location of a leak within the wellbore based on the presence of the leak event and the correlating of the leak event with the induced pressure differential.
BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
Inventeur(s)
Couves, John William
Krawiec, Piotr
Rashid, Bilal
Totton, Timothy Stephen
Abrégé
A method for recovering crude oil from a reservoir comprising at least one layer of reservoir rock having crude oil and a formation water within the pore space thereof wherein the layer(s) of reservoir rock is penetrated by at least one injection well and at least one production well, the method comprising: injecting into the layer(s) of reservoir rock from the injection well, alternating slugs of an aqueous displacement fluid comprising a concentrated solution of a water-soluble additive in an aqueous solvent and of an aqueous spacer fluid characterized in that: (a) the number of injected slugs of aqueous displacement fluid, n, is in the range of 15 to 1000 per swept pore volume, PVR, of the layer(s) of reservoir rock; (b) the injected pore volume of each individual slug, PVSlug-i, of aqueous displacement fluid is in the range of 10-12 to 10-2 of the swept pore volume, PVR, of the layer(s) of reservoir rock; (c) the total injected pore volume of the slugs of aqueous displacement fluid is in the range of 10-8 to 10-1 of the swept pore volume, PVR, of the layer(s) of reservoir rock; (d) the injected pore volume of each individual slug of aqueous spacer fluid, PVSpacer-i, is in the range of 0.0001 to 0.1000 of the swept pore volume, PVR, of the layer(s) of reservoir rock; (e) the total injected pore volume of the slugs of aqueous spacer fluid is in the range of 0.9000000 to 0.9999999 of the swept pore volume, PVR, of the layer(s) of reservoir rock; (f) the reservoir rock has a dispersivity, a, in the range of 1 to 30% of the interwell distance between the injection well and production well; (g) the amount of additive delivered to the layer(s) of reservoir rock by the plurality of slugs of aqueous displacement fluid is equal to or greater than a predetermined minimum additive quantity (MAQ).
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
17.
METHODS AND SYSTEMS FOR DRILLING BOREHOLES IN EARTH FORMATIONS
BP EXPLORATON OPERATING COMPANY LIMITED (Royaume‑Uni)
Inventeur(s)
Curry, David A.
Pessier, Rudolf Carl
Spencer, Reed W.
Kuesters, Andrew
Wingate, John
Abrégé
Methods of drilling earth formations may involve removing a portion of an underlying earth formation utilizing cutting elements of an earth-boring drill bit. A rotational speed of the drill string may be sensed utilizing a first sensor. A rate of penetration of the drill string during advancement of the earth-boring drill bit may be sensed utilizing a second sensor. An instantaneous average depth of cut of cutting elements of the earth-boring drill bit may be determined utilizing a control unit to calculate the instantaneous average depth of cut based on a sensed rotational speed of the drill string and a sensed speed of advancement of the drill string. The weight on the earth-boring drill bit may be increased utilizing the drawworks when the instantaneous average depth of cut is less than the predetermined minimum depth of cut.
E21B 44/00 - Systèmes de commande automatique spécialement adaptés aux opérations de forage, c. à d. systèmes à fonctionnement autonome ayant pour rôle d'exécuter ou de modifier une opération de forage sans l'intervention d'un opérateur humain, p.ex. systèmes de ; Systèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
Inventeur(s)
Bouska, John Gerard
Ourabah, Amine
Wye, Robin Roy
Abrégé
A system and method for acquiring and processing seismic data. A method for processing seismic data, includes receiving, by a seismic data processing system, signals representing seismic data recorded at a remote location; receiving, by the seismic data processing system, in conjunction with the signals, identification of a sensor via which the signals were acquired; retrieving, by the seismic data processing system, a sensor transfer function that corresponds to the sensor and relates the motion of the sensor to the signals; generating, by the seismic data processing system, based on the sensor transfer function and a reference transfer function, an inverse filter that when applied to the signals changes parameters of the signals to correspond to the reference transfer function; and applying, by the seismic data processing system, the inverse filter to the signals to conform the parameters of the signals to the reference transfer function.
G01V 1/16 - Séismologie; Prospection ou détection sismique ou acoustique Éléments récepteurs de signaux sismiques; Aménagements ou adaptations des éléments récepteurs
G01V 13/00 - Fabrication, étalonnage, nettoyage ou réparation des instruments ou dispositifs couverts par les groupes
19.
DETECTING DOWNHOLE EVENTS USING ACOUSTIC FREQUENCY DOMAIN FEATURES
BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
Inventeur(s)
Langnes, Tommy
Thiruvenkatanathan, Pradyumna
Abrégé
A method of detecting an event within a wellbore includes obtaining a sample data set, determining a plurality of frequency domain features of the sample data set, comparing the plurality of frequency domain features with an event signature, determining that the plurality of frequency domain features matches the thresholds, ranges, or both of the event signature, and determining the presence of the event within the wellbore based on determining that the plurality of frequency domain features match the thresholds, ranges, or both of the event signature. The sample data set is a sample of an acoustic signal originating within a wellbore comprising a fluid, and the sample data set is representative of the acoustic signal across a frequency spectrum. The event signature comprises a plurality of thresholds, ranges, or both corresponding to the plurality of frequency domain features.
BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
Inventeur(s)
Jerauld, Gary Russell
Mohammadi, Hourshad
Abrégé
A method of recovering oil from a subterranean oil-bearing reservoir uses an injection fluid comprising a viscosifying polymer in a low salinity water. The reservoir is penetrated by one or more injection wells and by one or more production wells. The method comprises injecting the injection fluid into at least one of the injection wells in a slug size in the range of 0.4 to 1.5 pore volumes (PV).
C09K 8/588 - Compositions pour les méthodes de récupération assistée pour l'extraction d'hydrocarbures, c. à d. pour améliorer la mobilité de l'huile, p.ex. fluides de déplacement caractérisées par l'utilisation de polymères spécifiques
E21B 43/16 - Procédés de récupération assistée pour l'extraction d'hydrocarbures
BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
Inventeur(s)
Brodie, James Andrew
Jerauld, Gary Russell
Abrégé
Methods, apparatuses and computer readable instructions for determining the effectiveness of, and for performing, a low salinity waterflood. An ion diffusion distance value is determined based on the rate of diffusion of ions within the rock of a reservoir and the residency time of floodwater within the reservoir. The thickness of the layers of the reservoir are compared to this ion diffusion value to determine the effectiveness of performing a low salinity waterflood and also to enable the effective control of a waterflood and to assist in the determination of locations of wells.
BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
Inventeur(s)
Harper, Mark
Dellinger, Joseph A.
Thompson, Martin
Openshaw, Graham
Abrégé
A marine seismic source comprises a housing (201) having a central axis (205), an open end (201a), and a closed end opposite the open end (201b). In addition, the seismic source includes a piston (210) extending coaxially through the open end of the housing. The piston is adapted to axially reciprocate relative to the housing. Further, the piston has a first end (210a) distal the housing and a second end (210b) disposed within the housing.
BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
Inventeur(s)
Harper, Mark
Dellinger, Joseph A.
Thompson, Martin
Openshaw, Graham
Abrégé
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 seismic source includes a piston extending coaxially through the open end of the housing. The piston is adapted to axially reciprocate relative to the housing. Further, the piston has a first end distal the housing and a second end disposed within the housing.
BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
Inventeur(s)
Williams, John Dale
Abrégé
A process of producing an injection water stream of controlled salinity and controlled sulfate anion content that is suitable for injection into an oil bearing formation of an oil reservoir, the process comprising the steps of: (a) feeding a source water having a total dissolved solids content in the range of 20,000 to 45,000 ppm and a sulfate anion concentration in the range of 1,000 to 4,000 ppm, preferably, 1,500 ppm to 4,000 ppm to a desalination plant that comprises a plurality of reverse osmosis (RO) membrane units and a plurality of nanofiltration (NF) membrane units wherein the source water is pressurised to a pressure in the range of 350 to 1250 psi absolute, and dividing the source water to provide a feed water for the RO membrane units (hereinafter "RO feed water") and a feed water for the NF membrane units (hereinafter "NF feed water"); (b) if necessary, increasing the pressure of the RO feed water to a value in the range of 900 to 1250 psi absolute before introducing the RO feed water to the RO membrane units and withdrawing an RO permeate and an RO retentate from the RO membrane units wherein the RO membrane units are operated in either a single-pass, single-stage mode or in a single-pass, two-stage mode and wherein the recovery of RO permeate is in the range of (35) to 75% by volume, preferably, 35 to 60% by volume based on the volume of the RO feed water that is fed to the RO membrane units such that the RO permeate has a total dissolved solids contents of less than 250 ppm, and a sulfate anion concentration of less than 3 ppm; (c) if necessary, reducing the pressure of the NF feed water to a value in the range of 350 to 450 psi absolute before introducing the NF feed water to the NF membrane units and withdrawing an NF permeate and an NF retentate from the NF membrane units wherein the NF membrane units are operated in a single-pass, single-stage mode and wherein the NF membrane units are operated with a recovery of NF permeate in the range of 35 to 60% by volume based on the volume of the NF feed water that is fed to the NF membrane units such that the NF permeate has a total dissolved solids content in the range of 15,000 to 40,000 ppm, preferably, 15,000 to 35,000 ppm, and a sulfate anion concentration of less than 40 ppm, preferably less than 30 ppm; and (d) mixing at least a portion of the RO permeate and at least a portion of the NF permeate in a ratio in the range of 2: 1 to 40: 1, preferably, 4: 1 to 27:1, in particular, 10: 1 to 25: 1 to provide an injection water having a total dissolved solids content in the range of 500 to 5,000 ppm, and a sulfate anion concentration of less than 7.5 ppm, preferably, less than (5) ppm, more preferably less than 3 ppm.
BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
Inventeur(s)
Chen, Quan
Collins, Ian Ralph
Abrégé
A method of comparing a secondary oil recovery process with a tertiary oil recovery process, the secondary oil recovery process and the tertiary oil recovery process being applied to a substantially fluid-saturated porous medium containing an oil phase and an aqueous phase, the method comprising using relaxation time measurements in the calculation of a wettability index modification factor for the oil phase or the aqueous phase, thereby comparing the tertiary oil recovery process with the secondary oil recovery process.
G01N 13/00 - Recherche des effets de surface ou de couche limite, p.ex. pouvoir mouillant; Recherche des effets de diffusion; Analyse des matériaux en déterminant les effets superficiels, limites ou de diffusion
G01N 24/08 - Recherche ou analyse des matériaux par l'utilisation de la résonance magnétique nucléaire, de la résonance paramagnétique électronique ou d'autres effets de spin en utilisant la résonance magnétique nucléaire
BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
Inventeur(s)
Chen, Quan
Collins, Ian Ralph
Abrégé
A method of comparing a secondary oil recovery process with a tertiary oil recovery process, the secondary oil recovery process and the tertiary oil recovery process being applied to a substantially fluid- saturated porous medium containing an oil phase and an aqueous phase, the method comprising using relaxation time measurements in the calculation of a wettability index modification factor for the oil phase or the aqueous phase, thereby comparing the tertiary oil recovery process with the secondary oil recovery process.
G01V 3/32 - Prospection ou détection électrique ou magnétique; Mesure des caractéristiques du champ magnétique de la terre, p.ex. de la déclinaison ou de la déviation spécialement adaptée au carottage fonctionnant par résonance magnétique électronique ou nucléaire
27.
METHOD AND SYSTEM FOR CONFIGURING CRUDE OIL DISPLACEMENT SYSTEM
BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
Inventeur(s)
Collins, Ian Ralph
Houston, Stephanie Jane
Webb, Kevin John
Abrégé
A computer-implemented method for determining one or more operating modes for a crude oil displacement system is provided. The crude oil displacement system is arranged to inject an aqueous displacement fluid into one or more reservoirs, each reservoir comprising a porous and permeable rock formation, wherein crude oil and formation water are contained within a pore space of the rock formation. The crude oil displacement system is for use in displacing crude oil from the pore space of the rock formation. The computer-implemented method comprises the steps of receiving measurement data associated with one or more chemical characteristics of the displacement fluid and one or more chemical characteristics of the rock formation, the crude oil and the formation water of the one or more reservoirs, and inputting the measurement data and data representing a predetermined volume of oil into a computer-implemented predictive model. The predictive model is operated so as to generate predicted data indicative of a predicted additional amount of oil, compared to the predetermined volume of oil, that will be displaced by configuring the crude oil displacement system so as to inject the displacement fluid having the chemical characteristics into the one or more reservoirs. On the basis of the predicted data, the one or more operating modes of the crude oil displacement system are determined. A further computer-implemented method employing the predictive model in which predicted data indicative of one or more predicted chemical characteristics of the displacement fluid are generated is also provided. Additionally, a system for configuring a crude oil displacement system is provided.
BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
Inventeur(s)
Collins, Ian Ralph
Mason, Andrew Russell
Abrégé
A method of storing CO2 in a porous and permeable hydrocarbon reservoir having at least one injection well and at least one production well penetrating said reservoir, which method comprises the steps of: (a) recovering a produced fluid stream comprising produced hydrocarbons, produced water, and produced CO2 from the production well; (b) passing the produced fluid stream to a production facility where a produced vapour stream comprising carbon dioxide and volatile hydrocarbons is separated from the produced fluid stream; (c) compressing the produced vapour stream to above the cricondenbar for the composition of the produced vapour stream; (d) cooling the compressed stream thereby forming a cooled stream that is in a dense phase state; (e) importing a CO2 stream to an injection facility wherein the imported CO2 is either in a liquid state or a supercritical state; (f) mixing the cooled stream from step (d) with the imported CO2 stream thereby forming a co-injection stream; and (g) injecting the co-in-jection stream into the hydrocarbon bearing reservoir from said injection well.
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
BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
Inventeur(s)
Howe, David John
Abrégé
A method of performing a 3-D seismic survey operation using (i) a plurality of vibroseis sources, and (ii) an array of seismic sensors arranged within a survey area wherein each vibroseis source emits a distinctive acoustic signal and each seismic sensor of the array is in a continuous state of readiness to detect reflected acoustic signals, the method comprising: (a) assigning vibroseis points (VPs) to each of the vibroseis sources; (b) independently moving each vibroseis source to assigned: vibroseis point (VPs) where the vibroseis source emits its distinctive acoustic signal independently in time of the emission of the distinctive acoustic signals of the other vibroseis sources at their assigned vibroseis points (VPs); (c) recording the emission time of the distinctive acoustic signal by each vibroseis source at its assigned VPs together with the geographic position of the assigned VPs; (d) continuously listening for reflected acoustic signals using the array of seismic sensors and recording a time domain record of the reflected acoustic signals received by each seismic sensor of the array; wherein the reflected acoustic signals associated with the emission of a distinctive acoustic signal by a vibroseis source at an assigned VP are determined by: (i) extracting the reflected acoustic signals from the time domain records for the seismic sensors of the array during a predetermined listening time associated with the emission of the distinctive acoustic signal by the vibroseis source at the assigned VP; (ii) cross-correlating the extracted reflected acoustic signals with the distinctive emitted acoustic signal for the vibroseis source at the assigned VP thereby eliminating weakly correlated signals; and (iii) attenuating randomised cross-contamination in the cross-correlated extracted reflected acoustic signals from step (ii) using random noise attenuation techniques.
BP EXPLORATION OPERATING COMPANY LIMITED (Royaume‑Uni)
DAVY PROCESS TECHNOLOGY LIMITED (Royaume‑Uni)
Inventeur(s)
Font Freide, Josephus Johannes Helena Maria
Hardy, Lawrence Trevor
Abrégé
The present invention relates to a process for the conversion of synthesis gas to hydrocarbons in the presence of a modified supported Fischer-Tropsch catalyst composition, by addition of a silylating compound modifier, preferably an organosilicon compound such as bis (timethylsilyl) trif luoroacetamide.
B01J 31/02 - Catalyseurs contenant des hydrures, des complexes de coordination ou des composés organiques contenant des composés organiques ou des hydrures métalliques
B01J 23/06 - Catalyseurs contenant des métaux, oxydes ou hydroxydes métalliques non prévus dans le groupe du zinc, du cadmium ou du mercure
B01J 23/80 - Catalyseurs contenant des métaux, oxydes ou hydroxydes métalliques non prévus dans le groupe du cuivre ou des métaux du groupe du fer en combinaison avec des métaux, oxydes ou hydroxydes prévus dans les groupes avec du zinc, du cadmium ou du mercure
B01J 33/00 - Protection des catalyseurs, p.ex. par revêtement
C10G 2/00 - Production de mélanges liquides d'hydrocarbures de composition non définie à partir d'oxydes de carbone