A downhole tool for installing a tubing hanger in a well without an umbilical includes a body defining a primary flow path; a first connector at a first end of the body for mechanically connecting the tool to a tubing hanger; a second connector at a second end of the body for mechanically connecting the tool to a tubular or tool handling equipment; a locking actuator configured to move from a running position to a locking position under the action of fluid pressure, the actuator including an interface for engaging and moving a lock of a tubing hanger into a locked position as the actuator moves to the locking position; and a bypass valve activating system configured to operate a tubing hanger annulus bypass valve. The downhole tool is configured to move the locking actuator from the running position to the locking position, and operate a tubing hanger annulus bypass valve, without the use of an umbilical.
A method of operating a hydrocarbon production system. The hydrocarbon production system including a gas turbine engine configured to combust hydrocarbon gas produced at the hydrocarbon production system and to provide power for the hydrocarbon production system as a result of the combustion. The method includes combusting produced hydrocarbon gas in the gas turbine engine, capturing carbon dioxide exhausted from the gas turbine engine as a result of the combustion of the hydrocarbon gas, storing the captured carbon dioxide at the hydrocarbon production system in a first set of storage pipes, and transporting the stored carbon dioxide away from the hydrocarbon production system for permanent storage.
F01N 3/08 - Exhaust or silencing apparatus having means for purifying, rendering innocuous, or otherwise treating exhaust for rendering innocuous
B01D 53/14 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by absorption
A subsea foundation system and a method of connecting a lower pipe portion to a subsea foundation are provided. The method includes: providing the subsea foundation, an upper pipe portion being connected to the subsea foundation, deploying the subsea foundation subsea; and connecting the lower pipe portion to the upper pipe portion. The subsea foundation system includes: the subsea foundation; the upper pipe portion connected to the subsea foundation, and the lower pipe portion. The lower pipe portion can be connected to the upper pipe portion subsea. The lower pipe portion may be connected to the subsea foundation in a stowed position before deployment subsea. The lower pipe portion may be connected to a pull-in arrangement before deployment subsea.
The invention provides a method for separating particles from a mixture comprising water and particles, comprising: (i) adding a charged gas to said mixture comprising water and particles; (ii) moving said charged gas through said mixture so that said charged gas contacts said particles and associates therewith; and (iii) separating from said mixture said gas and particles.
An electronic inflow control device for use in a hydrocarbon producing well is configured to switch electronically between an open state and a closed state. The inflow control device includes a housing, including one or more electromagnets; a gate including one or more permanent magnets and moveable within the housing between a closed state and an open state; the housing defining a first valve seat for receiving the gate in a closed state, and a second valve seat for receiving the gate in an open state.
A method of installing a subsea cable bundle including an umbilical and at least one direct current and fibre optic (DCFO) cable attached to an outside of the umbilical includes connecting a first end of the cable bundle to a pulling head, lowering the first end of the cable bundle into the se, connecting the pulling head to a winch cable of a winch (the winch may be connected before or after lowering the first end), the winch being located on a platform and the winch cable extending from the platform into the sea through a J-tube, and using the winch to pull the first end of the cable bundle up to the platform through the J-tube. The method further includes laying the cable bundle on the seafloor, and at a target location, at or close to a subsea structure, detaching the DFCO cable from the umbilical and connecting the DCFO cable and the umbilical at their second ends to the subsea structure.
H02G 1/10 - Methods or apparatus specially adapted for installing, maintaining, repairing, or dismantling electric cables or lines for laying cables, e.g. laying apparatus on vehicle in or under water
The geochemical parameters of reservoir fluid do not directly and universally correlate with the fluid type of the reservoir fluid, e.g. reservoir oil and reservoir gas. However, within an individual hydrocarbon basin, the local reservoir oils and the local reservoir gases are often geochemically distinct. Therefore, by examining various geochemical parameters for reservoir fluid samples taken from a particular region of interest, it is possible to identify region-specific thresholds for those geochemical parameters, and also to identify particular region-specific thresholds having a high degree of confidence for distinguishing between different reservoir fluid types. Advantageously, many geochemical parameters can be determined using mud-gas data, and in some cases using only standard mud-gas data. Therefore, by collecting mud-gas data when drilling a new well within the region of interest, these region-specific thresholds can be used to generate a substantially continuous and highly accurate reservoir fluid type log along a length of the well. This same technique may also be applied retrospectively to existing wells where mud-gas data was collected at the time of drilling, since at least standard mud-gas data is routinely collected while drilling.
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
There is provided a method for testing a valve of a subsea tree. The method comprises: closing the valve to be tested; fluidly isolating an isolatable region of the subsea tree directly adjacent to the valve to be tested; after being isolated, depressurising the isolatable region to a pressure below an ambient, subsea pressure or pressurising the isolatable region using a pressure manipulation device positioned subsea; monitoring a pressure of the isolatable region after being depressurised; and determining whether the valve to be tested is operating correctly based on the monitoring.
F16K 37/00 - Special means in or on valves or other cut-off apparatus for indicating or recording operation thereof, or for enabling an alarm to be given
E21B 34/04 - Valve arrangements for boreholes or wells in well heads in underwater well heads
G01M 3/28 - Investigating fluid tightness of structures by using fluid or vacuum by measuring rate of loss or gain of fluid, e.g. by pressure-responsive devices, by flow detectors for pipes, cables, or tubesInvestigating fluid tightness of structures by using fluid or vacuum by measuring rate of loss or gain of fluid, e.g. by pressure-responsive devices, by flow detectors for pipe joints or sealsInvestigating fluid tightness of structures by using fluid or vacuum by measuring rate of loss or gain of fluid, e.g. by pressure-responsive devices, by flow detectors for valves
A method of generating a model for predicting at least one property of a fluid at a sample location within a hydrocarbon reservoir includes simulating behaviour of one or more hydrocarbon reservoirs during production; generating a plurality of simulated fluid samples from the one or more simulated hydrocarbon reservoirs, the plurality of simulated fluid samples corresponding to a plurality of different spatial locations and/or different time locations within the one or more simulated hydrocarbon reservoirs; generating a training data set including input data and target data based on the simulated fluid samples, the input data including simulated mud-gas data for each sample location indicative of mobile and immobile hydrocarbons at the sample location, and the target data including the at least one property of only the mobile hydrocarbons at each sample locations; and constructing a model using the training data set such that the model can be used to predict the at least one property of the fluid at a sample location based on measured mud-gas data for the sample location.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
A connector (18) for connecting a subsea wellhead system (16) to a second component (20) is disclosed. The connector (18) comprises a locking element (38) configured to engage with a locking portion (34) of the wellhead system (16) and a locking portion (52) of the second component (20), a gripping element (40) configured to engage with a gripping portion (60) of the wellhead system (16), and a compression element (42). The gripping element (38) and the locking element (40) of the wellhead system (16) are spaced from each other, and the compression element (42) is configured to introduce compression into the wellhead system (16) at least between the locking portion (34) and the gripping portion (60).
A suction anchor and method of installing the suction anchor. The suction anchor including a suction chamber bounded by: a circumferential outer wall; an upper wall; and an internal housing wall. The internal housing defining a passage for receiving wellhead components that may be secured to the suction anchor. The suction chamber has a minor upper portion and a major lower portion. The minor upper portion having internal reinforcing members extending along the inside of the upper wall from the outer walls to the internal housing. The major portion is adapted to be embedded in a seabed and the minor portion is adapted to project from the seabed when the anchor is installed. The reinforcing members serve to reinforce the upper wall of the chamber against collapse and to rigidly support the internal housing to resist forces arising from bending moments applied to wellhead components received and secured therein.
B01D 53/34 - Chemical or biological purification of waste gases
B01D 53/14 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by absorption
A method of monitoring for changes in a subsurface formation, comprising: comparing measured seismic data acquired in a first seismic survey of the subsurface formation with synthetic seismic data, wherein the synthetic seismic data is generated using a reference model of the subsurface formation and simulated conditions that are equivalent to conditions under which the measured seismic data was acquired, wherein the reference model is built using measured seismic data acquired from a reference seismic survey of the subsurface formation that is performed before or after the first seismic survey.
Method of generating a model for predicting a fluid type of a reservoir fluid at a sample location within a hydrocarbon reservoir. The method comprises: providing a training data set comprising input data and target data, the input data comprising mud-gas data and/or PVT data, and geospatial data, for each of a plurality of sample locations in a field comprising the hydrocarbon reservoir and/or in a nearby field, and the target data comprising a fluid type for each of the plurality of sample locations; and instructing a machine learning algorithm to generate a model using the training data set such that the model can be used to predict the fluid type of the reservoir fluid at the sample location based on measured mud-gas data and geospatial data for the sample location, wherein a drilling fluid recycling correction has not been applied to the mud-gas data.
G01V 9/00 - Prospecting or detecting by methods not provided for in groups
G01N 30/00 - Investigating or analysing materials by separation into components using adsorption, absorption or similar phenomena or using ion-exchange, e.g. chromatography
A motion controller for a floating wind turbine including a number of rotor blades is provided. The motion controller is arranged to adjust the blade pitch of each rotor blade when the floating wind turbine is operating in winds below the rated wind speed so as to create a net force that damps a surge motion of the floating wind turbine. Also provided is a method of damping the motion of a floating wind turbine and a wind turbine having such a motion controller.
An offshore hydrocarbon pressure control apparatus (20) comprises: a first subsea pipeline (26) configured to receive a first hydrocarbon flow; a second 5 subsea pipeline (28) configured to receive a second, different hydrocarbon flow; a turboexpander (22) configured to expand the first hydrocarbon flow; and a compressor (24) driven by the turboexpander and configured to compress the second hydrocarbon flow, wherein both the turboexpander (22) and the compressor (24) are located either subsea or on an offshore platform.
E21B 43/01 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
F25J 1/00 - Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
F02C 6/02 - Plural gas-turbine plants having a common power output
F01D 15/00 - Adaptations of machines or engines for special useCombinations of engines with devices driven thereby
17.
ASSEMBLY AND METHOD FOR CONNECTING A STEEL WIND TURBINE TOWER TO A CONCRETE FOUNDATION
A cable head ring (30) for use in connecting a wind turbine tower (10) to a concrete foundation (20) comprises an annular plate (32) for connecting to the upper end of the concrete foundation (20), an inner tubular web (36) extending axially from the annular plate (32) and an outer tubular web (38) extending axially from the annular plate (32), wherein an annular gap (40) is formed between the inner and outer tubular webs (36, 38) for receiving a tubular wind turbine component. The annular plate (32) comprises a plurality of passages (42) extending axially therethrough for receiving tensioning tendons (24) of the concrete foundation (20) when mounted thereon. The inner and outer tubular webs (36, 38) include holes (44, 46) extending radially therethrough. The positions of the holes (44) in the inner tubular web (36) correspond to the positions of the holes (46) in the outer tubular web (38) such that a fastener (54) can extend radially through a hole (44) in the inner tubular web (36 and a hole (46) in the outer tubular web (38) for securing a tubular wind turbine component within the annular gap (40).
E02D 27/42 - Foundations for poles, masts, or chimneys
E04H 12/08 - Structures made of specified materials of metal
E04H 12/12 - Structures made of specified materials of concrete or other stone-like material, with or without internal or external reinforcement, e.g. with metal coverings, with permanent form elements
Disclosed herein are pile structures for offshore wind turbines and method of installing the same. A pile structure (100) comprises: a pile body (101) having a pile tip (101a) configured to be inserted into a soil body (5) such as a seabed; and a fluid delivery apparatus (110) configured to deliver a fluid to a surface of the pile body (101) proximate to the pile tip (101a) in a direction extending aware from the pile tip (101a). The fluid delivery apparatus (110) is configured to deliver the fluid at a local differential pressure of between 0 and 8 bar, i.e. at a low pressure.
A method of cleaning deposited solid material from a fouled portion of a gas compressor (6) whilst the gas compressor (6) is in situ in a natural gas processing system (1) is provided. The method comprises the steps of supplying a liquid cleaning agent to a gas inlet of the gas compressor (6), the liquid cleaning agent being capable of removing the deposited solid material; passing the liquid cleaning agent through the gas compressor (6) to a gas outlet of the gas compressor (6), wherein at least a portion of the cleaning agent remains in a liquid state as it passes through the fouled portion of the gas compressor (6); and recovering a fluid containing removed material that is output from the gas compressor (6) so as to prevent the removed material reaching one or more gas processing stages of the gas processing system (1) downstream of the gas compressor (6).
An inflow control device configured to switch between an open and a closed state, includes: an inlet; an outlet; a housing; a first body and second body arranged within the housing. The second body is moveable relative to the first body. In an electrically energised state, the first body is operative to magnetically attract or repel the second body. In the open state, the first and second body are located at respective open positions and define a continuous path with the housing, through which fluid can flow from the inlet to the outlet. In the closed state, the first and second body are located at respective closed positions and are contiguous, thereby blocking the continuous path. The inflow control device is operative to switch between the open and closed states by electrically energising or de-energising the first body.
A method of injecting carbon dioxide into an offshore injection well (4), the method comprising: storing carbon dioxide within a plurality of storage pipes (103) at an offshore storage facility (1); and injecting the stored carbon dioxide into an injection well (4).
An inflow control device for use in a well or pipeline, the inflow control device being configured to switch reversibly between an open state and a closed state, or between a closed state and an open state, the inflow control device comprising: a housing; a gate moveable within the housing between a closed state and an open state; the housing defining a first valve seat for receiving the gate in a closed state, and a second valve seat for receiving the gate in an open state, wherein the first valve seat and the second valve seat comprise one or more permanent magnets, or wherein the gate comprises one or more permanent magnets.
A wireline mobile controller, arranged to open or close an inflow control device installed in a well, the mobile controller comprising: a first connector for electrically connecting the mobile controller to a wireline, and a second connector for mechanically connecting the mobile controller to the wireline; an electrical component, arranged to couple electromagnetically to the inflow control device when the electrical component is electrically energised, and to open or close the inflow control device remotely.
: A method of obtaining a three-dimensional model of a current sub-surface formation. The method comprises obtaining three-dimensional, treated, physical survey data, and comprising measurement data at each of a multiplicity of indexed locations within a regular three-dimensional grid of indexed locations. For a given set of geological processes, a backward sequence of corresponding inverse geological processes is obtained which, when the backward sequence is applied to the treated physical survey data, transform that treated physical survey data into representative survey data which is approximately representative of the sub-surface formation at a time of its formation. A three-dimensional model of the sub-surface formation is derived at a time of its formation, the model comprising one or more material properties at each of said indexed locations, and said set of geological processes is applied to the derived three-dimensional model, in a forward sequence to obtain a current model of the sub-surface formation. Each of the geological processes and their inverses is defined as a linear or rotational shift, or combination of such shifts, of the measurement data or material properties between the indexed locations.
: A system for monitoring properties within a subsea electrical architecture of an offshore windfarm comprising one or more wind turbines. The system comprises first passive optical sensors within the subsea unit for monitoring an electrical or environmental property within the subsea unit, a first optical fibre bundle extending integrally within a power cable, a first optical interconnection unit within the subsea unit and optically coupling one or more optical fibres of the optical fibre bundle to the passive optical sensors, a monitoring unit located at an onshore grid connection point, and a second optical interconnection unit optically coupling one or more optical fibres of the optical fibre bundle to said monitoring unit. The monitoring unit is configured to transmit monitoring light signals along one or more optical fibres of the first optical fibre bundle to said first optical interconnection unit and to localise a fault and/or operate a circuit breaker in dependence upon optical signals transmitted from the or each first passive optical sensor over the first optical fibre bundle.
F03D 17/00 - Monitoring or testing of wind motors, e.g. diagnostics
G01D 5/353 - Mechanical means for transferring the output of a sensing memberMeans for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for convertingTransducers not specially adapted for a specific variable using optical means, i.e. using infrared, visible or ultraviolet light with attenuation or whole or partial obturation of beams of light the beams of light being detected by photocells influencing the transmission properties of an optical fibre
F03D 13/00 - Assembly, mounting or commissioning of wind motorsArrangements specially adapted for transporting wind motor components
26.
OPTICALLY MACHINE READABLE IDENTIFIERS FOR TUBULAR SECTIONS
The method includes providing first and second machine readable codes on an external surface of each tubular section wherein the second code encodes less information than the first code and is derivable from, or mapped to, information encoded in the first code; using a machine to read the first machine readable code at a first pipe handling location on said platform; storing information of the read first codes; moving the sections in turn to a second pipe handling location, the second pipe handling location being a tubular structure assembly location on said platform or a location intermediate said first and second locations; using an optical machine at or close to the second pipe handling location to read the second codes from positioned sections; and storing information of the read second codes and their sequence order.
G06K 7/14 - Methods or arrangements for sensing record carriers by electromagnetic radiation, e.g. optical sensingMethods or arrangements for sensing record carriers by corpuscular radiation using light without selection of wavelength, e.g. sensing reflected white light
The invention provides a process for manufacturing ammonia, comprising: a) electrolysing water in an electrolyser to form a first oxygen stream and a first hydrogen stream; b) separating air in an air separation unit to form a second oxygen stream and a nitrogen stream; c) generating a second hydrogen stream by a two-stage reforming process comprising: i) feeding a reformer feed gas to reformer tubes of an oxyfuel steam methane reformer, wherein the reformer feed gas comprises a hydrocarbon feedstock and steam; ii) mixing the first oxygen stream with an at least partially recycled flue gas stream from said reformer, to form a combustion mixture; iii) introducing the combustion mixture to a combustion chamber of the oxyfuel steam methane reformer to burn a fuel gas so as to provide heat for steam reforming of the feed gas to a product gas in the reformer tubes and a flue gas in the combustion chamber; iv) feeding the product gas from the oxyfuel steam reformer to an autothermal reformer and reacting said product gas with the second oxygen stream in the autothermal reformer to form a synthesis gas; v) passing the synthesis gas from the autothermal reactor through a water-gas shift reactor unit to form a shifted synthesis gas; vi) introducing the shifted synthesis gas to a pressure swing adsorption unit to form a second hydrogen stream and a separate offgas, wherein the fuel gas in the oxyfuel steam reformer unit in iii) comprises at least a portion of the offgas from the pressure swing adsorption unit; d) mixing the first and second hydrogen streams and the nitrogen stream to produce a make-up gas; and e) feeding said make-up gas to a reactor to form ammonia.
C01B 3/02 - Production of hydrogen or of gaseous mixtures containing hydrogen
C01B 3/38 - Production of hydrogen or of gaseous mixtures containing hydrogen by reaction of gaseous or liquid organic compounds with gasifying agents, e.g. water, carbon dioxide, air by reaction of hydrocarbons with gasifying agents using catalysts
C01B 3/48 - Production of hydrogen or of gaseous mixtures containing hydrogen by reaction of gaseous or liquid organic compounds with gasifying agents, e.g. water, carbon dioxide, air by reaction of hydrocarbons with gasifying agents followed by reaction of water vapour with carbon monoxide
A method of installing a header pipe joint 1 at a subsea structure 5 is provided, comprising providing a header pipe joint 1 having at least one valve 2 installed therein and connecting the header pipe joint 1 inline of a spool 15 or pipeline 18 prior to lowering the header pipe joint 1 to the subsea structure 5. The header pipe joint 1 is then lowered to the subsea structure 5, and the valve 2 is connected to the subsea structure (e.g. a subsea production system of the subsea structure such as a xmas tree) with a connection bridge e.g. a choke bridge 14. This provides a fluidic connection between the subsea structure and the header pipe joint. The subsea structure 5 comprises a foundation, e.g. suction anchors 11, which provide support for both a wellhead and the header pipe joint. A subsea assembly comprising a subsea structure 5, header pipe joint 1 and connection bridge 14 is also provided.
A method of installing a subsea pipeline having a direct tie-in between a first section of the pipeline and a subsea structure, wherein, after installation, the first section is located at a tie-in position. The method comprises: laying at least a portion of the pipeline from a laying vessel, the at least a portion of the pipeline including the first section and a second section of the pipeline, such that the first section is beyond the tie-in position in the laying direction, and the first section and the tie-in position are beyond the second section in the laying direction; either before, during or after said laying, configuring the second section such that bending will be preferentially induced in the second section of the at least a portion of the pipeline when the first section is pushed or pulled back to the tie-in position; pushing or pulling the first section back to the tie-in position, wherein, responsive to said pushing or pulling, bending is preferentially induced in the second section.
A method of calculating extraction efficiency coefficients for mud-gas analysis comprises: generating a simulated output drilling fluid based on a mixture of about 1 wt.% of a reference reservoir fluid and a balance of an input drilling fluid; simulating release of gas from the simulated output drilling fluid under predetermined conditions using an equations-of-state model; and determining an extraction efficiency coefficient for each gas component based on a ratio between the composition of the reference reservoir fluid and the composition of the simulated released gas.
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
An offshore energy supply system 1 comprises: an energy supply module 2 for facilitating supply of energy from at least one energy supply to at least one user 7; at least one energy supply connection means 8 for connecting the energy supply module 2 to the at least one energy supply; and at least one user connection means 4 for connecting the energy supply module 2 to the at least one user 7, such that energy can be transferred from the at least one energy supply via the energy supply module 2 to the at least one user 7. At least one of the at least one energy supply is/are arranged to supply electrical energy and/or hydrogen. The energy supply module 2 is configured to be located on a sea bed 9.
B63B 27/24 - Arrangement of ship-based loading or unloading equipment for cargo or passengers of pipe-lines
B63B 27/30 - Arrangement of ship-based loading or unloading equipment for cargo or passengers for transfer at sea between ships or between ships and off-shore structures
B60L 53/10 - Methods of charging batteries, specially adapted for electric vehiclesCharging stations or on-board charging equipment thereforExchange of energy storage elements in electric vehicles characterised by the energy transfer between the charging station and the vehicle
A method is provided for performing subsea well interventions in a subsea well which is provided with a vessel at the sea surface and a subsea lubricator at the seabed. The method comprises connecting a riser to the vessel, so that the riser extends for at least some of the distance between the vessel and the well, but is spaced apart from said lubricator, and lowering a tool and a pressure control head through said riser to said lubricator.
A method of controlling diffusion of a wake generated by a horizontal axis wind turbine is provided. The wind turbine comprises a rotor having a hub and a plurality of rotor blades 20 mounted to the hub. Each rotor blade 20 has a radially- outer, energy-extraction portion 32 and a radially-inner, ventilation portion 30, wherein the radially-inner ventilation portion 30 is shaped to, in use, extract reduced levels of kinetic energy from the wind compared to the radially-outer energy extraction portion 32 in order to ventilate a central area 34 of the wake. Diffusion of the wake is controlled by adjusting the tip speed ratio of the rotor in order to modify turbulent mixing within the wake.
A floating wind turbine installation comprises an asymmetric floating wind turbine structure that is tethered to the floor of a body of water by a mooring system. The floating wind turbine structure comprises a wind turbine mounted on a semi- submersible floating platform, and is oriented such that the wind turbine is positioned on an upwind side of the centre of mass of the floating wind turbine structure when the wind approaches the wind turbine structure in the direction of the prevailing wind at the location of the wind turbine installation.
A method of estimating the primary and secondary acoustic velocities, Vp and Vs, of formation surrounding a first wellbore includes obtaining well logging data for a multiplicity of other wellbores to collect, for each other wellbore a plurality of input data sets including at least a Nuclear Magnetic Resonance logging data set, and an element composition scanning data set. The operation further collects, for each other wellbore, at least one output data set including a primary and secondary velocity data set. The method incudes training or establishing at least one regression model using said input and output data sets, obtaining well logging data for said first wellbore to obtain a corresponding plurality of input data sets, and applying the obtained corresponding plurality of input data sets to the trained or established regression model to generate as an output of the regression model, an output data set for the first wellbore including a primary and secondary velocity data set.
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
G01V 11/00 - Prospecting or detecting by methods combining techniques covered by two or more of main groups
36.
WHIPSTOCK ASSEMBLY AND ASSOCIATED METHOD OF INSTALLING THE WHIPSTOCK ASSEMBLY
The invention relates to a whipstock assembly (10), and an associated method of installing the whipstock assembly (1). The whipstock assembly (1) is configured for installation in a well (1), the whipstock assembly (10) comprising a housing (13) extending in a longitudinal direction, wherein the whipstock assembly (10) comprises: - a whipstock device (11) with an inclined surface (12) located in an upper part of the housing (13) for deflecting a drill string (4); - an anchoring device (14) below the whipstock device (11), the anchoring device (14) having a run state and a set state, and wherein in the run state the anchoring device (14) is configured to be run into the well (1) and in the set state the anchoring device (14) is configured to anchor against an inner wall (2) of the well (1); - a sealing device (15) below the whipstock device (11), the sealing device (15) having a run state and a set state, and wherein in the run state the sealing device (15) is configured to be run into the well (1) and in the set state the sealing device (15) is configured to seal against the inner wall (2) of the well (1); - an activation device (20) for actuating the anchoring device (14) from the run state to the set state and for actuating the sealing device (15) from the run state to the set state; - a locking device (30) operable between: o a first position in which the locking device (30) prevents activation of the activation device (20); and o a second position in which the locking device (30) allows activation of the activation device (20) thereby forcing the anchoring device (14) to the set state and the sealing device (15) to the set state.
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
A method of operating a hydrocarbon production system (1), the hydrocarbon production system (1) comprising a gas turbine engine (5) configured to provide power for the hydrocarbon production system (1), the method comprising: splitting produced hydrocarbon gas to form blue hydrogen and carbon dioxide; combusting the blue hydrogen in the gas turbine (5) engine to provide power for the hydrocarbon production system (1); capturing the carbon dioxide formed from splitting the hydrocarbon gas; and storing the captured carbon dioxide in a set of storage pipes (19) at the hydrocarbon production system (1).
C01B 3/48 - Production of hydrogen or of gaseous mixtures containing hydrogen by reaction of gaseous or liquid organic compounds with gasifying agents, e.g. water, carbon dioxide, air by reaction of hydrocarbons with gasifying agents followed by reaction of water vapour with carbon monoxide
A method of storing ethane comprises storing ethane in a plurality of storage pipes (23) as a liquid at ambient temperature conditions. The storage pipes (23) may be provided on a tanker (2).
F17C 5/02 - Methods or apparatus for filling pressure vessels with liquefied, solidified, or compressed gases for filling with liquefied gases
F17C 5/04 - Methods or apparatus for filling pressure vessels with liquefied, solidified, or compressed gases for filling with liquefied gases requiring the use of refrigeration, e.g. filling with helium or hydrogen
F17C 1/00 - Pressure vessels, e.g. gas cylinder, gas tank, replaceable cartridge
F17C 11/00 - Use of gas-solvents or gas-sorbents in vessels
B63B 25/08 - Load-accommodating arrangements, e.g. stowing or trimmingVessels characterised thereby for bulk goods fluid
B63B 25/14 - Load-accommodating arrangements, e.g. stowing or trimmingVessels characterised thereby for bulk goods fluid closed pressurised
B63B 27/30 - Arrangement of ship-based loading or unloading equipment for cargo or passengers for transfer at sea between ships or between ships and off-shore structures
39.
HYDROCARBON PRODUCTION SYSTEM WITH REDUCED CARBON DIOXIDE EMISSION
A method of operating a hydrocarbon production system, the hydrocarbon production system comprising a power source (107) configured to provide power for the hydrocarbon production system and a plurality of storage pipes (103), the method comprising: storing ammonia as a liquid at ambient temperature conditions in the plurality of storage pipes (103); and using the ammonia as an energy source for the power source (107) in order to provide power for the hydrocarbon production system.
A method of storing ammonia, the method comprising storing the ammonia in a plurality of storage pipes (103) in a liquid state at ambient temperature conditions. The storage pipes (103) may be situated at an offshore floating facility (1) or aboard a transportation vehicle (e.g. a tanker).
A method of operating an offshore hydrocarbon production system, the offshore hydrocarbon production system comprising a power source (107) configured to provide power for the offshore hydrocarbon production system, the method comprising using ammonia as an energy source for the power source (107) in order to provide power for the offshore hydrocarbon production system; wherein the power source (107) is located on/at a unit that is separate from the remainder of the offshore hydrocarbon production system and hence the step of using the ammonia as an energy source for the power source (107) takes place on/at the unit that is separate from the remainder of the offshore hydrocarbon production system.
A method is disclosed for generating a machine learning model to predict a reservoir fluid property, such as gas-oil ratio or density, based on standard mud-gas and petrophysical data. It has been found that this model predicts these reservoir fluid properties with an accuracy that is close to that which can be achieved using advanced mud-gas data. This is advantageous, as than standard mud-gas data and petrophysical data is much more readily available than advanced mud-gas data.
A wind turbine system including a rotationally asymmetric floating wind turbine installation and a rotationally asymmetric mooring system connected to the floating wind turbine installation. The mooring system includes a number of mooring lines connected, directly or indirectly, to the floating wind turbine installation such that the mooring system has a lower yaw stiffness when a wind acting on the wind turbine installation comes from 0° than when a wind acting on the wind turbine installation comes from ±90°. A wind coming from 0° is defined as a wind direction when the horizontal part of the aerodynamic rotor thrust force resulting from the wind is directed towards the center of gravity of the floating wind turbine installation.
A method of estimating a depth of a hydrocarbon-water contact of a hydrocarbon reservoir in a structure. The method may include the steps of analysing one or more samples obtained from the structure to generate a relationship relating resistivity to hydrocarbon-water contact depth, obtaining a resistivity measurement of the hydrocarbon reservoir, and estimating the hydrocarbon-water contact depth from the relationship relating resistivity to hydrocarbon-water contact depth and the resistivity measurement of the hydrocarbon reservoir.
E21B 49/02 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil
G01N 15/08 - Investigating permeability, pore volume, or surface area of porous materials
G01V 3/20 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with propagation of electric current
G01N 27/04 - Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating impedance by investigating resistance
A method of identifying a location of gas breakthrough within a completed production well comprises: obtaining production composition data and/or tracer data from the production well; analysing the production composition data and/or tracer data to determine whether gas breakthrough has occurred within the production well; and in response to determining that gas breakthrough has occurred within the production well, examining mud-gas data collected during drilling of the production well to identify a gas breakthrough location within the well where the gas breakthrough has occurred.
A method of identifying a location of gas breakthrough within a completed production well comprises: obtaining production composition data and/or tracer data from the production well; analysing the production composition data and/or tracer data to determine whether gas breakthrough has occurred within the production well; and in response to determining that gas breakthrough has occurred within the production well, examining mud-gas data collected during drilling of the production well to identify a gas breakthrough location within the well where the gas breakthrough has occurred.
A downhole tool for installing a tubing hanger in a well without an umbilical, the tool comprising: a body defining a primary flow path; a first connector at a first end of the body for mechanically connecting the tool to a tubing hanger; a second connector at a second end of the body for mechanically connecting the tool to a tubular or tool handling equipment; a locking actuator configured to move from a running position to a locking position under the action of fluid pressure; the actuator comprising an interface for engaging and moving a lock of a tubing hanger into a locked position as the actuator moves to the locking position; and a bypass valve activating system configured to operate a tubing hanger annulus bypass valve; wherein the downhole tool is configured to move the locking actuator from the running position to the locking position, and operate a tubing hanger annulus bypass valve, without the use of an umbilical.
E21B 33/043 - Casing headsSuspending casings or tubings in well heads specially adapted for underwater well heads
E21B 33/035 - Well headsSetting-up thereof specially adapted for underwater installations
E21B 23/02 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for locking the tools or the like in landing nipples or in recesses between adjacent sections of tubing
E21B 33/04 - Casing headsSuspending casings or tubings in well heads
E21B 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
A downhole tool for installing a tubing hanger in a well without an umbilical, the tool comprising: a body defining a primary flow path; a first connector at a first end of the body for mechanically connecting the tool to a tubing hanger; a second connector at a second end of the body for mechanically connecting the tool to a tubular or tool handling equipment; a locking actuator configured to move from a running position to a locking position under the action of fluid pressure; the actuator comprising an interface for engaging and moving a lock of a tubing hanger into a locked position as the actuator moves to the locking position; and a bypass valve activating system configured to operate a tubing hanger annulus bypass valve; wherein the downhole tool is configured to move the locking actuator from the running position to the locking position, and operate a tubing hanger annulus bypass valve, without the use of an umbilical.
E21B 33/043 - Casing headsSuspending casings or tubings in well heads specially adapted for underwater well heads
E21B 23/02 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for locking the tools or the like in landing nipples or in recesses between adjacent sections of tubing
E21B 33/035 - Well headsSetting-up thereof specially adapted for underwater installations
E21B 33/04 - Casing headsSuspending casings or tubings in well heads
49.
HYDROCARBON PRODUCTION SYSTEM WITH REDUCED CARBON DIOXIDE EMISSION
A method of operating a hydrocarbon production system (1), the hydrocarbon production system (1) comprising a gas turbine engine (5) configured to combust hydrocarbon gas produced at the hydrocarbon production system (1) and to provide power for the hydrocarbon production system (1) as a result of the combustion. The method comprises: combusting produced hydrocarbon gas in the gas turbine engine (5); capturing carbon dioxide exhausted from the gas turbine engine (5) as a result of the combustion of the hydrocarbon gas; storing the captured carbon dioxide at the hydrocarbon production system (1) in a first set of storage pipes (19a); and transporting the stored carbon dioxide away from the hydrocarbon production system (1) for permanent storage.
B01D 53/02 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by adsorption, e.g. preparative gas chromatography
B01D 53/14 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by absorption
A method of operating a hydrocarbon production system (1), the hydrocarbon production system (1) comprising a gas turbine engine (5) configured to combust hydrocarbon gas produced at the hydrocarbon production system (1) and to provide power for the hydrocarbon production system (1) as a result of the combustion. The method comprises: combusting produced hydrocarbon gas in the gas turbine engine (5); capturing carbon dioxide exhausted from the gas turbine engine (5) as a result of the combustion of the hydrocarbon gas; storing the captured carbon dioxide at the hydrocarbon production system (1) in a first set of storage pipes (19a); and transporting the stored carbon dioxide away from the hydrocarbon production system (1) for permanent storage.
B01D 53/02 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by adsorption, e.g. preparative gas chromatography
B01D 53/14 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by absorption
The present invention relates to a negative electrode for a lithium ion cell and a method for manufacturing the negative electrode, where the negative electrode comprises a layered composite comprising a layer of Cu or a Cu-alloy and a first active layer of one of: Al, an Al-alloy, an Al/Li-alloy, Sn, a Sn-alloy, Si, or a Si- alloy, and wherein the layers of the layered composite are diffusion bonded to each other.
H01M 4/48 - Selection of substances as active materials, active masses, active liquids of inorganic oxides or hydroxides
H01M 4/485 - Selection of substances as active materials, active masses, active liquids of inorganic oxides or hydroxides of mixed oxides or hydroxides for inserting or intercalating light metals, e.g. LiTi2O4 or LiTi2OxFy
H01M 4/505 - Selection of substances as active materials, active masses, active liquids of inorganic oxides or hydroxides of manganese of mixed oxides or hydroxides containing manganese for inserting or intercalating light metals, e.g. LiMn2O4 or LiMn2OxFy
H01M 4/525 - Selection of substances as active materials, active masses, active liquids of inorganic oxides or hydroxides of nickel, cobalt or iron of mixed oxides or hydroxides containing iron, cobalt or nickel for inserting or intercalating light metals, e.g. LiNiO2, LiCoO2 or LiCoOxFy
H01M 10/0525 - Rocking-chair batteries, i.e. batteries with lithium insertion or intercalation in both electrodesLithium-ion batteries
52.
RESIDUAL CURVATURE METHOD TO MITIGATE PIPELINE BUCKLING
A method for laying a pipeline on a seabed in order to provide controlled thermal expansion includes feeding the pipeline from a pipeline reel through a straightener system; and at the straightener system, imparting an alternating and continuously varying degree of residual curvature on at least a portion of the pipeline.
A method of hydrocarbon production at an offshore production facility (1). The method comprises: a) producing hydrocarbon fluid from a subsea wellhead (5) in communication with a subsea hydrocarbon reserve; b) conveying the produced hydrocarbon fluid to a topside structure (17) by means of the pressure of the produced hydrocarbon fluid at the wellhead; c) allowing the pressure of the produced hydrocarbon fluid at the wellhead to decline during step a) as a result of a declining hydrocarbon reserve pressure due to production of hydrocarbon fluid therefrom; and d) whilst allowing the pressure of the produced hydrocarbon fluid at the wellhead to decline, compensating for the declining pressure of the produced hydrocarbon fluid by introducing or increasing pumping of the produced hydrocarbon fluid using a subsea pump to ensure that the produced fluid is conveyed to the topside structure.
E21B 43/01 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 43/16 - Enhanced recovery methods for obtaining hydrocarbons
A floating, unmanned wellhead or production facility includes a topside configured to process a hydrocarbon fluid, and a spar hull supporting the topside. The spar hull is designed to minimize maintenance and thus does not include many of the systems commonly found in the hull of a floating offshore facility. Systems that are not present within the spar hull include an active ballast system, a bilge system, a drainage system, an active zone isolation system, a fire detection and suppression system, and an internal lighting system.
B63B 35/44 - Floating buildings, stores, drilling platforms, or workshops, e.g. carrying water-oil separating devices
B63B 39/02 - Equipment to decrease pitch, roll, or like unwanted vessel movementsApparatus for indicating vessel attitude to decrease vessel movements by displacement of masses
B63B 5/14 - Hulls characterised by their construction of non-metallic material made predominantly of concrete, e.g. reinforced
E21B 33/035 - Well headsSetting-up thereof specially adapted for underwater installations
A62C 3/00 - Fire prevention, containment or extinguishing specially adapted for particular objects or places
A system for liquid surge protection of a subsea riser having a horizontal portion on the seabed and a sag bend portion includes: a flexible tubing having a top end and a bottom end; a plurality of autonomous valves configured to permit liquid to pass through into the flexible tubing, wherein the autonomous valves are arranged between the top end and the bottom end of the tubing; and an inlet device coupled to the bottom end of the flexible tubing, wherein said inlet device is biased against a bottom wall the riser.
A hydrocarbon-forming gas compression method comprising: a hydrate formation step in which water and hydrate-forming gas are mixed at a first pressure and a first temperature, resulting in the formation of hydrate; a decomposition step in which the hydrate is warmed, and the hydrate is decomposed to re-generate hydrate-forming gas at a second pressure higher than the first pressure.
An electronic inflow control device for use in a hydrocarbon producing well, the inflow control device being configured to switch electronically between an open state and a closed state, the inflow control device comprising: a housing, comprising one or more electromagnets; a gate comprising one or more permanent magnets and moveable within the housing between a closed state and an open state; the housing defining a first valve seat for receiving the gate in a closed state, and a second valve seat for receiving the gate in an open state.
An electronic inflow control device for use in a hydrocarbon producing well, the inflow control device being configured to switch electronically between an open state and a closed state, the inflow control device comprising: a housing, comprising one or more electromagnets; a gate comprising one or more permanent magnets and moveable within the housing between a closed state and an open state; the housing defining a first valve seat for receiving the gate in a closed state, and a second valve seat for receiving the gate in an open state.
A method of using a source of substantially continuous noise to obtain seismic data simulating data obtained from an impulsive source located. The method comprises a) obtaining, for each of a plurality of seismic sensors, a seismic data stream, b) pre- processing and cross-correlating the seismic streams to obtain a plurality of cross-correlation data sets, c) estimating the location of the noise source by searching a grid of locations with respective semblances, where the semblance is obtained by moveout correcting each of said cross-correlation data sets using a velocity model, and semblance stacking the moveout corrected data, d) processing the data sets to enhance components associated with said noise source, and e) generating the simulated data by stacking each of said cross-correlation data sets, performing moveout correction, and reintroducing absolute source-receiver travel times.
G01V 1/42 - SeismologySeismic or acoustic prospecting or detecting specially adapted for well-logging using generators in one well and receivers elsewhere or vice-versa
The invention provides a process for disinfecting seawater, said process comprising the steps: (i) contacting the seawater with pure oxygen so as to produce purified seawater; and (ii) electrolysing said purified seawater to produce hydrogen and oxygen; wherein the oxygen produced in step (ii) is at least partially recycled for use in step (i).
A controller is provided for a floating wind turbine including a rotor with a number of rotor blades connected to a generator. The controller includes an active damping controller for calculating one or more outputs for damping both a first motion of the floating wind turbine in a first frequency range and a second motion of the floating wind turbine in a second frequency range based on an input of the first motion and an input of the second motion, The controller is arranged to calculate an output for controlling a blade pitch of one or more of the rotor blades and/or for controlling a torque of the generator based on an actual rotor speed, a target rotor speed, and the one or more outputs from the active damping controller such that both the first motion and the second motion will be damped.
An underwater vehicle (10) for transporting fluid, wherein the underwater vehicle comprises: a prime mover configured to power propulsion of the underwater vehicle through the water; and a plurality of storage pipes (13) for storing the fluid therein.
B63B 25/08 - Load-accommodating arrangements, e.g. stowing or trimmingVessels characterised thereby for bulk goods fluid
B63B 25/12 - Load-accommodating arrangements, e.g. stowing or trimmingVessels characterised thereby for bulk goods fluid closed
B63C 11/52 - Tools specially adapted for working underwater, not otherwise provided for
B63B 21/66 - Equipment specially adapted for towing underwater objects or vessels, e.g. fairings for tow-cables
B63B 27/34 - Arrangement of ship-based loading or unloading equipment for cargo or passengers for transfer at sea between ships or between ships and off-shore structures using pipe-lines
A method of registering geological data at a formation core tracking system includes, at the tracking system, registering a formation core provided within a field of view of an optical imaging system of the tracking system; tracking the orientation of the formation core relative to the tracking system and the distance of the formation core relative to the tracking system; obtaining data associated with a first section of the formation core which is located at a predetermined distance from the tracking system, displaying the data together with an image of the formation core such that an augmented reality image is provided on a display device of the tracking system, changing the distance between the tracking system and the core; and updating the displayed data by obtaining data associated with a second section of the formation core which is located at said predetermined distance from the tracking system.
G06F 3/02 - Input arrangements using manually operated switches, e.g. using keyboards or dials
G06F 3/0488 - Interaction techniques based on graphical user interfaces [GUI] using specific features provided by the input device, e.g. functions controlled by the rotation of a mouse with dual sensing arrangements, or of the nature of the input device, e.g. tap gestures based on pressure sensed by a digitiser using a touch-screen or digitiser, e.g. input of commands through traced gestures
A method of installing a subsea cable bundle comprising an umbilical and at least one direct current and fibre optic (DCFO) cable attached to an outside of the umbilical. The method comprises connecting a first end of the cable bundle to a pulling head, lowering the first end of the cable bundle into the se, connecting the pulling head to a winch cable of a winch (the winch may be connected before or after lowering the first end), the winch being located on a platform and the winch cable extending from the platform into the sea through a J-tube, and using the winch to pull the first end of the cable bundle up to the platform through the J-tube. The method further comprises laying the cable bundle on the seafloor, and at a target location, at or close to a subsea structure, detaching the DFCO cable from the umbilical and connecting the DCFO cable and the umbilical at their second ends to the subsea structure.
E21B 33/035 - Well headsSetting-up thereof specially adapted for underwater installations
H02G 9/02 - Installations of electric cables or lines in or on the ground or water laid directly in or on the ground, river-bed or sea-bottomCoverings therefor, e.g. tile
A method of installing a subsea cable bundle comprising an umbilical and at least one direct current and fibre optic (DCFO) cable attached to an outside of the umbilical. The method comprises connecting a first end of the cable bundle to a pulling head, lowering the first end of the cable bundle into the se, connecting the pulling head to a winch cable of a winch (the winch may be connected before or after lowering the first end), the winch being located on a platform and the winch cable extending from the platform into the sea through a J-tube, and using the winch to pull the first end of the cable bundle up to the platform through the J-tube. The method further comprises laying the cable bundle on the seafloor, and at a target location, at or close to a subsea structure, detaching the DFCO cable from the umbilical and connecting the DCFO cable and the umbilical at their second ends to the subsea structure.
H02G 1/10 - Methods or apparatus specially adapted for installing, maintaining, repairing, or dismantling electric cables or lines for laying cables, e.g. laying apparatus on vehicle in or under water
H02G 9/02 - Installations of electric cables or lines in or on the ground or water laid directly in or on the ground, river-bed or sea-bottomCoverings therefor, e.g. tile
A blade pitch controller for a wind turbine includes a nominal control system and a tower feedback loop. The tower feedback loop includes a filtering system. The filtering system is arranged to control wind turbine blade pitch so as to provide additional effective stiffness to the wind turbine in response to motion of the wind turbine which is above a filter frequency of the filtering system.
:An unmanned underwater vehicle, comprising: an outer hull defining an internal volume; a pressure communication channel between the internal volume and the exterior of the outer hull, arranged to control the pressure in the internal volume based on the exterior pressure; a buoyancy and trim control system; a probe provided within the internal volume of the vehicle; a port at the bottom side of the vehicle, providing a channel between the internal volume and the exterior of the vehicle, for the probe to extend through the port for collecting material or data.
E21B 25/18 - Apparatus for obtaining or removing undisturbed cores, e.g. core barrels or core extractors the core receiver being specially adapted for operation under water
The geochemical parameters of reservoir fluid do not directly and universally correlate with the fluid type of the reservoir fluid, e.g. reservoir oil and reservoir gas. However, within an individual hydrocarbon basin, the local reservoir oils and thelocal reservoir gases are often geochemically distinct. Therefore, by examining various geochemical parameters for reservoir fluid samples taken from a particular region of interest, it is possible to identify region-specific thresholds for those geochemical parameters, and also to identify particular region-specific thresholds having a high degree of confidence for distinguishing between different reservoir fluid types.Advantageously, many geochemical parameters can be determined using mud-gas data, and in some cases using only standard mud-gas data. Therefore, by collecting mud-gas data when drilling a new well within the region of interest, these region-specific thresholds can be used to generate a substantially continuous and highly accurate reservoir fluid type log along a length of the well. This same technique may also be applied retrospectively to existing wells where mud-gas data was collected at the time of drilling, since at least standard mud-gas data is routinely collected while drilling.
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
G01V 9/00 - Prospecting or detecting by methods not provided for in groups
The geochemical parameters of reservoir fluid do not directly and universally correlate with the fluid type of the reservoir fluid, e.g. reservoir oil and reservoir gas. However, within an individual hydrocarbon basin, the local reservoir oils and thelocal reservoir gases are often geochemically distinct. Therefore, by examining various geochemical parameters for reservoir fluid samples taken from a particular region of interest, it is possible to identify region-specific thresholds for those geochemical parameters, and also to identify particular region-specific thresholds having a high degree of confidence for distinguishing between different reservoir fluid types.Advantageously, many geochemical parameters can be determined using mud-gas data, and in some cases using only standard mud-gas data. Therefore, by collecting mud-gas data when drilling a new well within the region of interest, these region-specific thresholds can be used to generate a substantially continuous and highly accurate reservoir fluid type log along a length of the well. This same technique may also be applied retrospectively to existing wells where mud-gas data was collected at the time of drilling, since at least standard mud-gas data is routinely collected while drilling.
E21B 47/003 - Determining well or borehole volumes
E21B 47/008 - Monitoring of down-hole pump systems, e.g. for the detection of "pumped-off" conditions
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
G01N 37/00 - Details not covered by any other group of this subclass
An unmanned underwater vehicle, comprising: an outer hull defining an internal volume; a pressure communication channel between the internal volume and the exterior of the outer hull, arranged to control the pressure in the internal volume based on the exterior pressure; an inflatable cushion provided outside the hull and at the bottom side of the underwater vehicle, wherein the inflatable cushion is arranged between the hull and the seabed when the vehicle is landed on the seabed; a first fluid pump and fluid conduit between the first fluid pump and the inflatable cushion, for inflating or deflating the inflatable volume.
B63B 59/02 - Fenders integral with waterborne vessels or specially adapted thereforRubbing-strakes
B63B 43/18 - Improving safety of vessels, e.g. damage control, not otherwise provided for preventing collisionImproving safety of vessels, e.g. damage control, not otherwise provided for reducing collision damage
A method for offloading cargo fluid from a container in an underwater vehicle, the method comprising: displacing cargo fluid from the container with a backfill liquid at a first pressure; depressurising the backfill liquid to a second pressure, wherein the second pressure is lower than the first pressure; and discharging at least part of the backfill liquid from the container.
A method for use in evaluating or mapping a sub-sea metallic mineral resource or resources over a region is provided. The method comprises: providing sample data relating to at least one sample taken from the region (1a); providing at least one set of measured data relating to the region (1b); and c. inputting the sample data and the at least one set of measured data into a machine-learning algorithm (2). The machine-learning algorithm comprises a model relating the measured data to a quantity, fraction and/or density of the resource or resources. The method also comprises running the machine-learning algorithm to train the model (2).
There is provided a method for testing a valve of a subsea tree. The method comprises: closing the valve to be tested; fluidly isolating an isolatable region of the subsea tree directly adjacent to the valve to be tested; after being isolated, depressurising the isolatable region to a pressure below an ambient, subsea pressure or pressurising the isolatable region using a pressure manipulation device positioned subsea; monitoring a pressure of the isolatable region after being depressurised; and determining whether the valve to be tested is operating correctly based on the monitoring.
E21B 33/035 - Well headsSetting-up thereof specially adapted for underwater installations
E21B 47/117 - Detecting leaks, e.g. from tubing, by pressure testing
G01M 3/28 - Investigating fluid tightness of structures by using fluid or vacuum by measuring rate of loss or gain of fluid, e.g. by pressure-responsive devices, by flow detectors for pipes, cables, or tubesInvestigating fluid tightness of structures by using fluid or vacuum by measuring rate of loss or gain of fluid, e.g. by pressure-responsive devices, by flow detectors for pipe joints or sealsInvestigating fluid tightness of structures by using fluid or vacuum by measuring rate of loss or gain of fluid, e.g. by pressure-responsive devices, by flow detectors for valves
A method of generating a model for predicting at least one property of a fluid at a sample location within a hydrocarbon reservoir, the method comprising: simulating behaviour of one or more hydrocarbon reservoir during production; generating a plurality of simulated fluid samples from the one or more simulated hydrocarbon reservoir, the plurality of simulated fluid samples corresponding to a plurality of different spatial locations and/or different time locations within the one or more simulated hydrocarbon reservoir; generating a training data set comprising input data and target data based on the simulated fluid samples, the input data comprising simulated mud-gas data for each sample location indicative of mobile and immobile hydrocarbons at the sample location, and the target data comprising the at least one property of only the mobile hydrocarbons at each sample locations; and constructing a model using the training data set such that the model can be used to predict the at least one property of the fluid at a sample location based on measured mud-gas data for the sample location.
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
G01V 9/00 - Prospecting or detecting by methods not provided for in groups
A method of generating a model for predicting at least one property of a fluid at a sample location within a hydrocarbon reservoir, the method comprising: simulating behaviour of one or more hydrocarbon reservoir during production; generating a plurality of simulated fluid samples from the one or more simulated hydrocarbon reservoir, the plurality of simulated fluid samples corresponding to a plurality of different spatial locations and/or different time locations within the one or more simulated hydrocarbon reservoir; generating a training data set comprising input data and target data based on the simulated fluid samples, the input data comprising simulated mud-gas data for each sample location indicative of mobile and immobile hydrocarbons at the sample location, and the target data comprising the at least one property of only the mobile hydrocarbons at each sample locations; and constructing a model using the training data set such that the model can be used to predict the at least one property of the fluid at a sample location based on measured mud-gas data for the sample location.
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
There is provided a method for testing a valve of a subsea tree. The method comprises: closing the valve to be tested; fluidly isolating an isolatable region of the subsea tree directly adjacent to the valve to be tested; after being isolated, depressurising the isolatable region to a pressure below an ambient, subsea pressure or pressurising the isolatable region using a pressure manipulation device positioned subsea; monitoring a pressure of the isolatable region after being depressurised; and determining whether the valve to be tested is operating correctly based on the monitoring.
E21B 33/035 - Well headsSetting-up thereof specially adapted for underwater installations
G01M 3/28 - Investigating fluid tightness of structures by using fluid or vacuum by measuring rate of loss or gain of fluid, e.g. by pressure-responsive devices, by flow detectors for pipes, cables, or tubesInvestigating fluid tightness of structures by using fluid or vacuum by measuring rate of loss or gain of fluid, e.g. by pressure-responsive devices, by flow detectors for pipe joints or sealsInvestigating fluid tightness of structures by using fluid or vacuum by measuring rate of loss or gain of fluid, e.g. by pressure-responsive devices, by flow detectors for valves
E21B 47/117 - Detecting leaks, e.g. from tubing, by pressure testing
There is provided a method and system for monitoring a hydrocarbon liquid from a hydrocarbon fluid processing system. The method comprises: determining information about the composition of the hydrocarbon liquid, wherein the determination comprises: obtaining a gas from the hydrocarbon liquid; allowing the gas to equilibrate with the hydrocarbon liquid in the closed container; analysing a sample of the equilibrated gas to measure the composition of the gas; and determining information about the composition of the hydrocarbon liquid based upon the gas composition measurement; and periodically repeating the determination of the information about the composition of the hydrocarbon liquid to monitor the hydrocarbon liquid composition over time.
A container device for transporting and releasing a plugging material into a well includes a longitudinal chamber for containing the plugging material, the chamber including a tubular wall extending in a longitudinal direction and at least one opening for releasing the plugging material from the chamber; a lower seal extending across the opening and closing the chamber in a closed configuration; a pressure application mechanism provided at an upper portion of the container device for pressurising at least part of the device and expelling the plugging material; and a connector provided at an upper portion of the container device for attaching the container device to an elongate member for lowering into a wellbore.
A foundation for a subsea assembly is provided. The foundation includes connection points. The connection points permit other components to be connected to the foundation and permit loads to transfer from the other components into the foundation. The foundation may be a suction anchor. A method of converting an exploration well using the foundation to a production well is also provided.
E21B 33/038 - Connectors used on well heads, e.g. for connecting blow-out preventer and riser
E21B 41/08 - Underwater guide bases, e.g. drilling templatesLevelling thereof
E02B 17/02 - Artificial islands mounted on piles or like supports, e.g. platforms on raisable legsConstruction methods therefor placed by lowering the supporting construction to the bottom, e.g. with subsequent fixing thereto
A foundation for a subsea assembly is provided. The foundation includes connection points. The connection points permit other components to be connected to the foundation and permit loads to transfer from the other components into the foundation. The foundation may be a suction anchor. A method of converting an exploration well using the foundation to a production well is also provided.
A method of exploring for hydrocarbons in a region, including the steps of obtaining seismic data for the region corresponding to two or more different times and analyzing the seismic data corresponding to the two or more different times to determine whether there are any changes in the seismic data.
B01D 53/14 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by absorption
B01D 53/14 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by absorption
A method of exploring for hydrocarbons in a region comprises obtaining seismic data for the region. The seismic data comprises seismic data measured at two or more different times (e.g. dates). The method further comprises comparing the seismic data measured at two or more different times, wherein comparing the seismic data measured at two or more different times comprises determining a time shift between the seismic data measured at two or more different times. The method further comprises assessing, based on the comparison of the seismic data measured at two or more different times, whether there is likely to be hydrocarbons in the region. If it is assessed that there is likely to be hydrocarbons in the region, the method further comprises assessing whether the hydrocarbons are likely to be oil or gas.
A method and corresponding gas processing system for cleaning deposited solid material from a fouled portion of a gas compressor whilst the gas compressor is in situ in a natural gas processing system are provided. Cleaning of a gas compressor is achieved by accumulating liquid removed from cooling gas used for cooling the gas compressor and supplying the accumulated liquid to an inlet of the gas compressor in order to remove deposited solid material from the gas compressor. The cooling gas is extracted from an intermediate stage of the gas compressor.
A system and method of analysing drilling cuttings using image data output from a hyperspectral imaging device and at least one optical camera, includes generating a hyperspectral imaging data set including a plurality of lines of hyperspectral data derived from line images taken by the hyperspectral imaging device positioned along a drilling fluid cuttings path, obtaining tracking information in respect of particles of interest from the output of the at least one optical camera, correcting the position of pixels associated with particles of interest in the plurality of lines of hyperspectral imaging data based on the obtained tracking information to generate corrected hyperspectral imaging data, and analysing the corrected hyperspectral imaging data to characterise the cuttings.
E21B 47/002 - Survey of boreholes or wells by visual inspection
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
A subsea foundation system and a method of connecting a lower pipe portion to a subsea foundation are provided. The method includes: providing the subsea foundation, an upper pipe portion being connected to the subsea foundation, deploying the subsea foundation subsea; and connecting the lower pipe portion to the upper pipe portion. The subsea foundation system includes: the subsea foundation; the upper pipe portion connected to the subsea foundation, and the lower pipe portion. The lower pipe portion can be connected to the upper pipe portion subsea. The lower pipe portion may be connected to the subsea foundation in a stowed position before deployment subsea. The lower pipe portion may be connected to a pull-in arrangement before deployment subsea.
There is provided a method and system for determining the true vapour pressure (TVP) of a hydrocarbon liquid. The method comprises: obtaining a gas from the hydrocarbon liquid; allowing gas to equilibrate with the liquid in a closed container; analysing a sample of the equilibrated gas to measure the composition of the gas; and determining the TVP of the hydrocarbon liquid based upon the gas composition measurement.
G01N 7/14 - Analysing materials by measuring the pressure or volume of a gas or vapour by allowing the material to emit a gas or vapour, e.g. water vapour, and measuring a pressure or volume difference
A transition piece (12) for use in a foundation of an offshore wind turbine (1) comprises a tubular concrete support structure (13) for supporting a wind turbine (1). The concrete support structure (13) has a first end (16) arranged to receive an end portion of a pile (11) for mounting the transition piece (12) on the pile (11), and a second end (17) distal from the first end (16) for supporting a wind turbine (1). The transition piece (12) may form part of a foundation for an offshore wind turbine (1) in which the transition piece (12) is mounted on an end of a pile (11) extending from the sea floor (7). The end of the pile (11) on which the transition piece (12) is mounted is below the surface of the water (8) and the transition piece (12) protrudes above the surface of the water (8) such that a wind turbine (1) may be mounted thereon.
F03D 13/20 - Arrangements for mounting or supporting wind motorsMasts or towers for wind motors
E02D 27/42 - Foundations for poles, masts, or chimneys
E02B 17/02 - Artificial islands mounted on piles or like supports, e.g. platforms on raisable legsConstruction methods therefor placed by lowering the supporting construction to the bottom, e.g. with subsequent fixing thereto
Methods of monitoring for influx and/or loss events in a wellbore are disclosed. One method comprises: receiving a measurement relating to fluid entering or leaving the wellbore, wherein the measurement is selected from flow out rate and active volume; and comparing the measurement with an expected value for the measurement to provide a deviated measurement value. The method further comprises receiving a pump pressure value of a pump associated with the wellbore; and comparing the pump pressure value with an expected pump pressure value to provide a deviated pump pressure value. It is then established whether an influx event and/or it is established whether a loss event may have occurred based on at least the deviated measurement value and deviated pump pressure value. Systems configured to monitor for influx and/or loss events in a wellbore are also disclosed.
An inflow control device configured to switch between an open and a closed state, comprising: an inlet; an outlet; a housing; a first body and second body arranged within the housing, wherein the second body is moveable relative to the first body, wherein in an electrically energised state, the first body is operative to magnetically attract or repel the second body; wherein, in the open state, the first and second body are located at respective open positions and define a continuous path with the housing, through which fluid can flow from the inlet to the outlet; wherein, in the closed state, the first and second body are located at respective closed positions and are contiguous, thereby blocking said continuous path; and wherein, the inflow control device is operative to switch between the open and closed states by electrically energising or de-energising the first body.
An inflow control device configured to switch between an open and a closed state, comprising: an inlet; an outlet; a housing; a first body and second body arranged within the housing, wherein the second body is moveable relative to the first body, wherein in an electrically energised state, the first body is operative to magnetically attract or repel the second body; wherein, in the open state, the first and second body are located at respective open positions and define a continuous path with the housing, through which fluid can flow from the inlet to the outlet; wherein, in the closed state, the first and second body are located at respective closed positions and are contiguous, thereby blocking said continuous path; and wherein, the inflow control device is operative to switch between the open and closed states by electrically energising or de-energising the first body.
An apparatus for removing soil from a conduit for a subsea well that is forced or placed into a seabed is provided. The apparatus comprises a soil disturbance device to displace soil within the conduit before drilling is performed. A method of removing soil from a conduit for a subsea well that is forced or placed into a seabed is also provided. The method comprises using a soil disturbance device to displace soil within the conduit before drilling is performed.
Herein disclosed is a well assembly comprising a sensor and a method of monitoring using the sensor. The well assembly may comprise a wellbore and the sensor, wherein the sensor is in a fixed location relative to the wellbore, and wherein the sensor is for monitoring the size and/or shape of the wellbore. The method may be a method of monitoring the size and/or shape of the wellbore. The method may comprise: providing the sensor in a fixed location relative to the wellbore, and monitoring the size and/or shape of the wellbore using the sensor. The well assembly may comprise a well foundation and the sensor, wherein the sensor is in a fixed location relative to the well foundation, and wherein the sensor is for monitoring the earth underneath the well foundation during installation of the well assembly. The method may be a method of monitoring the earth underneath the well foundation. The method may comprise providing the sensor in a fixed location relative to the well foundation, and monitoring the earth underneath the well foundation during installation of the well assembly.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 47/08 - Measuring diameters or related dimensions at the borehole
E21B 47/005 - Monitoring or checking of cementation quality or level
E21B 47/001 - Survey of boreholes or wells for underwater installations
A method of analysing seismic data from a geological structure. The method includes determining a set of tiles from a data cube of seismic data and determining which tiles of the set of tiles can be grouped into one or more patches of tiles.
A distributed acoustic sensing system for acquiring seismic data is presented. The system includes a sensing cable and an instrument float. The sensing cable is for sensing seismic waves and is suitable for use on the seabed. The instrument float includes instrumentation for acquiring seismic data. The instrument float is connectable or connected to the sensing cable via a riser cable.
G01V 1/22 - Transmitting seismic signals to recording or processing apparatus
G01D 5/353 - Mechanical means for transferring the output of a sensing memberMeans for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for convertingTransducers not specially adapted for a specific variable using optical means, i.e. using infrared, visible or ultraviolet light with attenuation or whole or partial obturation of beams of light the beams of light being detected by photocells influencing the transmission properties of an optical fibre
G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas
G01V 1/20 - Arrangements of receiving elements, e.g. geophone pattern
A method of connecting a conduit to a subsea structure is provided. In the disclosed method, a tensioning member is provided on the conduit and attached to the conduit at two locations proximate a first end of the conduit. The tensioning member is used to maintain a curvature formed in the conduit between the two locations e.g. by deflecting a portion of the conduit. A first end of the conduit is engaged with a guide assembly provided adjacent to the subsea structure, and tension in the tensioning member is released to adjust the axial position of the first end of the conduit to enable direct connection between the conduit and the subsea structure. A method of disconnecting a conduit from a subsea structure, and a system for connecting a conduit to a subsea structure are also provided.
F16L 1/26 - Repairing or joining pipes on or under water
E21B 43/01 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
E21B 43/013 - Connecting a production flow line to an underwater well head
F16L 1/16 - Laying or reclaiming pipes on or under water on the bottom
A well insert for insertion into a foundation of a well is provided. The insert comprises a channel therethrough for the well; and the well insert is arranged so that when the well insert is inserted into the foundation of the well, the channel of the insert can be adjusted relative to vertical. A well assembly comprising the well insert and a well foundation is also provided as is a method of inserting a well insert and a method of controlling the orientation of a well using a well insert.
A tubular for use in the creation or completion of, or production from, an oil and/or gas well. The tubular comprises; an elongate main body; a stab-in connector element located at an end of the main body; and a rotatable connection sleeve disposed coaxially around a first end portion of the main body at or near said end of the main body. The connection sleeve is configured to provide a mechanical coupling between the tubular and another tubular without requiring rotation of the main body, to thereby provide a stab-in connection between the stab-in connector element of the tubular and a complementary stab-in connector element of the other tubular for electrical power and/or data transmission.
A motion controller 20 for a floating wind turbine 1 comprising a plurality of rotor blades is provided. The motion controller 20 is arranged to adjust the blade pitch of each rotor blade when the floating wind turbine 1 is operating in winds below the rated wind speed so as to create a net force that damps a surge motion of the floating wind turbine 1. Also provided is a method of damping the motion of a floating wind turbine 1 and a wind turbine 1 having such a motion controller 20.
