Herein disclosed is a method of locating a wellhead support structure (1) about an existing subsea well (5). The method comprises providing a wellhead support structure (1), wherein the wellhead support structure (1) comprises a suction anchor (2) and a guide device (3); and guiding the wellhead support structure (1) into a position about the existing subsea well (5) using the guide device (3). Herein disclosed is also a wellhead support structure (1) for location about an existing subsea well (5), wherein the wellhead support structure (1) comprises: a suction anchor (2); and a guide device (3) for guiding the wellhead support structure (1) into a position about the subsea well (5).
A tool for use in a well system, the tool comprising: a stator and a rotor; the rotor being rotatably connected to the stator, the rotor being arranged to rotate around a main axis of rotation; the rotor comprising a main body and a surface, the surface facing the main axis of rotation, the surface being movable with respect to the main body of the rotor, and the surface being arranged to engage with a wall of the well system.
E21B 29/00 - Cutting or destroying pipes, packers, plugs or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windowsDeforming of pipes in boreholes or wellsReconditioning of well casings while in the ground
E21B 41/04 - Manipulators for underwater operations, e.g. temporarily connected to well heads
B08B 9/02 - Cleaning pipes or tubes or systems of pipes or tubes
3.
ASSEMBLY AND METHOD FOR CONNECTING A STEEL WIND TURBINE TOWER TO A CONCRETE FOUNDATION
A cable head ring for use in connecting a wind turbine tower to a concrete foundation. The cable head ring includes an annular plate for connecting to the upper end of the concrete foundation, an inner tubular web extending axially from the annular plate and an outer tubular web extending axially from the annular plate. An annular gap is formed between the inner and outer tubular webs for receiving a tubular wind turbine component. The annular plate has a plurality of passages extending axially therethrough for receiving tensioning tendons of the concrete foundation. The inner and outer tubular webs include holes extending radially therethrough. The positions of the holes in the inner tubular web correspond to the positions of the holes in the outer tubular web such that a fastener can extend radially through a hole in the inner tubular web and a hole in the outer tubular web.
G01V 3/30 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electromagnetic waves
G01V 3/38 - Processing data, e.g. for analysis, for interpretation or for correction
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 including: 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 include one or more permanent magnets, or wherein the gate includes one or more permanent magnets.
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 including 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, in which 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, and the gate defines side openings which can be selectively aligned with side openings in an insert of the housing extending into the gate.
The present disclosure relates to a subsea pipeline buckling mode trigger system, the subsea pipeline buckling mode trigger system comprising a pipeline sub-section circumscribed by a coating, the coating defining an axially localised region of weakness that extends around at least part of the circumference of the pipeline sub-section, and associated methods of manufacture.
An inflow control device, comprising: an inlet for fluid ingress; an outlet for fluid egress; a rotor operable to rotate about a rotor axis; and a valve body comprising at least one port through the valve body, wherein rotation of the rotor is arranged to cause the valve body to advance towards or away from a position wherein the device defines a pathway for fluid to pass between the inlet and the outlet via said at least one port through the valve body.
A well sub-assembly, comprising: a base pipe; a first winding wound around a first annular core; a second winding around the base pipe; and a return line electrically connected to the base pipe at two spaced apart positions along the base pipe, wherein, the return line and a part of the base pipe, defined between the two spaced positions, collectively form a closed loop. The first annular core extends through the closed loop and the second winding is arranged around said part of the base pipe. The closed loop is configured to carry an electrical current.
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
E21B 47/13 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range
A platform (100) for providing a water tight seal in an offshore wind turbine tower. The platform (100) comprises, a platform main body (10) providing a platform surface having a periphery, at least one flap (30) surrounding the main body and pivotally connected to the main body (10), a seal member (20) providing a peripheral portion (22) surrounding the periphery of the main body (10) and attached to the or each flap (30). The at least one flap (30) is configured to be pivoted relative to the platform main body (10) so as to move the peripheral portion (22) from a transport position where the platform (100) has a first diameter to an installation position where the platform (100) has a second diameter greater than the first diameter.
A method for controlling the production of a hydrocarbon producing smart well including receiving, by a control device, data signals, from one or more electrical devices located in the smart well, of the smart well in a first configurational state; analysing, by the control device, the data signals to determine the state of each of said plurality of inflow control devices and the operating conditions of the smart well; determining, by the control device, an updated state of the smart well corresponding to an optimal pressure regime, wherein the updated state of the smart well is defined by an updated configurational state of said plurality of inflow control devices; transmitting control signals to the inflow control devices, via electrical conductors, for said plurality of inflow control devices to update their state according to the control signal.
A flow conditioning unit for conditioning a multiphase fluid, a fluid processing system for transporting a multiphase fluid, and a method for conditioning a multiphase fluid using a flow conditioning unity are disclosed. The flow conditioning unit 1 comprises a main pipeline having an inlet portion 10 arranged to receive a multiphase fluid flow; a gas extraction portion 20 arranged to remove gas content from the main pipeline; a liquid reservoir 40 arranged to receive liquid content from the main pipeline; and a gas-liquid mixer 50 arranged to receive a gas content flow from the gas extraction portion 20 and a liquid content flow from the liquid reservoir 40 to produce a conditioned multiphase fluid flow. The liquid reservoir 40 is arranged to accommodate surges of liquid and to provide a conditioned flow rate of liquid content to the gas-liquid mixer 50. The liquid reservoir 40 comprises at least one bend portion.
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 computer-implemented method of processing time-lapse seismic data, the method comprising: providing a forward model configured to generate synthetic seismic data for a given combination of velocity ratio and density ratio, and for each of a plurality of given sampling depths of the subsurface region, iterating over different combinations of velocity ratio and density ratio to determine a given combination of velocity ratio and density ratio that minimises an objective function including a misfit term between (i) synthetic seismic data computed using the forward model and (ii) corresponding seismic data of the second seismic trace, wherein said ratios are defined at said sampling depth.
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 method of calculating extraction efficiency coefficients for mud-gas analysis includes: 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.
A floating wind turbine installation including 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 includes 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 system for monitoring properties within a subsea electrical architecture of an offshore windfarm including one or more wind turbines incudes 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.
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.
Herein disclosed is a pipe part for connecting to a subsea foundation, wherein the pipe part comprises a pipe and a plug, wherein the plug has a shaped upper surface such that in use the plug is configured to act as a guide for tools or equipment located within or extending through the pipe. A subsea foundation system comprising: a subsea foundation; and the pipe part comprising a plug, a method of providing the pipe part, and a method of guiding a tool or equipment in the pipe part are also disclosed. Herein disclosed is also a pipe part for connecting to a subsea foundation, wherein the pipe part comprises an orientation guide to facilitate the pipe part being installed in a particular orientation. A pipe part for connection to a subsea foundation, wherein the pipe part comprises a pipe; and a plurality of conduits located within the pipe. A method of designing a subsea foundation system, wherein the subsea foundation system comprises: a subsea foundation; and a pipe part for connecting to the subsea foundation to provide the subsea foundation system, the method comprising: obtaining details about the planned used of the subsea foundation system; and designing the pipe part based on the planned use.
A method of determining the state of a downhole valve, wherein the valve comprises a sleeve, and wherein the sleeve is moveable within a housing, the method comprising: operating the valve to change the state of the valve by moving the sleeve; monitoring an optical output of an optical fibre, wherein the optical fibre is arranged in the longitudinal direction of the DHSV; detecting an optical signal as a result of a signal generated by the movement of the sleeve during said step of operating.
E21B 47/09 - Locating or determining the position of objects in boreholes or wellsIdentifying the free or blocked portions of pipes
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
An assembly is provided for connecting a well head system to a subsea foundation structure, the assembly comprising a first component and a second component The first component has a first opening and the second component has a second opening, which is configured for insertion of a wellhead system therethrough. The second component comprises a recess for receiving at least part of the first component therein, wherein the second component comprises a housing portion that is configured to extend away from the first component, when the first component has been received in the recess of the second component. The assembly may comprise a third component that is arranged to in use be located between at least part of the first component and/or second component and at least part of the wellhead system.
A whipstock assembly including a whipstock with an inclined surface in an upper part of a housing for deflecting a drill string; an anchor, below the whipstock having run and set states, in the run state the anchor runs into the well and in the set state the anchor anchors against an inner wall of the well; a sealing device having run and set states, in the run state the sealing device runs into the well and in the set state the sealing device seals against the inner wall; an activation device for actuating the both the anchor and the sealing device from the run state to the set state and; a lock operable between: a first position in which the preventing activation of the activation device; and a second position allowing activation of the activation device thereby forcing both the anchor and the sealing device 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
An assembly is provided for connecting a well head system to a subsea foundation structure, the assembly comprising a first component and a second component The first component has a first opening and the second component has a second opening, which is configured for insertion of a wellhead system therethrough. The second component comprises a recess for receiving at least part of the first component therein, wherein the second component comprises a housing portion that is configured to extend away from the first component, when the first component has been received in the recess of the second component. The assembly may comprise a third component that is arranged to in use be located between at least part of the first component and/or second component and at least part of the wellhead system.
A method of determining at least one fluid interface in at least one annulus surrounding a tubing of a wellbore, the method comprising: providing a buoyancy module, floating the buoyancy module at the at least one fluid interface; generating an acoustic signal with an acoustic signal generator connected to the buoyancy module; detecting the acoustic signal with an optical signal carried within an optical fibre arranged in the longitudinal direction of the tubing.
G01V 8/16 - Detecting, e.g. by using light barriers using one transmitter and one receiver using optical fibres
G01V 8/24 - Detecting, e.g. by using light barriers using multiple transmitters or receivers using optical fibres
E21B 47/14 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
An electrical power distribution system comprising a power cable and a shunt reactor electrically connected to a conductor line of the power cable, the shunt reactor comprising a winding having an open core such that, when submerged in water, the open core is water filled.
Described is an optical fibre cable connection system. The system comprises a first connection part comprising a housing defining an internal space and an opening into the internal space, a first optical fibre cable having a termination end located within the internal space adjacent to said opening, a first sealing plate attached to the housing and sealing said opening whilst defining a first channel extending partially through the first sealing plate and being in alignment with said opening and a second channel extending completely through the first sealing plate and being spaced laterally apart from the first channel, a second sealing plate attached to the housing and spaced apart from the internal space by the first sealing plate, wherein the first sealing plate is movable laterally with respect to the second sealing plate and the housing, and a translation mechanism for causing lateral movement of the first sealing plate. The system further comprises a second connection part comprising a second optical fibre cable, and a shearable end cap fixed to a termination end of the second optical fibre cable and configured to puncture the second sealing plate for insertion into said first channel.
: An inflow control device, comprising: an inlet for fluid ingress; an outlet for fluid egress; a rotor operable to rotate about a rotor axis; a fluid passageway arranged along the rotor axis and having a perforated portion for fluidly coupling the inlet to the outlet; and a valve body arranged around the fluid passageway and comprising a threaded coupling, wherein rotation of the rotor is arranged to cause: the valve body to travel along said threaded coupling to thereby advance towards or away from a configuration in which the perforated portion of the fluid passageway is at least partially obstructed by the valve body.
Described is an optical fibre cable connection system. The system comprises a first connection part comprising a housing defining an internal space and an opening into the internal space, a first optical fibre cable having a termination end located within the internal space adjacent to said opening, a first sealing plate attached to the housing and sealing said opening whilst defining a first channel extending partially through the first sealing plate and being in alignment with said opening and a second channel extending completely through the first sealing plate and being spaced laterally apart from the first channel, a second sealing plate attached to the housing and spaced apart from the internal space by the first sealing plate, wherein the first sealing plate is movable laterally with respect to the second sealing plate and the housing, and a translation mechanism for causing lateral movement of the first sealing plate. The system further comprises a second connection part comprising a second optical fibre cable, and a shearable end cap fixed to a termination end of the second optical fibre cable and configured to puncture the second sealing plate for insertion into said first channel.
: An inflow control device, comprising: an inlet for fluid ingress; an outlet for fluid egress; a rotor operable to rotate about a rotor axis; a fluid passageway arranged along the rotor axis and having a perforated portion for fluidly coupling the inlet to the outlet; and a valve body arranged around the fluid passageway and comprising a threaded coupling, wherein rotation of the rotor is arranged to cause: the valve body to travel along said threaded coupling to thereby advance towards or away from a configuration in which the perforated portion of the fluid passageway is at least partially obstructed by the valve body.
A method of storing ethane includes storing ethane in a number of storage pipes as a liquid at ambient temperature conditions. The storage pipes may be provided on a tanker.
Disclosed is a compensating drill string tool for use in drilling a wellbore, the tool being configured for connection within a length of drill pipe or between an end of the drill pipe and a drill bit, the tool comprising a locking arrangement configurable between a locked configuration and an unlocked configuration; the tool being further configurable to have an axial length that varies in use, in response to axial forces on the tool, when in the unlocked configuration; and an associated method of drilling a subterranean wellbore.
The present invention relates to a multiphase fluid processing system and a method of charging a liquid cleaning agent injection apparatus in situ in a multiphase fluid processing system. The multiphase fluid processing system (100) comprises a gas/liquid separator (1) arranged to produce a gas stream and a liquid stream from a multiphase fluid; a gas compressor (2) for compressing the gas stream; a gas line L1 arranged to supply the gas stream from the gas/liquid separator (1) to the gas compressor (2); a liquid cleaning agent injection apparatus (10) for containing a charged gas and a liquid cleaning agent, the liquid cleaning agent injection apparatus (10) being arranged such that the charged gas will drive the liquid cleaning agent into the gas stream in the gas line L1 during a cleaning operation; a first conduit including a first valve V1, the first conduit coupling the gas stream to an upper part of the liquid cleaning agent injection apparatus (10); a second conduit including a second valve V2, the second conduit coupling the liquid stream to a lower part of the liquid cleaning agent injection apparatus (10); and a controller (20) in communication with the first valve V1 and the second valve V2. The controller (20) is configured to control at least the second valve V2 to supply the liquid cleaning agent injection apparatus (10) with liquid from the liquid stream as at least part of the liquid cleaning agent; and control at least one valve V1, V2 to set a pressure of the charged gas within the liquid cleaning agent injection apparatus (10), using the pressure of the gas stream, such that that the pressure of the charged gas is greater than a suction pressure of the gas compressor (2)when in operation at a normal operational speed.
There is provided an apparatus (30) and method for conditioning the flow of a mixed phase flow from a supply pipe (101) from a hydrocarbon well. The apparatus (30) comprises an elongate reservoir (11) having a first end for receiving a multi-phase fluid flow from the supply pipe and a second closed end, there being provided a gas outlet (02) from the upper part of the first end, a liquid separation region downstream of the first end, and a liquid outlet (12) from the lower part of the liquid separation region; and a gas-liquid mixer to which the gas and liquid outlets are connected such that the separated gas and liquid may be recombined. The reservoir (11) may accommodate surges of liquid such that the flow rate from the liquid outlet is relatively invariant over time compared to that of the flow received by the apparatus.
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
F04D 31/00 - Pumping liquids and elastic fluids at the same time
F17D 1/20 - Arrangements or systems of devices for influencing or altering dynamic characteristics of the systems, e.g. for damping pulsations caused by opening or closing of valves
36.
ENHANCED REACTIVE POWER CONTROL FOR OFFSHORE WIND FARMS
A method of dynamically controlling reactive power compensation in a wind power generation system, the method comprising: obtaining one or more predetermined functions for determining values of a plurality of control parameters based on values of a plurality of input parameters; obtaining values for the plurality of input parameters; based on the obtained values of the input parameters, using the one or more predetermined functions to determine values of the control parameters; and, based on the determined values of the control parameters, controlling a plurality of wind turbine generators to supply or consume a first amount of reactive power and controlling reactive power compensation equipment external to the wind turbine generators to supply or consume a second amount of reactive power.
H02J 3/50 - Controlling the sharing of the out-of-phase component
H02J 3/18 - Arrangements for adjusting, eliminating or compensating reactive power in networks
H02J 3/16 - Circuit arrangements for ac mains or ac distribution networks for adjusting voltage in ac networks by changing a characteristic of the network load by adjustment of reactive power
A method of producing a gas via electrolysis of water, the method comprising: performing electrolysis of water within one or more electrolysis cells (52) to produce a mixture comprising a liquid and one of hydrogen and oxygen; and separating, within a separator (53), the mixture into a gas and a liquid, wherein the separator operates at a higher pressure than the pressure at which the one or more electrolysis cells operate.
The present disclosure relates to techniques for prediction of reservoir fluid properties of a hydrocarbon reservoir fluid, such as the density, the saturation pressure, the formation volume factor and the gas-oil ratio of the reservoir fluid. To predict the reservoir fluid properties, a model is generated by selecting a subset of available reservoir samples based on a degree of biodegradation of the samples, generating an input data set comprising input data and target data, the input data comprising measured or predicted mud-gas data; and generating a model using the input data. The application of this technique allows a continuous log of the selected property to be generated using mud-gas data collected during the well drilling process.
A transition piece for use in a foundation of an offshore wind turbine including a tubular concrete support structure for supporting the wind turbine. The concrete support structure has a first end arranged to receive an end portion of a pile for mounting the transition piece on the pile and a second end distal from the first end for supporting the wind turbine. The transition piece may form part of the foundation for the offshore wind turbine in which the transition piece is mounted on the end of the pile extending from the sea floor. The end of the pile on which the transition piece is mounted is below the surface of the water and the transition piece protrudes above the surface of the water such that the wind turbine may be mounted thereon.
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
E02B 17/00 - Artificial islands mounted on piles or like supports, e.g. platforms on raisable legsConstruction methods therefor
E02D 27/42 - Foundations for poles, masts, or chimneys
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 making use of size exclusion chromatography data.
Disclosed herein is an apparatus for installing a pile structure in a seabed; a system for installing a pile structure in a seabed; a method for installing a pile structure in a seabed; and a method for installing an offshore wind turbine in a seabed. The apparatus (200) comprises a mobile lid (201) configured to releasably seal against an inner wall 101 of a pile structure (100) at a plurality of positions P1, P2, such that a suction volume of the pile structure (100) can be controlled during installation of the pile structure (100) in a seabed (1). A suction can be applied in the suction volume below the mobile lid (201) to thereby drive the pile structure (100) into (15) the seabed (1).
A method of identifying a location of gas breakthrough within a completed production well includes: 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 training a neural network to predict seismic data from fibre optic seismic data comprises the following steps: providing first multicomponent seismic data (1a) and first fibre optic seismic data (1b) for a region; and inputting the first multicomponent seismic data and the first fibre optic seismic data into the neural network and training the neural network to predict seismic data from fibre optic seismic data based on the inputted first multicomponent seismic data and first fibre optic seismic data (2).
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.
F02C 3/00 - Gas-turbine plants characterised by the use of combustion products as the working fluid
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
62.
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.
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 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).
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.
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 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
74.
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.
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
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
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.
G01V 11/00 - Prospecting or detecting by methods combining techniques covered by two or more of main groups
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
85.
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
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 seating device (15) having a run state and a set state, and wherein in the run state the seating 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
89.
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
G01N 27/04 - Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating impedance by investigating resistance
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
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 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
E21B 33/043 - Casing headsSuspending casings or tubings in well heads specially adapted for underwater well heads
99.
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
