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).
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 corpuscular radiation using light without selection of wavelength, e.g. sensing reflected white light
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 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 walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
G01V 11/00 - Prospecting or detecting by methods combining techniques covered by two or more of main groups
A method of mapping reservoir fluid in a mature field includes identifying a region of interest within a hydrocarbon field, drilling a plurality of production wells through the region of interest, and collecting mud gas data as each production well is drilled. This mud gas data is used to generate a reservoir fluid property log, such as gas-oil ratio log, along a length of each of the production wells, which is in turn used to generate a refined model based on the 4D seismic data. The refined model permits better reservoir fluid mapping and has an improved vertical resolution at the region of interest than the first model of the field.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
8.
RESERVOIR FLUID PROPERTY ESTIMATION USING MUD-GAS DATA
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 position of a well path within a subsurface formation of the Earth, the method comprising determining a well path estimate using navigation measurements from a downhole tool and a position estimate derived from seismic data. A method of geosteering comprising: estimating a position of the well path and controlling a drill bit in response to the estimated position of the well path to follow a desired well trajectory.
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
11.
METHOD FOR ESTIMATING DEPTH OF HYDROCARBON RESERVOIR
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 walls; Formation testing; Methods 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 detecting; Measuring 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
12.
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 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 movements; Apparatus 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 heads; Setting-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.
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.
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.
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.
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.
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.
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 walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
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 method of connecting a lower pipe portion to a subsea foundation is provided. The method comprises: providing the subsea foundation, wherein the subsea foundation comprises an upper pipe portion connected to the subsea foundation, deploying the subsea foundation subsea; and connecting the lower pipe portion to the upper pipe portion. A subsea foundation system is also provided. The subsea foundation system comprises: a subsea foundation; an upper pipe portion connected to the subsea foundation, and a lower pipe portion, wherein the subsea foundation system is arranged such that subsea the lower pipe portion can be connected to the upper pipe portion. 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 subsea foundation may comprise a pipe overlap section that is arranged to overlap a portion of the upper pipe portion and/or the lower pipe portion when the lower pipe portion is connected to the upper pipe portion.
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 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 systems; Systems 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 member; Means 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 converting; Transducers 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 - Seismology; Seismic 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 method of estimating a mineral content of a seabed geological structure is provided wherein there is provided at least one geophysical parameter of the geological structure. The method includes inverting the at least one geophysical parameter to estimate the mineral content of the geological structure.
G01N 23/2251 - Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups , or by measuring secondary emission from the material using electron or ion microprobes using incident electron beams, e.g. scanning electron microscopy [SEM]
G01V 1/38 - Seismology; Seismic or acoustic prospecting or detecting specially adapted for water-covered areas
A method of installing a subsea pipeline for tie-in to a subsea structure includes laying, using a pipe laying vessel, an intermediate section of the pipeline on to a pipe restraint device, wherein the pipe restraint device is at or near the subsea structure, or is at or near a location at which a subsea structure will be installed, and the pipe restraint device restricts transverse movement of the pipeline. The intermediate section of the pipeline is configured to be tapped at or near the pipe restraint device for providing fluid communication between the pipeline and the subsea structure.
F16L 1/235 - Apparatus for controlling the pipe during laying
E21B 43/013 - Connecting a production flow line to an underwater well head
F16L 1/19 - Laying or reclaiming pipes on or under water on the bottom the pipes being S- or J-shaped and under tension during laying the pipes being J-shaped
F16L 41/06 - Tapping pipe walls, i.e. making connections through the walls of pipes while they are carrying fluids; Fittings therefor making use of attaching means embracing the pipe
36.
Prediction of Reservoir Fluid Properties from Mud-Gas Data
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.
An apparatus for controlling flow induced vibrations in a section of pipeline caused by a flow of liquid therethrough comprising: a sensor for measuring flow induced vibrations of the section of pipeline; a mechanical means for adjusting the natural frequency of the section of pipeline; wherein the mechanical means automatically adjusts the natural frequency of the section of pipeline based on the measured vibration in order to reduce the flow induced vibration.
F16L 55/04 - Devices damping pulsations or vibrations in fluids
F16L 3/10 - Supports for pipes, cables or protective tubing, e.g. hangers, holders, clamps, cleats, clips, brackets substantially surrounding the pipe, cable or protective tubing divided, i.e. with two members engaging the pipe, cable or protective tubing
F16F 15/00 - Suppression of vibrations in systems; Means or arrangements for avoiding or reducing out-of-balance forces, e.g. due to motion
F16F 15/02 - Suppression of vibrations of non-rotating, e.g. reciprocating, systems; Suppression of vibrations of rotating systems by use of members not moving with the rotating system
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.
F04D 31/00 - Pumping liquids and elastic fluids at the same time
E21B 43/34 - Arrangements for separating materials produced by the well
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
39.
SEISMIC ACQUISITION SYSTEM AND METHOD FOR SEABED MINERAL EXPLORATION
A seismic survey system for prospecting for sub-sea minerals including a first vessel towing a first seismic source and a seismic detector and a second vessel towing a second seismic source. The seismic detector is arranged to receive acoustic signals resulting from the reflection and/or refraction by the sea bed of acoustic signals emitted from both the first and second seismic sources.
A method of determining the electrical permittivity εkf of a region of a subsurface formation surrounding a drilled borehole includes: obtaining an assumed electrical permittivity εLWD; obtaining resistivity data comprising a first resistivity value Rp determined by analysing the phase delay d of an electromagnetic signal traversing said region and a second resistivity value Ra determined by analysing the attenuation α of the electromagnetic signal traversing said region; and calculating the electrical permittivity of the region from the first and second resistivity values and the assumed electrical permittivity by applying a plane wave approximation to the propagation of said electromagnetic signal across said region.
G01V 3/38 - Processing data, e.g. for analysis, for interpretation or for correction
G01V 3/30 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electromagnetic waves
A floating platform, preferably of the spar type, for treating seawater to provide prepared water for injection into a well extending through the seabed. The platform includes an elongate hull structure vertically position-able in a body of water such that the majority of the hull structure is submerged in the body of water, a deck secured to the top of the hull structure so that the deck lies above a surface of the body of water, and a chamber located within or substantially, within the hull structure so that the chamber is also submerged in the body of water and including a water inlet at a lower end of the chamber and a treated water outlet at an upper end, the chamber containing one or more cells for performing an anti-bacterial treatment on water passing up through the chamber from the inlet to the outlet. The platform further includes a pump for pumping water through the chamber from the inlet to the outlet through the cell or cells. In one configuration, the platform may be a spar platform.
A method of plugging a well extending into a formation to facilitate temporary or permanent abandonment of the well. The method comprises conveying a plug placement and verification tool (PPVT) through the well, to a plug formation location, the PPVT comprising a stinger for delivering a plugging material into the well, an expandable packer disposed at one end of the stinger and a pressure sensor disposed below the expandable packer, and operating the expandable packer to form a seal in the well above the pressure sensor. The method further comprises delivering a plugging material from the stinger into a region of the well above the expandable packer, thereby forming a plug in the well, and thereafter creating a pressure change above the plug and verifying the integrity of the plug using the pressure sensor.
E21B 29/02 - Cutting or destroying pipes, packers, plugs, or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground by explosives or by thermal or chemical means
E21B 33/126 - Packers; Plugs with fluid-pressure-operated elastic cup or skirt
E21B 33/13 - Methods or devices for cementing, for plugging holes, crevices, or the like
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 offshore oil and gas platform has a power supply system with a cascaded arrangement for a black start. The power supply system includes a first power supply apparatus for providing power at a first energy level, an uninterruptible power supply arrangement configured to receive power from the first power supply apparatus, wherein the uninterruptible power supply is for powering at least one essential and/or safety critical component, and a second power supply apparatus for providing power at a second energy level to a main power distribution system, wherein the second energy level is higher than the first energy level, wherein the second power supply apparatus includes a power source and a high-power energy storage system capable of supplying power at the second energy level, and wherein the second power supply apparatus can receive and store energy from the first power supply apparatus.
H02J 9/06 - Circuit arrangements for emergency or stand-by power supply, e.g. for emergency lighting in which the distribution system is disconnected from the normal source and connected to a standby source with automatic change-over
H02J 3/00 - Circuit arrangements for ac mains or ac distribution networks
H02J 13/00 - Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network
A method for managing metal naphthenates in produced hydrocarbons includes injecting acid and/or sour gas into produced hydrocarbons in a production well, flowline or riser, to thereby control the pH of fluids contained in the produced hydrocarbons.
C09K 8/524 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning organic depositions, e.g. paraffins or asphaltenes
C09K 8/536 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning characterised by their form or by the form of their components, e.g. encapsulated material
46.
Method of analysing seismic data to detect hydrocarbons
A method of analysing seismic data to detect possible hydrocarbons includes determining a set of data tiles from a seismic data cube of seismic data and testing each data tile in the set of data tiles to determine whether it corresponds to a possible fluid contact.
A method of producing a fluid from a hydrocarbon well, the fluid comprising an emulsion of water and oil and where the proportion of water (water cut) varies over time. The method comprises: determining whether the water cut of the produced fluid is within the oil/water inversion range; and when the water cut is within the oil/water inversion range, adding water to the produced fluid in order to increase its water cut to above the oil/water inversion range. Thus, the fluid produced transitions from the water-in-oil phase to the oil-in-water phase without (at least significantly) entering the inversion phase.
F17D 1/17 - Facilitating the conveyance of liquids or effecting the conveyance of viscous products by modification of their viscosity by mixing with another liquid
A method for desalting produced hydrocarbons includes injecting reduced-salinity water into produced hydrocarbons in a production well or riser, to dilute high-salinity produced water contained in the produced hydrocarbons.
A system for providing information on production value and/or emissions of a hydrocarbon production system is disclosed. The system includes: a plurality of sensors configured to measure a respective plurality of measured parameters of the hydrocarbon production system; an input interface for inputting a plurality of specified parameters into the system; and a processor configured to determine the production value and/or emissions of the hydrocarbon production system in real time based upon the measured parameters and the specified parameters.
E21B 47/10 - Locating fluid leaks, intrusions or movements
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
A method of plugging a well includes lowering a solid body into a wellbore by wireline; and filling the space around the solid body with a liquid plugging material. The solid body and the liquid plugging material together form a plug after the liquid plugging material is set.
E21B 23/14 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for displacing a cable or a cable-operated tool, e.g. for logging or perforating operations in deviated wells
E21B 27/02 - Dump bailers, i.e. containers for depositing substances, e.g. cement or acids
A wellhead load relief device for reducing riser system induced load effects on a subsea wellhead and a method of installing a subsea wellhead assembly onto a subsea wellhead using the wellhead load relief device. The wellhead load relief device includes: a receptacle for receiving well control equipment, wherein the receptacle has an open top to permit the well control equipment to be received in the receptacle; and an adjustable support mechanism for rigidly supporting well control equipment received in the receptacle. The adjustable support mechanism is located within the receptacle and the adjustable support mechanism has a lateral extent that is adjustable relative to the receptacle. The wellhead load relief device is for providing a load path for forces exerted on the well control equipment to the seabed without going via the subsea wellhead. A subsea wellhead assembly including the wellhead load relief device is also provided.
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
F16L 1/26 - Repairing or joining pipes on or under water
E21B 43/013 - Connecting a production flow line to an underwater well head
E21B 33/035 - Well heads; Setting-up thereof specially adapted for underwater installations
54.
Method of calculating temperature of a geological structure
A method of calculating the temperature of a geological structure is disclosed, wherein there is provided a magnetic parameter of the geological structure. The method includes inverting the magnetic parameter to estimate the temperature of the geological structure.
G01V 3/30 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electromagnetic waves
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
G01V 3/34 - Transmitting data to recording or processing apparatus; Recording data
G01V 3/38 - Processing data, e.g. for analysis, for interpretation or for correction
G01V 3/40 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for measuring magnetic field characteristics of the earth
A system for surge protection of a riser adapted to transport gas from a hydrocarbon production well or for surge protection in a well, the system comprising: a flexible tubing, wherein a portion of the flexible tubing extends into the riser or into the well and wherein the tubing terminates inside the riser or inside the well; a pressure control system arranged to create a pressure differential within the flexible tubing such that liquid is drawn from the riser or the well into the flexible tubing if liquid is present in the riser or the well; wherein the length of said portion of the flexible tubing is variable depending on the amount of liquid drawn into the flexible tubing.
A method of reducing the pressure of a liquid includes the steps of providing a conduit containing a packing material, such that a large number of small passages are formed in the packing material, and passing the liquid through the conduit and the packing material. The amount of packing material through which the liquid flows can be varied to vary the pressure drop experienced by the liquid passing through the packing material. The reduction in pressure achieved may be stepwise (discrete) or continuous. The method may be used to reduce the pressure of an aqueous polymer solution for use in a polymer flood technique for oil extraction, and allows the pressure to be reduced without damage to the polymer.
B01F 25/452 - Mixers in which the materials to be mixed are pressed together through orifices or interstitial spaces, e.g. between beads characterised by elements provided with orifices or interstitial spaces
F16K 47/08 - Means in valves for absorbing fluid energy for decreasing pressure and having a throttling member separate from the closure member
E21B 21/10 - Valves arrangements in drilling-fluid circulation systems
E21B 43/16 - Enhanced recovery methods for obtaining hydrocarbons
B01F 101/00 - Mixing characterised by the nature of the mixed materials or by the application field
A wellhead assembly and a method of installing a wellhead assembly. The method includes providing a well casing; providing a wellhead support structure; locating and fixing the well casing in a hole in the waterbed, wherein when the well casing is located and fixed in the hole the wellhead support structure is located a distance above the waterbed so as to leave a gap between the surface of the waterbed and the underside of the wellhead support structure; and fixing the wellhead support structure onto the surface of a waterbed with a settable material by putting the settable material into the gap when in a non-solid state to provide a rigid connection between the waterbed and the underside of the wellhead support structure. The assembly is arranged so that bending moments applied to the wellhead assembly can be at least partially transferred to the waterbed via the wellhead support structure.
An assembly for installing an object under water at a desired location, including a vessel arranged to carry the object; a submersible frame; and a connection between the object and the submersible frame. In use the vessel is spatially separated from the submersible frame along the direction of the water surface. The object, the connection and the submersible frame are arranged such that, when releasing the object from the vessel, the object becomes submerged and carries out a pendulum motion until the object is suspended from the submersible frame.
E02B 17/02 - Artificial islands mounted on piles or like supports, e.g. platforms on raisable legs; Construction methods therefor placed by lowering the supporting construction to the bottom, e.g. with subsequent fixing thereto
A method of conducting a pressure integrity test for an underground formation includes: whilst fluid is supplied to and/or released and returned from the underground formation under pressure, using an automated monitoring and supervisory system to: monitor the pressure of the fluid being supplied to and/or returned from the underground formation in real-time, monitor a volume of the fluid that is supplied to and/or returned from the underground formation in real-time, determine one or more relationship(s) for the monitored pressure and the monitored volume as the pressure and the volume vary relative to each other and/or with time during the real-time monitoring thereof, and analyze the monitored pressure and volume data using the one or more relationship(s) either in real-time or after completion of the pressure integrity test in order to provide information and/or warnings concerning at least one parameter relating to the underground formation.
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
E21B 47/117 - Detecting leaks, e.g. from tubing, by pressure testing
In a jarring device and method for applying an impact to a casing of a wellbore in a subterranean or subsea formation, the jarring device includes a hammer and a driving means for driving the hammer between a first position in which the hammer is spaced from the casing, and a second position in which the hammer contacts the casing, such that the driving means is operable during use to drive the hammer from the first position to the second position so as to impact the casing. The hammer is reciprocated by the driving means.
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
A system for hydrocarbon production comprising a host for receiving produced hydrocarbon; an offshore hydrocarbon production facility comprising: a production wellhead for connection to a subsea hydrocarbon reservoir; a production platform configured to receive produced fluid from the wellhead and being in fluid communication with the host via a long distance pipeline wherein the wellhead is local to the production platform, and the production platform is configured to process the produced fluid to provide a semi-stable oil product suitable for exporting along the long distance pipeline to the host; wherein the host is configured to store the semi-stable oil product.
E21B 43/017 - Production satellite stations, i.e. underwater installations comprising a plurality of satellite well heads connected to a central station
E21B 43/40 - Separation associated with re-injection of separated materials
E21B 43/013 - Connecting a production flow line to an underwater well head
63.
System and method for offshore hydrocarbon processing
A system for hydrocarbon production comprising a host for receiving produced hydrocarbon; an offshore hydrocarbon production facility comprising: a production wellhead for connection to a subsea hydrocarbon reservoir; a production platform configured to receive produced fluid from the wellhead and being in fluid communication with the host via a long distance pipeline; wherein the wellhead is local to the production platform, and the production platform is configured to process the produced fluid to provide a semi-stable oil product suitable for exporting along the long distance pipeline to the host.
E21B 43/017 - Production satellite stations, i.e. underwater installations comprising a plurality of satellite well heads connected to a central station
G06F 30/20 - Design optimisation, verification or simulation
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
A method of calculating the temperature and/or porosity of a geological structure, wherein there is provided at least two geophysical parameters of the geological structure, the method including inverting the at least two geophysical parameters to estimate the temperature and/or porosity of the geological structure.
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
G06F 17/11 - Complex mathematical operations for solving equations
A subsea well installation is provided, comprising a first pipeline comprising a first valve arrangement and a second pipeline comprising a second valve arrangement. The first valve arrangement is connected to a first subsea well and the second valve arrangement is connected to a second subsea well. The first valve arrangement is connected to the second valve arrangement. The installation is arranged such that fluid can be routed from the first well to any of the first pipeline and second pipeline. Each valve arrangement may comprise three two-way ball valves. Also provided is a method of installing the subsea well installation and a method of operating the subsea well installation.
E21B 34/06 - Valve arrangements for boreholes or wells in wells
E21B 43/013 - Connecting a production flow line to an underwater well head
E21B 43/017 - Production satellite stations, i.e. underwater installations comprising a plurality of satellite well heads connected to a central station
67.
Method and system for monitoring influx and loss events in a wellbore
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.
A method of generating geophysical data using at least one source. The method may include the steps of generating a geophysical wavefield with a varying signature using at least one source, wherein the signature is varied in a periodic pattern.
G01V 1/00 - Seismology; Seismic or acoustic prospecting or detecting
G01V 3/00 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation
G01V 1/37 - Effecting static or dynamic corrections on records, e.g. correcting spread; Correlating seismic signals; Eliminating effects of unwanted energy specially adapted for seismic systems using continuous agitation of the ground
G01V 3/08 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation operating with magnetic or electric fields produced or modified by objects or geological structures or by detecting devices
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spread; Correlating seismic signals; Eliminating effects of unwanted energy
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 41/10 - Guide posts, e.g. releasable; Attaching guide lines to underwater guide bases
E02B 17/02 - Artificial islands mounted on piles or like supports, e.g. platforms on raisable legs; Construction methods therefor placed by lowering the supporting construction to the bottom, e.g. with subsequent fixing thereto
A method of starting up flow of viscous oil in a pipeline, wherein the pipeline has an inlet and an outlet and wherein the viscous oil is initially stationary within the pipeline, includes supplying water to a first section of the pipeline through an inflow control device; initiating a flow of viscous oil within the first section towards the outlet by pressurising the water; supplying water to a second section of the pipeline through a further inflow wherein the first section is closer to the outlet of the pipeline than the second section; and initiating a flow of viscous oil within the second section towards the outlet by pressurising the water.
F17D 1/17 - Facilitating the conveyance of liquids or effecting the conveyance of viscous products by modification of their viscosity by mixing with another liquid
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
F15D 1/02 - Influencing the flow of fluids in pipes or conduits
A method of separating fluid phases in a well or riser. The method comprises: locating an inlet device of a flexible tubing at a substantially horizontal portion of the well or riser, wherein a portion of the flexible tubing extends into the well or riser and the flexible tubing terminates at the inlet device; biasing the inlet device against a wall of the well or riser; and extracting a stratified fluid phase from the well or riser through the inlet device and flexible tubing, wherein a shape of the inlet device is configured to match a shape of the wall.
There is provided a method of interconnecting a conduit and a plurality of subsea structures. The method comprises providing a first manifold header in-line of the conduit, where the first manifold header has at least one valve installed therein, A portion of the conduit is lowered to the sea bed such that the first manifold header is engaged with a first subsea structure, and a further portion of the conduit is lowered to the sea bed. A second manifold header, having at least one valve installed therein, is provided in-line of the conduit and engaged with a second subsea structure. The length of conduit provided on the sea bed between the first subsea structure and the second subsea structure is significantly greater than the distance between the first and second subsea structures.
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 1/19 - Laying or reclaiming pipes on or under water on the bottom the pipes being S- or J-shaped and under tension during laying the pipes being J-shaped
A sampling module is for mounting in a pipeline with a multiphase flow meter and for receiving multiphase fluid from the pipeline. The sampling module includes: a separation chamber for receiving and separating a sample volume of fluid from the multiphase fluid, the separation chamber having a vertical extent when in use; a lower valve for opening and closing a lower fluid path between a lower end of the separation chamber and the pipeline; an upper valve for opening and closing an upper fluid path between an upper end of the separation chamber and the pipeline; a lower sensor for measuring fluid properties of the fluid in a lower part of the separation chamber; and an upper sensor for measuring fluid properties of the fluid in an upper part of the separation chamber.
G01F 1/74 - Devices for measuring flow of a fluid or flow of a fluent solid material in suspension in another fluid
G01L 19/00 - MEASURING FORCE, STRESS, TORQUE, WORK, MECHANICAL POWER, MECHANICAL EFFICIENCY, OR FLUID PRESSURE - Details of, or accessories for, apparatus for measuring steady or quasi-steady pressure of a fluent medium insofar as such details or accessories are not special to particular types of pressure gauges
G01N 1/20 - Devices for withdrawing samples in the liquid or fluent state for flowing or falling materials
G01F 25/10 - Testing or calibration of apparatus for measuring volume, volume flow or liquid level or for metering by volume of flowmeters
G01N 9/24 - Investigating density or specific gravity of materials; Analysing materials by determining density or specific gravity by observing the transmission of wave or particle radiation through the material
G01N 27/06 - Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating impedance by investigating resistance of a liquid
A method of installing an object under water at a desired location includes providing the object on a vessel, connecting the object to a submersible frame located below the water surface, wherein the vessel is spatially separated from the submersible frame along the direction of the water surface, releasing the object from the vessel such that the object becomes submerged and carries out a pendulum motion until the object is suspended from the submersible frame, and moving the object to the desired location.
E02B 17/02 - Artificial islands mounted on piles or like supports, e.g. platforms on raisable legs; Construction methods therefor placed by lowering the supporting construction to the bottom, e.g. with subsequent fixing thereto
A tool for use in a borehole to perform a milling, under reaming, or other cutting operation includes a tool body configured for rotation about its longitudinal axis, within the borehole, and a set of cutters, the set including two or more cutters which, at least in a deployed configuration, extend outwardly from the tool body and are fixedly coupled together whilst being pivotally coupled to the tool body substantially on said axis so that the cutters rotate with the tool body whilst being pivotable together relative to the tool body during cutting.
E21B 29/00 - Cutting or destroying pipes, packers, plugs, or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground
E21B 10/32 - Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
A system for hydraulically controlling a subsea device includes a compensator provided within a cavity of a well system, a hydraulic connection between the compensator and the subsea device, a pressure regulator arranged to regulate the hydraulic pressure provided to the subsea device and a ventilation tool for releasing pressure at the subsea device.
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.
A method of processing a fluid produced from a well, the produced fluid being a high pressure fluid, the method comprising: reducing the pressure of the fluid to a reduced pressure such that a gas phase and a liquid phase are formed; separating the gas phase from the liquid phase thus forming a gas product and a liquid product; and storing the liquid product in a storage tank at a pressure such that the liquid product remains in a stable liquid phase during storage, wherein the reduced pressure is greater than atmospheric pressure.
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 subsea wellhead assembly and a method of installing a subsea well head assembly. The subsea wellhead assembly includes: a conductor; a subsea wellhead; and subsea riser system equipment mounted on the subsea wellhead. The subsea riser system equipment is connected to the conductor such that forces can be transmitted from the subsea riser equipment to the conductor in both tension and compression.
E21B 33/035 - Well heads; Setting-up thereof specially adapted for underwater installations
E21B 33/043 - Casing heads; Suspending casings or tubings in well heads specially adapted for underwater well heads
E21B 33/076 - Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells specially adapted for underwater installations
A method of fluid substitution, wherein an initial data set is provided, wherein a substituted data set is provided, wherein a rock physics model is provided, wherein the initial data set includes initial data of a geophysical parameter and initial fluid data, and wherein the substituted data set includes substituted fluid data. The method includes using the model and the initial data set to calculate first calculated data of the geophysical parameter, using the model and the substituted data set to calculate second calculated data of the geophysical parameter, calculating the difference between the first calculated data of the geophysical parameter and the second calculated data of the geophysical parameter, and applying the difference to the initial data of the geophysical parameter to produce substituted data of the geophysical parameter.
There is provided a wellhead assembly that includes a production well, a first valve, process equipment, a transport pipe for transporting fluid away from the wellhead assembly, and piping fluidly connecting the production well to the first valve, process equipment, and the transport pipe. The first valve is located between the production well and the process equipment, and there is a fall in the piping between the first valve and the transport pipe such that when the first valve is closed liquid will drain from the first valve into the transport pipe under the action of gravity. There is also provided a method of draining the wellhead assembly, an arrangement for depressurising the wellhead assembly using a service line and a method of depressurising the wellhead assembly.
A subsea well assembly includes a high pressure wellhead housing; and a port for monitoring and/or controlling fluid within an annulus within the high pressure wellhead housing. The port extends through the high pressure wellhead housing. The subsea well assembly further includes a wellhead support for laterally supporting the high pressure wellhead housing, wherein, at an axial height of the port, the wellhead support surrounds the high pressure wellhead housing at circumferentially discrete locations and the port is located at a circumferential location where the high pressure wellhead housing is not covered by the wellhead support. A method of monitoring and/or controlling fluid within the annulus within the subsea well assembly is also provided.
E21B 33/035 - Well heads; Setting-up thereof specially adapted for underwater installations
E21B 33/043 - Casing heads; Suspending casings or tubings in well heads specially adapted for underwater well heads
E21B 33/076 - Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells specially adapted for underwater installations
E21B 34/04 - Valve arrangements for boreholes or wells in well heads in underwater well heads
A suction anchor for a subsea well is provided. The suction anchor includes a wellhead support structure. The wellhead support structure is at least in part external of the internal volume of the suction anchor.
E21B 33/038 - Connectors used on well heads, e.g. for connecting blow-out preventer and riser
E02B 17/02 - Artificial islands mounted on piles or like supports, e.g. platforms on raisable legs; Construction methods therefor placed by lowering the supporting construction to the bottom, e.g. with subsequent fixing thereto
A method of at least partially deghosting recorded seismic s-waves, wherein recorded seismic data is provided, wherein the recorded seismic data has been recorded at a receiver located beneath the Earth's surface, and wherein the recorded seismic data includes s-wave data. The method may include the steps of finding a model of the Earth's crust for use in deghosting the recorded seismic data using the s-wave data, wherein the model includes at least one region and wherein the model includes the Earth's surface and the location of the receiver, using the model to find a deghosting operator that, when applied to the s-wave data, at least partially deghosts the s-wave data, and applying the deghosting operator to the s-wave data to at least partially deghost the s-wave data.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spread; Correlating seismic signals; Eliminating effects of unwanted energy
G01V 1/28 - Processing seismic data, e.g. analysis, for interpretation, for correction
A method of assessing the effect of a production chemical on the stability of a water and oil emulsion, the emulsion comprising the production chemical, is provided. The method comprises: applying a potential difference across the emulsion at a detection site; measuring a current flowing through the emulsion due to the applied potential difference; and using this measured current to assess the effect of the production chemical. The step of using the measured current to assess the effect of the production chemical may comprise determining, based on the measured current, whether a critical potential of the emulsion has been reached or exceeded. The emulsion may be a crude oil emulsion. It may be a water-in-oil emulsion. The production chemical may be an emulsion breaker. Also provided is an apparatus for assessing the effect of a production chemical on a water and oil emulsion.
G01N 27/06 - Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating impedance by investigating resistance of a liquid
G01N 13/00 - Investigating surface or boundary effects, e.g. wetting power; Investigating diffusion effects; Analysing materials by determining surface, boundary, or diffusion effects
A method of seismic modeling using an elastic model, the elastic model including a grid having a grid spacing sized such that, when synthetic seismic data is generated using the elastic model, synthetic shear wave data exhibits numerical dispersion, the method including: generating generated synthetic seismic data using the elastic model, wherein the generated synthetic seismic data includes synthetic compression wave data and synthetic shear wave data, and modifying the generated synthetic seismic data to produce modified synthetic seismic data by attenuating at least some of the synthetic shear wave data in order to attenuate at least some of the numerically dispersive data.
A wellhead is provided. The wellhead comprises a high pressure wellhead housing; a casing hanger assembly located within the high pressure wellhead housing; and a casing supported on the casing hanger assembly. The casing hanger assembly is arranged so that the casing is able to move relative to the high pressure wellhead housing. This may be to accommodate well growth experienced by the wellhead during use.
A connector for connecting two subsea well assembly components; wherein the connector is arranged such that it can be preloaded in both tension and compression concurrently. The connector includes a tension part which in use can be in tension and a compression part that in use can be in compression. The tension part has an adjustable length and/or the compression part has an adjustable length. There is also provided a subsea well assembly, that includes a first subsea well assembly component; and a second subsea well assembly component; wherein the first subsea well assembly component and the second subsea well assembly component are connected to each other to provide a well conduit therebetween. The first subsea well assembly component and the second subsea well assembly component are connected such that forces can be transmitted both in tension and compression between the two components without going through the well conduit.
An offshore oil and gas platform has a power supply system with a cascaded arrangement for a black start. The power supply system includes a first power supply apparatus for providing power at a first energy level, an uninterruptible power supply arrangement configured to receive power from the first power supply apparatus, wherein the uninterruptible power supply is for powering at least one essential and/or safety critical component, and a second power supply apparatus for providing power at a second energy level to a main power distribution system, wherein the second energy level is higher than the first energy level, wherein the second power supply apparatus includes a power source and a high-power energy storage system capable of supplying power at the second energy level, and wherein the second power supply apparatus can receive and store energy from the first power supply apparatus.
H02J 3/00 - Circuit arrangements for ac mains or ac distribution networks
H02J 9/06 - Circuit arrangements for emergency or stand-by power supply, e.g. for emergency lighting in which the distribution system is disconnected from the normal source and connected to a standby source with automatic change-over
H02J 13/00 - Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network
A sensor apparatus for a downhole tool 12 comprises a sensor 24 for taking downhole measurements; and a sensor support 26, 28 for mounting the sensor 24 to the downhole tool 12. The sensor support 26, 28 includes an actuator 26 for moving at least a part of the sensor 24 in a direction extending along a longitudinal axis of the downhole tool 12, such that in use the moveable part(s) of the sensor 24 can move relative to the tool 12 in a direction extending along a longitudinal axis of a borehole. The sensor apparatus is arranged to log measurements from the sensor using a point on the tool 12 as a reference to determine relative depth between measurements without using an external reference point to obtain an indication of the absolute depth of the measurements.
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelines; Protecting measuring instruments in boreholes against heat, shock, pressure or the like
G01V 11/00 - Prospecting or detecting by methods combining techniques covered by two or more of main groups
E21B 47/09 - Locating or determining the position of objects in boreholes or wells; Identifying the free or blocked portions of pipes
A subsea assembly including; a foundation, a support device; and a subsea equipment adapter frame is provided. The foundation, support device and subsea equipment adapter frame are separate modular components that can be installed separately. The foundation may be a suction anchor. A method of installing and uninstalling the subsea assembly is also provided.
E02B 17/02 - Artificial islands mounted on piles or like supports, e.g. platforms on raisable legs; Construction methods therefor placed by lowering the supporting construction to the bottom, e.g. with subsequent fixing thereto
A method of 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 is provided. The method comprises the steps of supplying a liquid cleaning agent to a gas inlet of the gas compressor, the liquid cleaning agent being capable of removing the deposited solid material; passing the liquid cleaning agent through the gas compressor to a gas outlet of the gas compressor, 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; and recovering a fluid containing removed material that is output from the gas compressor so as to prevent the removed material reaching one or more gas processing stages of the gas processing system downstream of the gas compressor.
A method of installing a header pipe joint at a subsea structure is provided, comprising providing a header pipe joint having at least one valve installed therein and connecting the header pipe joint inline of a spool or pipeline prior to lowering the header pipe joint to the subsea structure. The header pipe joint is then lowered to the subsea structure, and the valve 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. This provides a fluidic connection between the subsea structure and the header pipe joint. The subsea structure comprises a foundation, e.g. suction anchors, which provide support for both a wellhead and the header pipe joint. A subsea assembly comprising a subsea structure, header pipe joint and connection bridge is also provided.
The present invention relates to a method for removing hydrocarbons from produced water, comprising: (i) separating produced water from a hydrocarbon and water mixture extracted from a subterranean formation: (ii) contacting said produced water with multivalent metal cations to produce a mixture of produced water and multivalent metal cations; and (iii) removing hydrocarbons from said mixture in a hydrocyclone and/or a compact flotation unit to give treated produced water, wherein the concentration of hydrocarbons in said produced water is less than 10% wt.
C02F 1/24 - Treatment of water, waste water, or sewage by flotation
C02F 1/38 - Treatment of water, waste water, or sewage by centrifugal separation
C02F 1/52 - Treatment of water, waste water, or sewage by flocculation or precipitation of suspended impurities
C09K 8/588 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific polymers
q in one or more of said measurements; c) updating one or more control parameters of the PLC based on the value for the bulk modulus; and d) manipulating the control choke using the PLC to attain a desired pressure in the system.
A method of conducting a pressure integrity test for an underground formation includes: whilst fluid is supplied to and/or released and returned from the underground formation under pressure, using an automated monitoring and supervisory system to: monitor the pressure of the fluid being supplied to and/or returned from the underground formation in real-time, monitor a volume of the fluid that is supplied to and/or returned from the underground formation in real-time, determine one or more relationship(s) for the monitored pressure and the monitored volume as the pressure and the volume vary relative to each other and/or with time during the real-time monitoring thereof, and analyze the monitored pressure and volume data using the one or more relationship(s) either in real-time or after completion of the pressure integrity test in order to provide information and/or warnings concerning at least one parameter relating to the underground formation.
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
E21B 47/117 - Detecting leaks, e.g. from tubing, by pressure testing
98.
System and method for providing information on production value and/or emissions of a hydrocarbon production system
A system for providing information on production value and/or emissions of a hydrocarbon production system is disclosed. The system includes: a plurality of sensors configured to measure a respective plurality of measured parameters of the hydrocarbon production system; an input interface for inputting a plurality of specified parameters into the system; and a processor configured to determine the production value and/or the emissions of the hydrocarbon production system in real time based upon the measured parameters and the specified parameters.
E21B 47/10 - Locating fluid leaks, intrusions or movements
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
Apparatus for monitoring the quality of gas in a process stream at a subsea location comprises: a container for permanent installation at the location; one or more devices for analysing gas quality, said devices being located in the container; and means for supplying a sample of gas from the process stream to the said one or more devices; wherein the pressure within the container is maintained at or near to atmospheric pressure. The invention also extends to a method of monitoring the quality of gas in a process stream at a subsea location.
G01N 30/88 - Integrated analysis systems specially adapted therefor, not covered by a single one of groups
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
E21B 41/00 - Equipment or details not covered by groups
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 41/06 - Work chambers for underwater operations, e.g. temporarily connected to well heads
A reelable pipeline includes a pipe-in-pipe section and a single pipe section coupled to the pipe-in-pipe section. The single pipe section has a bending stiffness that is different from the bending stiffness of the pipe-in-pipe section. The reelable pipeline includes a transition piece connected between the pipe-in-pipe section and the single pipe section and having a bending stiffness that varies along its length.
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