An electronic inflow control device for use in a hydrocarbon producing well, the inflow control device being configured to switch electronically between an open state and a closed state, the inflow control device comprising: a housing, comprising one or more electromagnets; a gate comprising one or more permanent magnets and moveable within the housing between a closed state and an open state; the housing defining a first valve seat for receiving the gate in a closed state, and a second valve seat for receiving the gate in an open state.
A method of installing a subsea cable bundle comprising an umbilical and at least one direct current and fibre optic (DCFO) cable attached to an outside of the umbilical. The method comprises connecting a first end of the cable bundle to a pulling head, lowering the first end of the cable bundle into the se, connecting the pulling head to a winch cable of a winch (the winch may be connected before or after lowering the first end), the winch being located on a platform and the winch cable extending from the platform into the sea through a J-tube, and using the winch to pull the first end of the cable bundle up to the platform through the J-tube. The method further comprises laying the cable bundle on the seafloor, and at a target location, at or close to a subsea structure, detaching the DFCO cable from the umbilical and connecting the DCFO cable and the umbilical at their second ends to the subsea structure.
E21B 33/035 - Well heads; Setting-up thereof specially adapted for underwater installations
H02G 9/02 - Installations of electric cables or lines in or on the ground or water laid directly in or on the ground, river-bed or sea-bottom; Coverings therefor, e.g. tile
The geochemical parameters of reservoir fluid do not directly and universally correlate with the fluid type of the reservoir fluid, e.g. reservoir oil and reservoir gas. However, within an individual hydrocarbon basin, the local reservoir oils and thelocal reservoir gases are often geochemically distinct. Therefore, by examining various geochemical parameters for reservoir fluid samples taken from a particular region of interest, it is possible to identify region-specific thresholds for those geochemical parameters, and also to identify particular region-specific thresholds having a high degree of confidence for distinguishing between different reservoir fluid types.Advantageously, many geochemical parameters can be determined using mud-gas data, and in some cases using only standard mud-gas data. Therefore, by collecting mud-gas data when drilling a new well within the region of interest, these region-specific thresholds can be used to generate a substantially continuous and highly accurate reservoir fluid type log along a length of the well. This same technique may also be applied retrospectively to existing wells where mud-gas data was collected at the time of drilling, since at least standard mud-gas data is routinely collected while drilling.
E21B 47/003 - Determining well or borehole volumes
E21B 47/008 - Monitoring of down-hole pump systems, e.g. for the detection of "pumped-off" conditions
E21B 49/00 - Testing the nature of borehole 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
There is provided a method for testing a valve of a subsea tree. The method comprises: closing the valve to be tested; fluidly isolating an isolatable region of the subsea tree directly adjacent to the valve to be tested; after being isolated, depressurising the isolatable region to a pressure below an ambient, subsea pressure or pressurising the isolatable region using a pressure manipulation device positioned subsea; monitoring a pressure of the isolatable region after being depressurised; and determining whether the valve to be tested is operating correctly based on the monitoring.
E21B 33/035 - Well heads; Setting-up thereof specially adapted for underwater installations
E21B 47/117 - Detecting leaks, e.g. from tubing, by pressure testing
G01M 3/28 - Investigating fluid tightness of structures by using fluid or vacuum by measuring rate of loss or gain of fluid, e.g. by pressure-responsive devices, by flow detectors for valves
A method of generating a model for predicting at least one property of a fluid at a sample location within a hydrocarbon reservoir, the method comprising: simulating behaviour of one or more hydrocarbon reservoir during production; generating a plurality of simulated fluid samples from the one or more simulated hydrocarbon reservoir, the plurality of simulated fluid samples corresponding to a plurality of different spatial locations and/or different time locations within the one or more simulated hydrocarbon reservoir; generating a training data set comprising input data and target data based on the simulated fluid samples, the input data comprising simulated mud-gas data for each sample location indicative of mobile and immobile hydrocarbons at the sample location, and the target data comprising the at least one property of only the mobile hydrocarbons at each sample locations; and constructing a model using the training data set such that the model can be used to predict the at least one property of the fluid at a sample location based on measured mud-gas data for the sample location.
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
B01D 53/14 - Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by absorption
An inflow control device configured to switch between an open and a closed state, comprising: an inlet; an outlet; a housing; a first body and second body arranged within the housing, wherein the second body is moveable relative to the first body, wherein in an electrically energised state, the first body is operative to magnetically attract or repel the second body; wherein, in the open state, the first and second body are located at respective open positions and define a continuous path with the housing, through which fluid can flow from the inlet to the outlet; wherein, in the closed state, the first and second body are located at respective closed positions and are contiguous, thereby blocking said continuous path; and wherein, the inflow control device is operative to switch between the open and closed states by electrically energising or de-energising the first body.
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.
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
9.
METHODS FOR ESTIMATING A POSITION OF A WELL PATH WITHIN A SUBSURFACE FORMATION
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.
A method of estimating the primary and secondary acoustic velocities, Vp and Vs, of formation surrounding a first wellbore. The method comprises 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 comprises 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.
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.
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 9/00 - Prospecting or detecting by methods not provided for in groups
A method of mapping reservoir fluid in a mature field comprises 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.
A method of estimating a depth of a hydrocarbon-water contact of a hydrocarbon reservoir in a structure comprises: a. analysing one or more samples obtained from the structure to generate a relationship relating resistivity to hydrocarbon-water contact depth; b. obtaining a resistivity measurement of the hydrocarbon reservoir; and c. estimating the hydrocarbon-water contact depth from the relationship relating resistivity to hydrocarbon-water contact depth and the resistivity measurement of the hydrocarbon reservoir.
G01V 3/18 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging
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 27/04 - Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating impedance by investigating resistance
G01V 3/26 - 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 magnetic or electric fields produced or modified either by the surrounding earth formation or by the detecting device
14.
RESIDUAL CURVATURE METHOD TO MITIGATE PIPELINE BUCKLING
A method for laying a pipeline on a seabed in order to provide controlled thermal expansion, comprising: feeding the pipeline (1) from a pipeline reel (2) through a straightener system (5); and at the straightener system (5), imparting an alternating and continuously varying degree of residual curvature on at least a portion of the pipeline (1).
A floating, unmanned wellhead or production facility 1 comprises a topside 2 configured to process a hydrocarbon fluid, and a spar hull 3 supporting the topside 1. The spar hull 3 is designed to minimise maintenance and thus does not comprise many of the systems commonly found in the hull 3 of a floating offshore facility 1. Systems that are not present within the spar hull 3 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.
: A system for liquid surge protection of a subsea riser having a horizontal portion on the seabed and a sag bend portion, the system comprising: 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 further comprising an inlet device coupled to the bottom end of the flexible tubing, wherein said inlet device is biased against a bottom wall the riser.
E21B 19/22 - Handling reeled pipe or rod units, e.g. flexible drilling pipes
E21B 34/08 - Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained
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 registering geological data at a formation core tracking system, the method comprising: 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 controller for a floating wind turbine comprising a rotor with a plurality of rotor blades connected to a generator is provided. The controller comprises: 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; wherein the controller is arranged to calculate an output for controlling a blade pitch of one or more of the plurality of 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 controlling a floating wind turbine is also provided.
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 blade pitch controller for a wind turbine comprises a nominal control system and a tower feedback loop. The tower feedback loop comprises 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 method of exploring for hydrocarbons in a region comprises: (a) obtaining seismic data for the region corresponding to two or more different times; and (b) analysing the seismic data corresponding to two or more different times to determine whether there are any changes in the seismic data.
An unmanned production platform (1) comprises apparatus for producing and processing hydrocarbons from a subsea reservoir. A storage vessel (7) is provided in combination with and proximate to the platform (1), typically just outside the safety zone. The storage vessel (7) provides storage for hydrocarbons produced at the platform (1) and further provides a utility for use at the platform (1), such as chemical storage, liquid desiccant regeneration and/or seawater treatment. Typically, the unmanned production platform (1) comprises no utilities and all utilities require for production are provided by the storage vessel (7).
B63B 35/44 - Floating buildings, stores, drilling platforms, or workshops, e.g. carrying water-oil separating devices
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 43/017 - Production satellite stations, i.e. underwater installations comprising a plurality of satellite well heads connected to a central station
23.
APPARATUS AND METHOD FOR REMOVING SOIL FROM A CONDUIT
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.
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.
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 and corresponding gas processing system for 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) are provided. Cleaning of a gas compressor (6) is achieved by accumulating liquid removed from cooling gas used for cooling the gas compressor (6) and supplying the accumulated liquid to an inlet of the gas compressor (6) in order to remove deposited solid material from the gas compressor (6). The cooling gas is extracted from an intermediate stage of the gas compressor (6).
B08B 9/00 - Cleaning hollow articles by methods or apparatus specially adapted thereto
E21B 37/06 - Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting the deposition of paraffins or like substances
Herein disclosed is a well assembly 1 comprising a sensor 2 and a method of monitoring using the sensor 2. The well assembly may comprise a wellbore 7 and the sensor 2, wherein the sensor 2 is in a fixed location relative to the wellbore 7, and wherein the sensor 2 is for monitoring the size and/or shape of the wellbore 7. The method may be a method of monitoring the size and/or shape of the wellbore 7. The method may comprise: providing the sensor 2 in a fixed location relative to the wellbore 7, and monitoring the size and/or shape of the wellbore 7 using the sensor 2. The well assembly 1 may comprise a well foundation 6 and the sensor 2, wherein the sensor 2 is in a fixed location relative to the well foundation 6, and wherein the sensor 7is for monitoring the earth underneath the well foundation 6 during installation of the well assembly 1. The method may be a method of monitoring the earth underneath the well foundation 6. The method may comprise providing the sensor 2 in a fixed location relative to the well foundation 6, and monitoring the earth underneath the well foundation 6 during installation of the well assembly 1.
A method of connecting a conduit (10) to a subsea structure (20) is provided. In the disclosed method, a tensioning member (16) is provided on the conduit and attached to the conduit at two locations proximate a first end (14) 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 (30) 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.
E21B 43/013 - Connecting a production flow line to an underwater well head
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 1/16 - Laying or reclaiming pipes on or under water on the bottom
A distributed acoustic sensing system 1 for acquiring seismic data is presented. The system 1 comprises: a sensing cable 2 and an instrument float 3. The sensing cable 2 is for sensing seismic waves and is suitable for use on the seabed 22. The instrument float 3 comprises instrumentation for acquiring seismic data. The instrument float 3 is connectable or connected to the sensing cable 2 via a riser cable 8.
A method of analysing seismic data from a geological structure comprises: 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 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 comprises inverting the at least one geophysical parameter to estimate the mineral content of the geological structure.
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.
An apparatus (30) for controlling flow induced vibrations in a section of pipeline (2) caused by a flow of liquid therethrough comprising:a sensor (50) for measuring flow induced vibrations of the section of pipeline;a mechanical means (38) for adjusting the natural frequency of the section of pipeline (2); 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.
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.
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 determining the electrical permittivity (I) of a region of a subsurface formation surrounding a drilled borehole, the method comprises: obtaining an assumed electrical permittivity e LWD ; obtaining resistivity data comprising a first resistivity value R p determined by analysing the phase delay d of an electromagnetic signal traversing said region and a second resistivity value R a determined by analysing the attenuation a 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 3/30 - 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
G01V 3/18 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging
G01V 3/38 - Processing data, e.g. for analysis, for interpretation or for correction
36.
SEISMIC ACQUISITION METHOD FOR SEABED MINERAL EXPLORATION
A seismic survey system for prospecting for sub-sea minerals comprising: a first vessel 21 towing a first seismic source 22 and a seismic detector 23; and a second vessel 24 towing a second seismic source 25. The seismic detector 23 is arranged to receive acoustic signals resulting from the reflection 28 and/or refraction 31 by the sea bed 27 of acoustic signals emitted from both the first and second seismic sources.
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)6varies 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 cut6is 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.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
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. The method comprises 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 method for managing metal naphthenates in produced hydrocarbons. The method comprises 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.
C07C 7/00 - Purification, separation or stabilisation of hydrocarbons; Use of additives
C07C 7/152 - Purification, separation or stabilisation of hydrocarbons; Use of additives by treatment giving rise to a chemical modification of at least one compound by forming adducts or complexes
C07C 67/00 - Preparation of carboxylic acid esters
C07C 69/00 - Esters of carboxylic acids; Esters of carbonic or haloformic acids
C10G 17/02 - Refining of hydrocarbon oils, in the absence of hydrogen, with acids, acid-forming compounds, or acid-containing liquids, e.g. acid sludge with acids or acid-containing liquids, e.g. acid sludge
C10G 21/00 - Refining of hydrocarbon oils, in the absence of hydrogen, by extraction with selective solvents
C10G 29/00 - Refining of hydrocarbon oils, in the absence of hydrogen, with other chemicals
C10G 31/00 - Refining of hydrocarbon oils, in the absence of hydrogen, by methods not otherwise provided for
E21B 43/00 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
A method is presented for predicting which shape and/or amplitude of seismic wave or wave pulse would cause an increase in oil relative permeability when a seismic wave or wave pulse with that shape and/or amplitude is applied to a region of interest. The method comprises: (a) obtaining one or more parameter values for the region of interest; (b) inputting the one or more parameter values into a model which predicts changes in oil relative permeability for the region of interest for different seismic wave or wave pulse shapes and/or amplitudes; (c) repeating step (b) one or more times for different seismic wave or wave pulse shapes and/or amplitudes; and (d) determining which seismic wave or wave pulse shape and/or amplitude causes an increase or the greatest increase in oil relative permeability based on the output of the model.
A system for hydrocarbon production comprising a host 11 for receiving produced hydrocarbon; an offshore hydrocarbon production facility comprising: a production wellhead 1 for connection to a subsea hydrocarbon reservoir; a production platform 9 configured to receive produced fluid from the wellhead and being in fluid communication with the host via a long distance pipeline 10; 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 10 to the host.
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
A system for hydrocarbon production comprising a host 11 for receiving produced hydrocarbon; an offshore hydrocarbon production facility comprising: a production wellhead 1 for connection to a subsea hydrocarbon reservoir; a production platform 9 configured to receive produced fluid from the wellhead and being in fluid communication with the host via a long distance pipeline 10; 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 10 to the host; wherein the host 10 is configured to store the semi-stable oil product.
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
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.
A jarring device 100 and method for applying an impact to a casing 10 of a wellbore in a subterranean or subsea formation. The jarring device 100 comprises: a hammer 120 and a driving means 110 for driving the hammer 120 between a first position in which the hammer is spaced from the casing 10 and a second position in which the hammer 120 contacts the casing 10, such that the driving means 1 10 is operable during use to drive the hammer 120 from the first position to the second position so as to impact the casing 10; wherein the hammer 120 is reciprocated by the driving means 110.
There is disclosed an apparatus for axially anchoring a tool11downhole in a well casing5, the apparatus comprising: an anchor 12 configured to be disposed in, and actuatably and rotatably engaged with, the casing; and a rotatable tool1 being configured to be disposed within the casing; whereby the anchor, when rotatably engaged with the casing, prevents movement of the rotatable tool in the axial direction A whilst allowing for rotation of the tool about the axial direction. A 10 corresponding method of anchoring a tool downhole is also disclosed.
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
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
46.
INTERCONNECTION OF SUBSEA PIPELINES AND STRUCTURES
There is provided a method of interconnecting a conduit and a plurality of subsea structures. The method comprises providing a first manifold header (67) in-line of the conduit, where the first manifold header has at least one valve (2) installed therein, A portion of the conduit is lowered to the sea bed such that the first manifold header (67) is engaged with a first subsea structure (51 ), and a further portion of the conduit is lowered to the sea bed. A second manifold header (69), having at least one valve (2) installed therein, is provided in-line of the conduit and engaged with a second subsea structure (52). The length of conduit provided on the sea bed between the first subsea structure (51 ) and the second subsea structure (52) is significantly greater than the distance between the first and second subsea structures.
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 1/26 - Repairing or joining pipes on or under water
A sampling module 4 for mounting in a pipeline 18 with a multiphase flow meter 2 and for receiving multiphase fluid 16 from the pipeline 18, wherein the sampling module 4 comprises: a separation chamber 6 for receiving and separating a sample volume of fluid from the multiphase fluid 16, the separation chamber 6 having a vertical extent when in use; a lower valve 8 for opening and closing a fluid path between a lower end of the separation chamber 6 and the pipeline 18; an upper valve 10 for opening and closing a fluid path between an upper end of the separation chamber 6 and the pipeline 18; a lower sensor 12 for measuring fluid properties of the fluid in a lower part of the separation chamber 6; and an upper sensor 14 for measuring fluid properties of the fluid in an upper part of the separation chamber 6.
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
G01F 1/56 - Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow by using electric or magnetic effects
G01N 1/10 - Devices for withdrawing samples in the liquid or fluent state
G01N 11/02 - Investigating flow properties of materials, e.g. viscosity or plasticity; Analysing materials by determining flow properties by measuring flow of the material
G01N 23/02 - Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups , or by transmitting the radiation through the material
G01N 27/04 - Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating impedance by investigating resistance
A wellhead load relief device for reducing riser system induced load effects on a subsea wellhead is provided. The wellhead load relief device comprises: a receptacle for receiving a 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 a well control equipment received in the receptacle, wherein the adjustable support mechanism is located within the receptacie of the wellhead load relief device and wherein the adjustable support mechanism has a lateral extent that is adjustable relative to the receptacle, and wherein 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 comprising the wellhead load relief device is also provided. A method of installing a subsea wellhead assembly onto a subsea wellhead using a wellhead load relief device, a method of moving a well control equipment from a first wellhead to a second wellhead together with the wellhead load relief device, and a method of uninstalling a well control equipment with the wellhead load relief device in place are also provided.
A method of installing a wellhead assembly comprising a well casing and a wellhead support structure is provided. The method comprises providing the well casing; providing the 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 and allowing it to solidify to provide a rigid connection between the waterbed and the underside of the wellhead support structure, wherein 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. A wellhead assembly may also be provided. The assembly may be installed according to the method.
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
E21B 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom 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
F16L 1/12 - Laying or reclaiming pipes on or under water
F16L 1/15 - Laying or reclaiming pipes on or under water between the surface and the bottom vertically
F16L 3/00 - Supports for pipes, cables or protective tubing, e.g. hangers, holders, clamps, cleats, clips, brackets
F16L 5/00 - Devices for use where pipes, cables or protective tubing pass through walls or partitions
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.
An unmanned offshore wellhead platform 10 for use in the oil and gas industry, the platform comprising: riser hang-off equipment 13 for connection to at least one riser for flow of hydrocarbon fluids from at least one well; and process equipment 14 for processing the hydrocarbon fluids to produce processed or part processed hydrocarbon fluids for storage and/or transport to another installation, wherein all of the process equipment 14 is on a single process deck 12 of the platform 10.
B63B 35/44 - Floating buildings, stores, drilling platforms, or workshops, e.g. carrying water-oil separating devices
E02B 17/00 - Artificial islands mounted on piles or like supports, e.g. platforms on raisable legs; Construction methods therefor
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 suction anchor is provided that comprises a suction chamber bounded by: (i) a circumferential outer wall, (ii) an upper wall having a central opening, and (iii) the wall of an internal housing; the internal housing defining a passage in communication with the central opening for receiving wellhead components that may be secured to the suction anchor; the suction chamber having a minor upper portion and a major lower portion; the minor upper portion comprising internal reinforcing members extending along the inside of the upper wall from the outer walls to the internal housing; the major portion being adapted to be embedded in a seabed and the minor portion being adapted to project from the seabed when the anchor is installed; wherein the reinforcing members serve both to reinforce the upper wall of the chamber against collapse and to rigidly support the internal housing such that it may resist forces applied to it arising from bending moments applied to a wellhead components received and secured therein. A method of installing the suction anchor is also provided.
A method of installing an object under water at a desired location, the method comprising: 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.
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 eventmay 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 tool for use in a borehole to perform a milling, under reaming, or other cutting operation. The tool comprises a tool body configured for rotation about its longitudinal axis, within the borehole, and a set of cutters, the set comprising 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 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
E21B 10/26 - Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers
E21B 10/62 - Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable
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
A system for hydraulically controlling a subsea device, the system comprising 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 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 comprises initial data of a geophysical parameter and initial fluid data, and wherein the substituted data set comprises substituted fluid data, the method comprising: using (3) the model and the initial data set to calculate first calculated data of the geophysical parameter; using (5) the model and the substituted data set to calculate second calculated data of the geophysical parameter; calculating (6) the difference between the first calculated data of the geophysical parameter and the second calculated data of the geophysical parameter; and applying (7) said difference to the initial data of the geophysical parameter to produce substituted data of the geophysical parameter.
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, the method comprising: 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 said 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 said 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
F17D 1/14 - Conveying liquids or viscous products by pumping
F17D 1/16 - Facilitating the conveyance of liquids or effecting the conveyance of viscous products by modification of their viscosity
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
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 43/34 - Arrangements for separating materials produced by the well
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
F04D 31/00 - Pumping liquids and elastic fluids at the same time
F16L 55/04 - Devices damping pulsations or vibrations in fluids
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
61.
CONNECTOR FOR CONNECTING SUBSEA WELL ASSEMBLY COMPONENTS AND METHOD OF CONNECTING
There is provided 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 comprises a tension part which in use can be in tension and a compression part that in use can be in compression, and 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 comprises 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; and wherein the first subsea well assembly component and the second subsea well assembly component are additionally connected such that forces can be transmitted both in tension and compression between the two components without going through the well conduit. The force transmission connection may be by means of the connector.
A method of at least partially deghosting recorded seismic s-waves, wherein recorded seismic data is provided, wherein said recorded seismic data has been recorded at a receiver (15) located beneath the Earth's surface (13), and wherein said recorded seismic data comprises s-wave data, the method comprising: finding (3) a model (10) of the Earth's crust for use in deghosting the recorded seismic data using the s-wave data, wherein the model comprises at least one region (11, 12, 16) and wherein the model comprises the Earth's surface (13) and the location of the receiver (15); using (4) said model (10) to find a deghosting operator that, when applied to the s-wave data, at least partially deghosts the s- wave data; and applying (5) 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
An offshore oil and gas platform 14, 16 has a power supply system with a cascaded arrangement for a black start. The power supply system comprises: a first power supply apparatus 60 for providing power at a first energy level; an uninterruptible power supply arrangement configured to receive power from the first power supply apparatus 60, wherein the uninterruptible power supply is for powering at least one essential and/or safety critical component of the oil and gas platform 14, 16; and a second power supply apparatus 66, 68 for providing power at a second energy level to a main power distribution system 64 of the offshore platform 14, 16, wherein the second energy level is higher than the first energy level, wherein the second power supply apparatus comprises a power source 68, 70 and a high-power energy storage system 66 capable of supplying power at the second energy level, and wherein the second power supply apparatus 66, 68 can receive energy from the first power supply apparatus 60 and can store energy from the first power supply apparatus 60 in the high-power energy storage system 66. A control system 62 is used for controlling the first and second power supply apparatuses, and the control system 62 is arranged to perform a black start routine to provide full power to the offshore platform 14, 16 via the main power distribution system 64 after a shutdown of the power source 68, 70 in the second power supply apparatus. The black start routine includes using the first power supply apparatus 60 to initiate the uninterruptible power supply and thereby power up the at least one essential and/or safety critical component; and then using the high-power energy storage system to power 66 up the power source 68, 70.
H02J 4/00 - Circuit arrangements for mains or distribution networks not specified as ac or dc
B63B 35/44 - Floating buildings, stores, drilling platforms, or workshops, e.g. carrying water-oil separating devices
H02J 9/00 - Circuit arrangements for emergency or stand-by power supply, e.g. for emergency lighting
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 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 13/00 - Investigating surface or boundary effects, e.g. wetting power; Investigating diffusion effects; Analysing materials by determining surface, boundary, or diffusion effects
G01N 27/02 - Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating impedance
G01N 27/04 - Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating impedance by investigating resistance
G01N 27/92 - Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating breakdown voltage
Methods of Enhanced Oil Recovery (EOR) from an oil reservoir by C02 flooding are disclosed. One method comprises producing a well stream from the reservoir; separating the well stream into a liquid phase and a gas phase with a first gas/liquid separator, wherein the gas phase comprises both C02 gas and hydrocarbon gas; cooling the gas phase with a first cooler; compressing the gas phase using a first compressor into a compressed stream; mixing the compressed stream with an external source of C02 to form an injection stream; and injecting the injection stream into the reservoir. Systems for EOR from an oil reservoir by C02 flooding are also disclosed.
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.
C09K 8/00 - Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
C09K 8/58 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
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
C10G 33/04 - De-watering or demulsification of hydrocarbon oils with chemical means
E21B 43/00 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
E21B 43/16 - Enhanced recovery methods for obtaining hydrocarbons
67.
OFFSHORE HYDROCARBON PROCESSING FACILITY AND METHOD OF OPERATION
An offshore hydrocarbon processing facility (2) comprises an offshore floating structure (8) and a submerged floating riser deck (10). The submerged floating riser deck is operatively connected to a subsea hydrocarbon riser (12). Hydrocarbon processing equipment (26) is disposed on the submerged floating riser deck. The offshore floating structure (8) may be connected to the submerged floating riser deck (10) using a riser (16) that can be disconnected if there is inclement weather.
B63B 21/50 - Anchoring arrangements for special vessels, e.g. for floating drilling platforms or dredgers
B63B 27/00 - Arrangement of ship-based loading or unloading equipment for cargo or passengers
B63B 35/44 - Floating buildings, stores, drilling platforms, or workshops, e.g. carrying water-oil separating devices
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 for pressure protection of an offshore platform (14, 16) of an oil and gas installation, the offshore platform (14, 16) being connected to source of hydrocarbons via a pipeline (18), the method comprising: using a safe link device (62) at the pipeline (18); wherein the safe link device (62) is located subsea and outside of the safety zone of the platform (14), (17); protecting the platform via a subsea High Integrity Pressure Protection System (HIPPS) for the platform (14, 16) and/or the pipeline (18); and wherein the safe link device (62) is arranged to activate to release pressure from the pipeline (18) when the pressure exceeds a preset threshold that is above the normal ultimate limit state pressure for the platform (14, 16).
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 eing 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 suction anchor for a subsea well is provided. The suction anchor comprises: a wellhead support structure, wherein the wellhead support structure is at least in part external of the internal volume.
A subsea well assembly for monitoring and/or controlling fluid within an annulus within the assembly is provided. The assembly comprises: 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 assembly comprises a wellhead support for laterally supporting the high pressure wellhead housing, wherein at the 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 an annulus within the assembly is also provided.
A foundation for a subsea assembly is provided. The foundation comprises connection points. The connection points permit other components to be connected to the suction anchor and permit loads to transfer from the component connected to the connection points into the foundation. The foundation may be a suction anchor. A method of converting an exploration well using such a foundation to a production well is provided.
A subsea assembly comprising; 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 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 with a connection bridge. This provides a fluidic connection between the subsea structure and the header pipe joint. The subsea structure 5 comprises a foundation 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 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.
G01V 5/04 - Prospecting or detecting by the use of nuclear radiation, e.g. of natural or induced radioactivity specially adapted for well-logging
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
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
G01N 23/083 - Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups , or by transmitting the radiation through the material and measuring the absorption the radiation being X-rays
76.
SYSTEM AND METHOD FOR PROVIDING INFORMATION ON PRODUCTION VALUE AND/OR EMISSIONS OF A HYDROCARBON PRODUCTION SYSTEM
A system 101 for providing information on production value and/or emissions of a hydrocarbon production system 1, the system 101 comprising: a plurality of sensors 102, 103, 104, 105, 106, 107, 108 configured to measure a respective plurality of measured parameters 109 of the hydrocarbon production system; an input interface 111 for inputting a plurality of specified parameters 114 into the system 101; and a processor 110 configured to determine the production value and/or emissions of the hydrocarbon production system 1 in real time based upon the measured parameters 109 and the specified 114 parameters.
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 41/00 - Equipment or details not covered by groups
A reelable pipeline comprising 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 further comprising 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.
Apparatus for monitoring the quality of gas in a process stream (12) at a subsea location comprises: a container (20) for permanent installation at the location; one or more devices (40) for analysing gas quality, said devices (40) being located in the container (20); and means for supplying a sample of gas from the process stream to the said one or more devices; wherein the pressure (20) 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.
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.
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.
An offshore oil and gas platform 14, 16 has equipment and piping associated with an oil and gas installation. A method for optimising fire protection for the platform 14, 16 comprises: arranging the platform 14, 16 to have an evacuation time of at most 15 minutes or less using one or more evacuation route(s) via a gangway or bridge 136 allowing personnel to escape to a vessel or to another platform 14, 16; determining a maximum evacuation time for the platform 14, 16; assessing the risk to personnel using the evacuation route(s) in accordance with the determined maximum evacuation time in the event of a fire; and providing passive fire protection to equipment and/or piping on the platform 14, 16 in order to prevent escalation of the fire that would create a risk to personnel on the evacuation route(s) during the determined evacuation time.
A method for handling of hydrocarbons on an offshore platform 14, 16 includes the absence of emergency depressurisation for a fire. The method comprises: arranging the platform 14, 16 such that there is no mechanism for emergency depressurisation of a hydrocarbon inventory of the platform 14, 16 in the event of a fire; restricting the size of the platform 14, 16 such that evacuation of personnel can be achieved prior to escalation of a fire due to the lack of emergency depressurisation; and permitting a fire to escalate by combustion of the hydrocarbon inventory after evacuation of the personnel.
A marine installation system for installing an item on a riser, comprises: a cable extending between two supporting points, said cable being inclined relative to the horizontal; a first ROV arranged to mount said item on said cable at a first position; and a second ROV arranged to remove said item from said cable at a second position, and to install said item on said riser.
A subsea umbilical laying method is described, which comprises mechanically coupling (1) an umbilical termination assembly (20) at an end of a first umbilical to an umbilical termination assembly (21) at an end of a second umbilical, and subsequently deploying the mechanically coupled ends of the first and second umbilical together in a subsea umbilical laying process.
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
F16L 11/133 - Hoses, i.e. flexible pipes made of rubber or flexible plastics with arrangements for particular purposes, e.g. specially profiled, with protecting layer, heated, electrically conducting buoyant
A method of installing or removing a subsea wellhead assembly is provided. The method comprising providing a suction anchor that in use acts as a subsea well foundation, wherein the suction anchor comprises an outer suction skirt; and an inner member, wherein the inner member comprises a high pressure wellhead housing; and installing or removing the suction anchor together with the high pressure wellhead housing on or from a seabed.
A method of controlling a choke valve in a managed pressure drilling (MPD) system comprising: a) measuring to determine a dataset comprising, for each of a plurality of time steps: a fluid flow rate through the drill bit, a value of fluid flow rate through the control choke, a fluid flow rate from the back pressure pump and a fluid pressure at the control chokes; b) executing an inversion algorithm on the PLC to obtain the bulk modulus of a fluid within the annulus, the inversion algorithm taking the dataset as an input, wherein the inversion algorithm accounts for a measurement bias 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.
According to a first aspect of the present invention there is provided a method of controlling a borehole drilling process comprising a first set of operations and a second set of operations, the method comprising: generating and outputting at least one control signal by a drilling control system for controlling at least one control parameter associated with the first set of operations; and, subsequent to an indication that the first set of operations is complete, outputting at least one control signal received from an external system at the drilling control system for controlling at least one control parameter associated with the second set of operations.
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 41/00 - Equipment or details not covered by groups
A subsea structure 18 includes a support 6 in the form of a foundation or a supporting structure mounted to a foundation and being for transferring loads to the foundation. A method for installing a pipeline 19 at such a subsea structure 18 includes: providing the support 6 with a pull-in point 22 at a proximal location, wherein the proximal location is at a first side of the support 6; providing the support 6 with a strong point 20 at a distal location, wherein the distal location is spaced apart from the proximal location and there is a straight clear path between the pull-in point 22 and the strong point 20, this clear path bridging some of or all of a width of the support 6; passing a pull down wire 24 through a guide 21 at the strong point 20 and using the pull down wire 24 to pull in the pipeline 19; laying down the pipeline 19 and passing the pull down wire 24 along the clear path; and continuing the laying down and/or pulling in until a tie -in head 25 of the pipeline 19 is at a required location at the pull-in point 22.
A method of generating geophysical data using at least one source, the method comprising generating a geophysical wavefield with a varying signature using at least one source, wherein the signature is varied in a periodic pattern.
G01V 1/28 - Processing seismic data, e.g. analysis, for interpretation, for correction
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 3/38 - Processing data, e.g. for analysis, for interpretation or for correction
A process for generating power using a gas turbine, comprising the steps of: (i) vaporising and pre-heating liquid ammonia to produce pre-heated ammonia gas; (ii) introducing the pre-heated ammonia gas into an ammonia-cracking device suitable for converting ammonia gas into a mixture of hydrogen and nitrogen; (iii) converting the pre-heated ammonia gas into a mixture of hydrogen and nitrogen in the device; (iv) cooling the mixture of hydrogen and nitrogen to give a cooled hydrogen and nitrogen mixture; (v) introducing the cooled hydrogen and nitrogen mixture into a gas turbine; and (vi) combusting the cooled hydrogen and nitrogen mixture in the gas turbine to generate power.
F02C 3/20 - Gas-turbine plants characterised by the use of combustion products as the working fluid using a special fuel, oxidant, or dilution fluid to generate the combustion products
B01D 53/00 - Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols
F02C 3/30 - Adding water, steam or other fluids to the combustible ingredients or to the working fluid before discharge from the turbine
F02C 6/00 - Plural gas-turbine plants; Combinations of gas-turbine plants with other apparatus; Adaptations of gas-turbine plants for special use
F02C 9/40 - Control of fuel supply specially adapted to the use of a special fuel or a plurality of fuels
An artificial lift method is provided which is suitable for use in heavy oil reservoirs. The method comprises injecting a combination of water and gas into a well to create artificial lift.
A system for sensing pressure within an annulus of a wellbore, the system comprising one or more tubulars extending from the surface into the annulus, wherein the one or more tubulars are filled with gas.
A subsea wellhead assembly is provided. The subsea wellhead assembly comprises: a conductor; a subsea wellhead; and subsea riser system equipment mounted on the subsea wellhead; wherein the subsea riser system equipment is connected to the conductor such that forces can be transmitted from the subsea riser equipment to the conductor.
CA 03015507 2018-08-22 ABSTRACT The method of installing a subsea pipeline (1) having a direct tie-in to a subsea structure (5) comprises landing an end (101) of a pipeline on a pipeline landing frame (6) on a surface of a subsea structure (5), the pipeline landing frame (6) providing a location for landing an end (101) of a pipeline (1) before connection to a connection point of the subsea structure (5), subsequently lowering the pipeline end (101); and connecting the pipeline end to a connection point of the subsea structure (5). A pipeline landing frame (6) for implementing the method is also described.
A method of calculating the radiogenic heat production (RHP) of a geophysical structure, wherein there is provided at least one geophysical parameter of the geophysical structure, the method comprising inverting the at least one geophysical parameter to estimate the RHP of the geophysical structure.
A method of conducting a pressure integrity test for an underground formation (42), the method comprising: whilst fluid is supplied to and/or released and returned from the underground formation (42) under pressure, using an automated monitoring and supervisory system (26) to: monitor the pressure of the fluid being supplied to and/or returned from the underground formation (42) in real-time, monitor the volume of 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 they vary relative to each other and/or with time during the real-time monitoring thereof, and analyse the monitored pressure and volume data using the relationship(s) either in real-time or after completion of the pressure integrity test in order to provide information and/or warnings concerning one or more of: parameters relating to the underground formation (42), the performance of the test during testing, the outcome of the test, the quality of the monitored data, or test metrics such as leakage rate, air trap, plugged choke, system compliance surface pressure and surface volume. Real-time analysis may be used to provide real-time information and warnings to improve the pressure integrity test process. Volume measurements with steps of 10 litres or less and sampling rate of 5 seconds or less may advantageously be used.
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 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
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
A system for optimising injection of a diluent to one, some or all of one or more wells comprising a downhole pump and holding means for the diluent, said holding means being connected to the or each well via one or more injection lines through which the diluent may be pumped by diluent injection means, characterised in that said system comprises measurement means for real time measurement of one or more production performance parameters, and measurement of the rate of injection of the diluent; and means for optimising the injection of the diluent to at least one of said one or more wells on the basis of: (i) means for making controlled variations of the diluent injection into the at least or each well; (ii) means for the processing of the real time measurements of the production performance parameters affected by these variations to determine any necessary adjustment of the injection of the diluent towards an optimal value; and (iii) if required, making the corresponding physical adjustment of the injection of the diluent in order to bring production performance closer to the optimal point, as well as a method for said optimisation.
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
98.
METHOD AND SYSTEM FOR PROCESSING A FLUID PRODUCED FROM A WELL
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.
A method and system for calculating the viscosity of cement slurry used for a primary cementing of an oil or gas well (12) comprises: pumping the cement slurry along a conduit (16) to a cementing location (20); measuring a first pressure loss along a first, horizontal portion (28) of the conduit (16) and a second pressure loss along a second, vertical portion (30) of the conduit (16); and calculating a viscosity of the cement slurry based at least in part on the first and second pressure losses and a flow rate of the cement slurry.
G01N 9/26 - Investigating density or specific gravity of materials; Analysing materials by determining density or specific gravity by measuring pressure differences
G01N 11/00 - Investigating flow properties of materials, e.g. viscosity or plasticity; Analysing materials by determining flow properties
100.
METHOD AND APPARATUS FOR DEHYDRATION OF A HYDROCARBON GAS
A method of dehydrating a hydrocarbon gas stream comprises stripping water from a liquid desiccant stream using a water-undersaturated portion of the gas stream, drying the gas stream to extract the stripped water, and then further drying the partially-dried gas stream using the stripped desiccant to achieve a low water content level in the gas stream for pipeline transportation. In one embodiment, the liquid desiccant is supplied by a regeneration facility at a remote location and the liquid desiccant is returned to the regeneration facility for regeneration after drying the gas. In another embodiment, the regeneration of the desiccant is performed locally whereby the liquid desiccant is, after drying the gas, stripped again of water and reused locally.
C10G 70/04 - Working-up undefined normally gaseous mixtures obtained by processes covered by groups , , , , by physical processes
B01D 53/14 - Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by absorption
C10L 3/10 - Working-up natural gas or synthetic natural gas
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