04 - Industrial oils and greases; lubricants; fuels
07 - Machines and machine tools
09 - Scientific and electric apparatus and instruments
37 - Construction and mining; installation and repair services
39 - Transport, packaging, storage and travel services
40 - Treatment of materials; recycling, air and water treatment,
42 - Scientific, technological and industrial services, research and design
Goods & Services
Electrical energy from renewable sources; electrical energy
from wind-operated machines. Wind-operated machines; wind mills, offshore wind mills,
wind power plants, offshore wind power plants, wind
turbines, mill towers and mill masts, vanes for wind power
plants; parts and accessories for the aforesaid goods, not
included in other classes. Computer software and computer apparatus and equipment for
wind mills; control and surveillance apparatus for automatic
coupling of generators, automatically starting after power
outage, voltage surge protection against lightning;
microprocessors for control and voltage regulation, for
control of vibrations, phase condition and rotor speed, for
control of efficiency, of temperature, of wind direction and
of wind velocity; all related to wind mills. Erection, construction, installation, maintenance and repair
of windmills and wind power plants, offshore wind mills and
offshore wind power plants, wind turbines, mill towers, mill
masts and of vanes and other wind-operated machines;
advisory, consultancy and information relating to all the
aforesaid services. Transportation of wind mills and offshore wind power plants
and of wind turbines, mill towers, mill masts and of vanes;
storage and distribution of energy. Production of energy; production of energy by wind mills,
offshore wind mills, wind power plants, offshore wind power
plants, wind turbines, mill towers, mill masts, vanes and
other wind-operated machines. Development and testing of wind mills, wind power plants,
other wind-operated machines and components therefor;
computer programming related to wind power generation and
energy storage and distribution; scientific and
technological services and research and design relating to
wind power generation and energy storage and distribution;
industrial analysis and research services related to wind
power generation and energy storage and distribution; design
and development of computer hardware and software related to
wind power generation and energy storage and distribution;
advisory, consultancy and information relating to all the
aforesaid services.
A blade 20 for a horizontal-axis wind turbine rotor comprises a radially-outer, energy-extraction portion 32 and a radially-inner, ventilation portion 30. The radially-inner ventilation portion 30 is shaped to ventilate a central area 34 of a wake of the rotor during use such that it contains more kinetic energy compared to the wake from a conventional rotor design. The increased wind flow velocity at the centre 34 of the wake generates additional shear stresses, with corresponding turbulence development, which gives rise to increased wake diffusion.
The invention concerns a configuration of elongate subsurface heaters (20) in a subsurface oil shale formation (10) for use in hydrocarbon production. The heaters (20) are grouped into a series of columns (40), the columns extending generally perpendicular to the sedimentary layers (50) of the subsurface oil shale formation (10). The heaters may also be grouped into a series of layers, each layer extending in one sedimentary layer of the oil shale formation.
E21B 43/241 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection combined with solution mining of non-hydrocarbon minerals, e.g. solvent pyrolysis of oil shale
E21B 36/04 - Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones using electrical heaters
E21B 43/24 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
E21B 43/30 - Specific pattern of wells, e.g. optimising the spacing of wells
Formation testing which may involve circulating mud in a pipe string from a mud pit through a port in the pipe string to a downhole diverter sub, wherein the pipe string is suspended in a wellbore extending into a subterranean formation, operating a downhole pump to pump formation fluid from the formation, wherein the formation fluid comprises gas, and mixing the pumped formation fluid with circulated mud such that a proportion of the pumped formation gas in the circulated mud is maintained below a threshold value.
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
E21B 49/10 - Obtaining fluid samples or testing fluids, in boreholes or wells using side-wall fluid samplers or testers
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
A method and apparatus controls a compressor, where the compressor inlet gas may contain water and/or non-aqueous liquid. The method includes the steps of measuring temperature at the compressor inlet and/or outlet side, measuring pressure at the compressor inlet and outlet side in order to determine a compressor pressure ratio, measuring fluid mixture density at the compressor inlet and/or outlet side, measuring individual volume fractions of gas, water and non-aqueous liquid at the compressor inlet and/or outlet side, measuring fluid velocity at the compressor inlet and/or outlet side, and determining individual flow rates of gas, water and non-aqueous liquid on the basis of the measured individual volume fractions of gas, water and non aqueous liquid and the fluid velocity at the compressor inlet and/or outlet side.
A method and arrangement are proposed for introducing a CO2 composition into a subterranean geological formation for storage of CO2 therein. The CO2 composition is initially injected into the formation using a first set of injection parameters at which the CO2 composition is a supercritical fluid having first viscosity and density values. The injection parameters are then modified such that the CO2 composition is injected into the formation using at least one second set of injection parameters at which the CO2 composition is a supercritical fluid having second viscosity and density values that are different from said first viscosity and density values, wherein said injection parameters include the injection temperature, injection pressure and hydrocarbon content of the CO2 composition.
A method and arrangement are proposed for introducing a CO2 composition into a subterranean geological formation for storage of CO2 therein. The CO2 composition is initially injected into the formation using a first set of injection parameters at which the CO2 composition is a supercritical fluid having first viscosity and density values. The injection parameters are then modified such that the CO2 composition is injected into the formation using at least one second set of injection parameters at which the CO2 composition is a supercritical fluid having second viscosity and density values that are different from said first viscosity and density values, wherein said injection parameters include the injection temperature, injection pressure and hydrocarbon content of the CO2 composition.
The present invention relates to a method and an apparatus for control of a compressor, where the compressor inlet gas may contain water and/or non-aqueous liquid. The method comprises the steps of measuring temperature at the compressor (1) inlet and/or outlet side, measuring pressure at the compressor (1) inlet and outlet side in order to determine a compressor pressure ratio, measuring fluid mixture density at the compressor (1) inlet and/or outlet side, measuring individual volume fractions of gas, water and non- aqueous liquid at the compressor inlet and/or outlet side, measuring fluid velocity at the compressor inlet and/or outlet side, determining individual flow rates of gas, water and non-aqueous liquid on the basis of the measured individual volume fractions of gas, water and non-aqueous liquid and the fluid velocity at the compressor inlet and/or outlet side, based on the determined individual flow rates of gas, water and non-aqueous liquid, determining an actual fluid mixture total volumetric flow rate of gas and liquid at the compressor inlet and/or outlet side, and on the basis of the determined compressor pressure ratio and the determined actual fluid mixture total volumetric flow and/or the measured temperature and/or the measured fluid mixture density at the compressor (1) inlet and/or outlet side according to steps a-g, controlling (7, 8) a recirculation valve position of at least one recirculation valve (5, 6) arranged between the inlet and outlet side of said compressor (1) in order to ensure that the compressor does not enter into a surge regime.
The present invention relates to a method and an apparatus for control of a compressor, where the compressor inlet gas may contain water and/or non-aqueous liquid. The method comprises the steps of measuring temperature at the compressor (1) inlet and/or outlet side, measuring pressure at the compressor (1) inlet and outlet side in order to determine a compressor pressure ratio, measuring fluid mixture density at the compressor (1) inlet and/or outlet side, measuring individual volume fractions of gas, water and non- aqueous liquid at the compressor inlet and/or outlet side, measuring fluid velocity at the compressor inlet and/or outlet side, determining individual flow rates of gas, water and non-aqueous liquid on the basis of the measured individual volume fractions of gas, water and non-aqueous liquid and the fluid velocity at the compressor inlet and/or outlet side, based on the determined individual flow rates of gas, water and non-aqueous liquid, determining an actual fluid mixture total volumetric flow rate of gas and liquid at the compressor inlet and/or outlet side, and on the basis of the determined compressor pressure ratio and the determined actual fluid mixture total volumetric flow and/or the measured temperature and/or the measured fluid mixture density at the compressor (1) inlet and/or outlet side according to steps a-g, controlling (7, 8) a recirculation valve position of at least one recirculation valve (5, 6) arranged between the inlet and outlet side of said compressor (1) in order to ensure that the compressor does not enter into a surge regime.
A marine seismic source arrangement for conducting a seismic survey of a solid geological formation below water, comprises: at least one acoustic source for emitting an acoustic wave in said water, and a solid acoustic ceiling positioned in use above said acoustic source; wherein said acoustic ceiling: a) has a positive effective reflection coefficient so that down going components of said acoustic wave vertically below the source interfere constructively with components of said acoustic wave reflected from said ceiling; and b) is arranged to float on the surface of said water during use.
The present invention provides a method of recovering a hydrocarbon mixture from a subterranean formation comprising: (i) injecting an oxygen-rich gas into said formation; (ii) combusting said oxygen-rich gas in said formation thereby heating and reducing the viscosity of said hydrocarbon mixture and generating CO2-rich gas; (iii) recovering said heated hydrocarbon; and (iv) capturing at least a portion of CO2 from said CO2-rich gas.
The present invention provides a test cell for assessing a well fluid comprising: a body, an inlet means and an outlet means; a formation sample shaped to fit inside said body; and a screen sample shaped to fit inside said body.
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
15.
APPARATUS FOR SEALING TO A BROKEN PIPE AND METHOD FOR SEALING SUCH AN APPARATUS TO SUCH A BROKEN PIPE
A method and apparatus for sealing to a broken pipe conveying a first fluid under pressure. The apparatus comprises a first chamber for a pressurisable second fluid, a second chamber for a pressurisable third fluid, a first seal which is moveable from a first position, in which the first seal is free of the broken pipe during engagement of the apparatus with the broken pipe, to a second position in which, following the engagement, the first seal is in sealing and frictional contact with the broken pipe in response to an increased second fluid pressure in the first chamber, and a first connector for connecting the chamber to a source of pressurised the second fluid. A second seal and connector is also provided.
A subsea oil and/or gas production system comprises a host production facility (15) and a plurality of subsea wells (19, 20, 21). A fluid conveying network is provided that connects each subsea well to the host production facility. A separate electrical power and data network is provided for conveying direct current electrical power and data, operatively connected to each subsea well for providing each subsea well with data transfer and electrical power services. The use of direct current ensures that the electrical power and data network can provide power over much greater distances than currently available, and the use of separate networks for conveying fluids and for providing electrical power and data transfer allows for a much more flexible system.
E21B 33/035 - Well headsSetting-up thereof specially adapted for underwater installations
E21B 43/017 - Production satellite stations, i.e. underwater installations comprising a plurality of satellite well heads connected to a central station
A method and apparatus is disclosed for controlling the flow of fluid in oil and/or gas production, involving a control device or an autonomous valve (2) operating by the Bernoulli principle and comprising a moveable disk or body (9) provided within a housing (4) for opening and closing said valve (2), involving use of a material (24) within the valve (2) that changes its properties as to shape and/or volume and/or elastic modulus when exposed to a chemical substance contained in the flow of fluid and thus altering said flow of fluid.
A water injection system that includes a primary water injection line; an injection fluid supply tank; a high pressure injection pump in fluid communication with the injection fluid supply and primary water injection line for pumping injection fluid in injection fluid supply tank through the primary water injection line; a polymer gel supply tank; and a high pressure chemical injection pump in fluid communication with the polymer gel supply tank and the water injection line configured to pump polymer gel having a viscosity of at least about 50,000 cP (at 20° C. measured using a Bohlin Rheometer CSR 50, cone and plate measuring system CP 4°/40 mm, single shear rate 1/s) in the polymer gel supply tank into the water injection line for mixture with injection fluid is disclosed.
E21B 21/06 - Arrangements for treating drilling fluids outside the borehole
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
B01F 3/12 - Mixing, e.g. dispersing, emulsifying, according to the phases to be mixed liquids with solids
C02F 1/68 - Treatment of water, waste water, or sewage by addition of specified substances, e.g. trace elements, for ameliorating potable 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
A process for the recovery of hydrocarbon such as bitumen/EHO from a hydrocarbon bearing formation in which are situated an upper injection well and a lower production well, the method comprising the steps: preheating an area around and between the wells by circulating hot solvent through the completed interval of each of the wells until sufficient hydraulic communication between both wells is achieved; injecting one of more hydrocarbon solvents into the upper injection well at or above critical temperature of the solvent or solvent mixture, thereby causing a mixture of hydrocarbon and solvent to flow by gravity drainage to the lower production well; and producing the hydrocarbon to the surface through the lower production well.
A process for the recovery of hydrocarbon such as bitumen/EHO from a hydrocarbon bearing formation in which are situated an upper injection well and a lower production well, the method comprising the steps: preheating an area around and between the wells by circulating hot solvent through the completed interval of each of the wells until sufficient hydraulic communication between both wells is achieved; injecting one of more hydrocarbon solvents into the upper injection well at or above critical temperature of the solvent or solvent mixture, thereby causing a mixture of hydrocarbon and solvent to flow by gravity drainage to the lower production well; and producing the hydrocarbon to the surface through the lower production well. A non-condensable gas may be injected into the solvent chamber created by the hydrocarbon solvent.
A method and system for controlling the properties of a drilling fluid provided to a wellbore operation and/or for conducting a well operation. The method steps including: a. performing a wellbore operation using wellbore apparatus located in a wellbore; b. providing a fluid to the wellbore for facilitating the wellbore operation; c. measuring at least one property of the fluid or of cuttings carried by the fluid during performance of the wellbore operation; d. determining whether the measured fluid fulfils predetermined criteria, e. determining an alteration to the fluid provided to the wellbore using a fluid mixing model when said measured fluid does not fulfil the predetermined criteria and f. modifying the fluid provided to the wellbore using said determined alteration.
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 systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
The invention provides a method of oil treatment, e.g. following extraction of oil from a subterranean hydrocarbon reservoir, said method comprising incubating oil in an incubation vessel with a microorganism capable of digesting said oil, and recovering the digested oil.
C10G 32/00 - Refining of hydrocarbon oils by electric or magnetic means, by irradiation, or by using microorganisms
C10G 1/04 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
A hydraulic transmission system (1) for use in a wind turbine installation comprises a hydraulic pump (4a) connected via a transmission line (5,6) to a plurality of fixed displacement hydraulic motors (4b). The hydraulic motors (4b) are arranged such that they can be coupled to and drive a common load (2). The hydraulic motors (4b) can each be selectively coupled in and out of operation to drive the load (2).
F16H 61/444 - Control of exclusively fluid gearing hydrostatic with more than one pump or motor unit in operation by changing the number of pump or motor units in operation
F03D 11/02 - Transmission of power, e.g. using hollow exhausting blades
F03B 13/16 - Adaptations of machines or engines for special useCombinations of machines or engines with driving or driven apparatusPower stations or aggregates characterised by using wave or tide energy using wave energy using the relative movement between a wave-operated member and another member
24.
IMPROVED ESTIMATION OF TIME SHIFT BASED ON MULTI-VINTAGE SEISMIC DATA
The invention is a method of calculating seismic time shifts Δt(t), comprising : - conducting a number (n) of three or more seismic surveys with large time differences such as months or years, producing a number (n) of three or more vintages of seismic data d1(t), d2(t),.., dn(t)= d (t), each said vintage of seismic data dx(t) comprising one or more seismic traces, - calculating partial time derivatives from one or more base trace ∂/∂t db(t) multiplied by the sought time shift Δt(t) and setting the at product like ∂/∂t db (t) Δ t(t) = Δd, simplified to LΔt(t) = Δd wherein L comprises the partial time derivatives, and forming a set of (n-1) equations ĽΔt =Ad which is overdetermined in the series of consecutive time shifts Δt (t), - and solving for the consecutive time shifts Δt (t).
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
Apparatus for feeding a liner into a conduit. The apparatus comprises a pressure chamber (1) having a wedge-shaped end for receiving a liner (3), and a cylindrical end for delivering the liner towards a conduit (9). A clamp (4) is provided for clamping an end of the liner to said cylindrical end of the pressure chamber. A seal (2), provided at said wedge-shaped end, comprises one or more blocks (13) of resilient material fixed with respect to the pressure chamber and providing an opening into the pressure chamber through which a liner can pass, one or more compression plates (14) abutting against the block(s), and one or more adjustable clamps (15) configured in use to force the compression plate (s) against the block (s) such that the block (s) is (are) deformed so as to exert a force against a liner passing through the opening, thereby forming a substantially liquid tight seal between the liner and the interior of the pressure chamber. The apparatus further comprises a source of pressurised liquid for supplying liquid under pressure into the pressure chamber.
A method of controlling the annular pressure in a well during a well construction operation. The operation comprises pumping a fluid down a tubing located within the well and extracting the fluid that flows back through an annulus within said well and surrounding the tubing. The method comprises defining a set pressure pref, determining a desired extraction flow rate qc of fluid from said annulus in dependence upon the set pressure pref and a pumped flow rate into the annulus, and configuring an extraction path to achieve said desired extraction flow rate.
The present invention relates to grid models of geological structures. In an embodiment, it relates to forming a grid model of a geological structure by forming a grid, cutting the grid along a surface to form a grid model. In specific examples, the method includes identifying fault blocks and their bounding surfaces and individually forming a grid for each fault block. The grids may then be cut along the bounding surfaces to form block grids which reflect the geometry of the fault block. The individual block grids may then be assembled to form an assembled grid model.
A method of assessing a hydrocarbon source rock candidate uses seismic data for a region of the Earth. The data are analysed to determine the presence, thickness and lateral extent of candidate source rock based on the knowledge of the seismic behaviour of hydrocarbon source rocks. An estimate is provided of the organic content of the candidate source rock from acoustic impedance. An estimate of the hydrocarbon generation potential of the candidate source rock is then provided from the thickness and lateral extent of the candidate source rock and from the estimate of the organic content.
A method of assessing a hydrocarbon source rock candidate uses seismic data for a region of the Earth. The data are analysed to determine the presence, thickness and lateral extent of candidate source rock based on the knowledge of the seismic behaviour of hydrocarbon source rocks. An estimate is provided of the organic content of the candidate source rock from acoustic impedance. An estimate of the hydrocarbon generation potential of the candidate source rock is then provided from the thickness and lateral extent of the candidate source rock and from the estimate of the organic content.
The present invention provides a method for inhibiting scale formation within a hydrocarbon producing system (e.g. a subterranean formation), said method comprising contacting said system with a clay mineral, an organosilane and a scale inhibitor.
The present invention provides a method for inhibiting scale formation within a hydrocarbon producing system (e.g. a subterranean formation), said method comprising contacting said system with a clay mineral, an organosilane and a scale inhibitor.
The subsea well head structure (1) comprises a foundation ring (5) adapted to be supported on a seabed (3), a tubular casing portion (9) to be positioned uppermost in a borehole (13) coaxially with the foundation ring (5), a hanger structure (15) mounted on the foundation ring (5) for supporting the casing portion (9) on the foundation ring (5) through a first load supporting path, and a blow-out preventer (19) which is mounted to the foundation ring (5) through a supporting structure (21 ) supporting the blow-out preventer (19) on the foundation ring (5) through a second load supporting path in parallel to the first load supporting path of the hanger structure (15).
E21B 33/043 - Casing headsSuspending casings or tubings in well heads specially adapted for underwater well heads
33.
THE PRESENT INVENTION RELATES TO A METHOD AND MEANS FOR REAL TIME HOT X-RAY INSPECTION OF FORMATION OF COKE ON THE INTERIOR SURFACE (S) IN A FURNACE TUBE, WORKING AT HIGH TEMPERATURES
The present invention relates to a method and an apparatus for monitoring formation of coke on the interior surface in a heater or an oven. The apparatus comprises an x-ray source configured to be introduced into a pipe in the wall of the oven, and a cassette containing an imaging means, such as a film. The method comprises introducing an x-ray source through an opening in a wall of an oven or a heater and introducing a cassette containing an imaging means into another opening in the wall of the heater or the oven, taking images of the interior surface of the heater or the oven.
G01N 23/04 - 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 forming images of the material
A method of drilling is disclosed and includes pumping a wellbore fluid into a wellbore through an earth formation, wherein the wellbore fluid comprises a base fluid and a surface active agent capable of altering wettability of fines located in the earth formation, and allowing filtration of at least a portion of the wellbore fluid into the earth formation.
The present invention provides a process for simultaneously extracting and upgrading a heavy hydrocarbon mixture, said process comprising: i) injecting supercritical or near-supercritical CO2 at a temperature of around the critical temperature and a pressure of from around the critical pressure into a heavy hydrocarbon deposit; and ii) removing a stream of CO2 from the deposit, which stream is charged with a hydrocarbon mixture having a lower average molecular weight than that of the heavy hydrocarbon deposit, wherein the removed CO2 is optionally recovered and either recycled for subsequent re-injection or injected for long-term sub-surface storage.
A method of conducting a marine seismic survey of a survey area which comprises deploying a plurality of receiver cables (11) to define an active receiver area (12) the cables (11) extending in a longitudinal direction and towing a seismic source (14) behind a source vessel (13) to track across the active receiver area (12) in the longitudinal direction along a first line, turning the source vessel (13) and its source (14) around and then towing the source (14) to track back across the receiver area (12) in the reverse longitudinal direction along a second line, generally parallel to the first line. The second line is spaced from the first line in a transverse direction which is generally perpendicular to the longitudinal direction. The tracking, turning and tracking back steps are then repeated whereby the source vessel (13) and its source track across the active receiver area (12) along successively advanced lines. The source (14) is continuously fired at particular positions and/or time intervals while it is tracking the receiver area (12), and the seismic responses to the firing are continuously detected using the deployed receiver cables (11). The receivers (11) are picked up while the source (13) is being fired and redeployed.
A wellbore tubing expansion cone comprises a cone body (5) having a steel structure defining an outer conical circumferential surface portion and further comprises a coating (19) covering at least the conical surface portion of the steel structure and having a hardness higher than the hardness of the steel structure. The steel structure, at least at its conical surface portion, comprises a subsurface diffusion-modified region (21) hardened to a hardness higher than the hardness of the steel structure underlying the diffusion-modified region (21), but less than the hardness of the coating (19) covering the diffusion-modified region (21). The coating (19) is a multilayer coating comprising a plurality of layers arranged one upon another. The steel structure, the diffusion-modified region (21) and the multilayer coating (19) are adapted to provide a hardness distribution such that the hardness essentially steadily increases towards the outer surface of the cone body (5).
C23C 28/00 - Coating for obtaining at least two superposed coatings either by methods not provided for in a single one of main groups , or by combinations of methods provided for in subclasses and
An expandable pipe section (10'), intended to be joined with a corresponding pipe section (10") for use in connection with a well casing of a production well for hydrocarbons, where the pipe section (10') is configured to be screwed on or off an adjoining expandable pipe section (10"), the pipe section (10') at one end being provided with a male end having externally arranged threads (11") and where the adjoining expandable pipe section (10") is provided with a correspondingly shaped female end having corresponding internal threads (11'). The distance between adjacent threads at their widest point is less than the maximum width of a thread. Those parts of the pipe being provided with threads (11', 11") are provided with at least two step wise arranged parts with a cylindrical surface being coaxially arranged with the pipe wall(s).
A safety belt for securing personnel (1) in free-fall lifeboats and the like, comprising one or more lap belts (31) and upper body belts. A first (10) upper body belt is fastened to a seat structure (40) at a first point (11) behind the person's back and extends across the chest to a second point of attachment (12) on the seat structure (40) beyond the body, so that the first upper body belt (10) sits snugly against one side (2) of the upper body but not against the other side (3). A second upper body belt (20) is fastened to the seat structure (40) at a third point of attachment (21) behind the back and extends across the upper body from the opposite side (3) of the body to a fourth (22) point of attachment in the seat structure by or beyond the body on the other side (2) of the body, so that the second upper body belt (20) sits snugly against the other side (2) of the upper body but not the first side. The belts prevent acceleration sideways and in a forward direction.
B60R 22/00 - Safety belts or body harnesses in vehicles
A62B 35/00 - Safety belts or body harnessesSimilar equipment for limiting displacement of the human body, especially in case of sudden changes of motion
A pressure joint is provided for use with a floating installation (1) that is connected to a stiff riser (3, 12). A low pressure slip joint (5) connects the installation (1) to the stiff riser (3, 12). A telescopic assembly (13, 14) fitted with a high pressure seal (15) is arranged to be fitted within the low pressure slip joint (5) when in a non-extended configuration, such that normal operation of the low pressure slip joint (5) is not impeded.
In order to perform a passive survey, sensors (5, 8) for obtaining data relating to the structure of the region (1) are deployed on ice bodies (4) which move as a result of natural drift. The sensors (5, 8) are used to obtain data at different locations resulting from movement of the ice bodies (4) with respect to the region (1). The sensors (5, 8) may be seismometers which respond to ambient noise, for example resulting from cracking or colliding of the ice bodies (4, 24).
The present invention provides a method of determining a physiochemical property of a drilling fluid at a drilling site during a drilling phase, said method comprising detecting a nuclear magnetic resonance signal from out-of-hole drilling fluid at said site and calculating therefrom a value indicative of said property.
The apparatus for evaluating a wellbore (5) while drilling comprises a logging tool (11) held on a drill string (1) and is adapted to obtain data from the wellbore (5) while moving the drill string (1) including the logging tool (11) uphole and out of the wellbore (5). The logging tool (11) includes a memory (23) for storing obtained data and an on-board power supply battery (25). A computer (31) being positioned at a surface level of the wellbore (5) is adapted to obtain the data from the memory (23) when the logging tool (11) is also positioned at the surface level. The logging tool (11) is adapted to perform a minimum power-consuming sleep mode with a data obtaining and storing function being disabled and the computer (31) is adapted to transmit a wake-up signal downhole to enable the data obtaining and storing function of the logging tool (11) just prior to tripping out the drill string (1) from the wellbore (5). The wake-up signal preferably is a mud pulse signal sent through the drilling fluid used when drilling the wellbore (5).
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
44.
EQUIPMENT AND METHOD FOR REINFORCING A BOREHOLE OF A WELL WHILE DRILLING
The equipment for drilling and reinforcing a borehole (1) of a well comprises a drill pipe string (5) carrying a drill tool (7) at its lowermost end and a downhole treatment device (19) held on the drill pipe string (5) for applying a liner (17) of polymer material at the surface of the borehole (1). The polymer material is a fusible and/or curable material dissolved and/or emulsified and/or dispersed in drilling fluid (9) or mud circulated through the drill pipe string (5) and an annulus between the drill pipe string (5) and the wall (15) of the borehole (1). The treatment device (19) is adapted to concentrate energy for fusing and/or curing the polymer material contained in the drilling fluid (9) in a limited space (25) at the vicinity of the wall (15) of the borehole (1). The treatment device (19) thus focuses its energy in the vicinity of the wall (15) and allows a continuous reinforcing of the borehole (1) simultaneously while drilling.
The present invention provides a method for recovering hydrocarbons from a sub- surface reservoir having present therein a wellbore in which a production conduit and an injection conduit are located, said method comprising injecting a heating fluid into the reservoir via said injection conduit, characterised in that said heating fluid is released via a plurality of discrete permeable sections (injection sections) located along the length of the injection conduit and produced hydrocarbons are collected via a plurality of discrete permeable sections (production sections) located along the length of the production conduit.
A free-fall lifeboat (1) for use on offshore platforms, wherein the lifeboat is releasably secured in a launching arrangement and is configured with a closed, elongated hull provided with an elongated slide means (5 a, 5b) secured to each side of the hull along the longitudinal direction of the hull. The slide means (5a, 5b) extend from a forward point (4a, 4b) close to the bow to a realpoint (3a, 3b) astern of the lifeboat's centre of gravity (9). The launching arrangement is provided with elongated rear guide means (7a, 7b) and an arc-shaped forward guide means (6a, 6b) arranged in an inclined position from the platform and extending obliquely down towards the sea surface in a direction away from the platform. The lifeboat's forward support point (4a, 4b) is designed to slide inside the guide means (6a, 6b) so as to allow the lifeboat to fall along the whole length of the forward guide means (6a, 6b) of the launching arrangement whilst the stern end slides along the rear guide means (7a, 7b).
The present invention concerns a method for measuring the thickness of any deposit of material on the inner wall of a structure conducting a fluid stream of hydrocarbons, the method comprising the steps of: applying a first heat pulse or continuous heating to at least one first section of the structure removing deposits on the inner wall of the first section of the structure; applying a second heat pulse to both the first section of the structure and at least one second section of the structure, the first and second sections being spaced apart, which heat pulse does not loosen any deposit of material in the second section; measuring the temperature of the wall of the structure or the fluid during the second heat pulse at both the first and second sections; and determining the thickness of any deposit of material on the inner wall of the structure at the second section based on the measured temperatures. The present invention also relates to a corresponding device and arrangement.
G01B 21/08 - Measuring arrangements or details thereof, where the measuring technique is not covered by the other groups of this subclass, unspecified or not relevant for measuring length, width, or thickness for measuring thickness
The mobile offshore platform (1 ) comprises a floatable foot structure (3) adapted to be supported on the sea floor, a single vertically extending tubular column (5) affixed at its lower end to the foot structure (3) and a jack- up deck unit (7) having therethrough an opening for the passage of the column and being movable along the column (5) by means of a jack-up mechanism (41 ). A floatable annular cone element (21 ) having a substantially frusto-conical upper surface (23) and a substantially flat, or inversely coned, lower surface encloses the column (5) and is movable along the column (5) relative to the deck unit (7) between a lowermost position at which the cone element (21) rests on the foot structure (5) and an elevated position remote from the foot structure (3). Under ice-free environmental conditions, the cone element is positioned in its lowermost position to lower wave-induced forces. If the sea is covered with ice, the cone element (21 ) is raised to a position at the surface level (37) of the sea to lift and break drifting ice. In transit of the platform (1 ), the cone element (21 ) is lowered onto the foot structure (3) to increase the water-plane area and thus the floating stability of the platform (1 ). The platform (1 ) floats due to the buoyancy of the foot structure (3), the column (5) and the cone element (21) alone without floating assistance of the deck unit (7).
E02B 17/00 - Artificial islands mounted on piles or like supports, e.g. platforms on raisable legsConstruction methods therefor
E02B 17/02 - Artificial islands mounted on piles or like supports, e.g. platforms on raisable legsConstruction methods therefor placed by lowering the supporting construction to the bottom, e.g. with subsequent fixing thereto
E02B 17/08 - Equipment specially adapted for raising, lowering, or immobilising the working platform relative to the supporting construction for raising or lowering
49.
METHOD AND DEVICE FOR MEASURING THE THICKNESS OF ANY DEPOSIT OF MATERIAL ON AN INNER WALL OF A STRUCTURE
A method of measuring the thickness of any deposit of material (28) on an inner wall (12) of a structure (14). The method comprises: (a) causing vibrations in the structure; (b) detecting said vibrations in the structure; (c) determining a resonance frequency of the structure based on the detected vibrations; and (d) determining the thickness of any deposit of material on the inner wall of the structure based on the determined resonance frequency.
G01B 7/06 - Measuring arrangements characterised by the use of electric or magnetic techniques for measuring length, width, or thickness for measuring thickness
50.
METHOD OF DETECTING OR MONITORING A SUBSURFACE HYDROCARBON RESERVOIR-SIZED STRUCTURE
Subsurface hydrocarbon reservoir-sized structures are detected or monitored by ambient noise tomography. Interface wave data are recorded for interface waves excited by seismic ambient noise. The data are recorded simultaneously at pairs of locations with the locations of each pair being spaced by less than or equal to a wavelength at the frequencies of interest. The recorded data are processed (3-7) by tomography to obtain group-velocity and/or phase-velocity tomograms, which are inverted to obtain seismic parameters values, such as seismic velocity. The seismic parameters may then be used to form a geological model (8) of a subsurface region of interest.
A method of processing controlled source electromagnetic (CSEM) data is provided for reducing the airwave contribution. CSEM data are acquired, for example using a conventional towed source (4) and receiver (5) arrangement. The recorded data are weighted in accordance with the geometrical spreading of the airwave component. The differences between pairs of weighted data records are then formed.
G01V 3/12 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation operating with electromagnetic waves
There is disclosed a method of performing a controlled source electromagnetic survey, which includes in one embodiment deploying a receiver and an electric dipole source. The source defines a dipole axis. An electromagnetic field is transmitted from the electric dipole source. First and second horizontal components of an electromagnetic field response are detected using the receiver. A vertical component of the electromagnetic field response is then estimated using the detected first and second horizontal components of the electromagnetic field response.
G01V 3/12 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation operating with electromagnetic waves
Methods of enhancing oil recovery from subterranean hydrocarbon reservoirs are described, wherein a microorganism capable of digesting oil is injected into the formation.
C12P 39/00 - Processes involving microorganisms of different genera in the same process, simultaneously
C09K 8/592 - Compositions used in combination with generated heat, e.g. by steam injection
C09K 8/582 - 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 bacteria
A wellbore machining device is proposed for machining a tubular component (1) of a wellbore. The device comprises a control unit (3) at the surface level of the wellbore and a down-hole tool unit (5) connected to the control unit (3) through a wire line (7). The tool unit (5) comprises an elongated guide member (17), a tool member (9) movably supported on the guide member (17) with respect to at least three axes of motion and a plurality of actuators (11) controlled by the control unit (3) and adapted to move the tool member (9) with respect to the axes of motion. The tool unit (5) further comprises two anchor members (21) each mounted to an axial end of the guide member (17) and adapted to releasably clamp the tool unit (5) to the tubular component (1). The control unit (3) and the tool unit (5) form a computer numerical control device (CNC device) wherein the actuators (11) are electric servo motors controlling an actual position of the tool member (9) with respect to a path and/or a sequence of desired position defined by the control unit (3).
E21B 29/00 - Cutting or destroying pipes, packers, plugs or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windowsDeforming of pipes in boreholes or wellsReconditioning of well casings while in the ground
E21B 29/06 - Cutting windows, e.g. directional window cutters for whipstock operations
To remove substances having a density less than water, in particular oil, from contaminated water produced in petroleum or natural gas production, a skimming device is proposed comprising a degassing vessel (1) containing a skimming weir (17) which defines a predetermined liquid overflow level (19). The skimming weir is in the form of a weir bucket which is connected through a pipe (27) to the bottom of a separate tank (21). A liquid level control (9) maintains the level of liquid within the degassing vessel (1) below the predetermined liquid overflow level (19). A monitoring device (37, 39) detects inflow of substances from the skimming weir (17) into the container (21), whereupon the liquid level control (9) lowers the liquid level within the degassing vessel (1) to skim the oil in a sequence of batches.
A method and apparatus is disclosed for controlling the flow of fluid in oil and/or gas production, involving a control device or an autonomous valve (2) operating by the Bernoulli principle and comprising a moveable disk or body (9) provided within a housing (4) for opening and closing said valve (2), involving use of a material (24) within the valve (2) that changes its properties as to shape and/or volume and/or elastic modulus when exposed to a chemical substance contained in the flow of fluid and thus altering said flow of fluid.
A method is provided for processing measured data to provide information on the structure of a region of the earth. The method comprises providing a flexural rigidity distribution of the region, providing a Young's modulus distribution of the region, and modifying the flexural rigidity distribution with the Young's modulus distribution to obtain an equivalent elastic thickness distribution of the region indicative of the structure thereof.
Air cooled heat exchanger, comprising a pipe bundle in the shape of a number of pipe sections arranged more or less in parallel and close proximity, but with a distance that allows air flow between the pipe sections, the pipe sections being open in their ends, the pipe bundle has an inlet side with open ends and an outlet side with open ends, an inlet manifold arranged so that one inlet for warm fluid is connected to the inlet side of the pipe bundle, an outlet manifold arranged so that the outlet side of the pipe bundle is connected to one outlet for cooled fluid. The heat exchanger is further characterized in that it comprises two inlets for cold air to the pipe bundle, arranged at opposite sides of the pipe bundle, two outlet channels for warm/hot air from the pipe bundle, connected to opposite sides of the pipe bundle, and at least one fan in each of the outlet channels, arranged in a protective position within the outlet channel.
F28D 7/16 - Heat-exchange apparatus having stationary tubular conduit assemblies for both heat-exchange media, the media being in contact with different sides of a conduit wall the conduits being arranged in parallel spaced relation
The gas-liquid separator separates a variable multi-phase flow of gas and liquid in a gas dominated flow and a liquid dominated flow. The separator (1) comprises a housing (3) which encloses a separation chamber (13), an inlet port (17) for feeding the multi-phase flow into the separation chamber (13), a liquid outlet port (21) for discharging the liquid dominated flow from the separation chamber (13) and a gas outlet port (25) provided at a position above both the inlet port (17) and the liquid outlet port (21) for discharging the gas dominated flow from the separation chamber (13). Both the inlet port (17) and the liquid outlet port (21) are positioned adjacent to an elongated lower bottom wall (7) of the housing (3) and define a flow direction into the and out of the separation chamber (13) approximately aligned along the bottom wall (7), wherein the separation chamber (13) extends above the bottom wall in between the inlet port (17) and the liquid outlet port (21). The liquid outlet port (21) is provided with a gas seal to prevent entrainment of free gas from the separation chamber (13) into the liquid outlet port (21). The gas-liquid separator (1) is compact and is preferably used at an offshore sub-sea position.
A water injection system that includes a primary water injection line; an injection fluid supply tank; a high pressure injection pump in fluid communication with the injection fluid supply and primary water injection line for pumping injection fluid in injection fluid supply tank through the primary water injection line; a polymer gel supply tank; and a high pressure chemical injection pump in fluid communication with the polymer gel supply tank and the water injection line configured to pump polymer gel having a viscosity of at least about 50,000 cP (at 20°C measured using a Bohlin Rheometer CSR 50, cone and plate measuring system CP 4°/ 40 mm, single shear rate 1/s) in the polymer gel supply tank into the water injection line for mixture with injection fluid is disclosed.
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
E21B 21/01 - Arrangements for handling drilling fluids or cuttings outside the borehole, e.g. mud boxes
E21B 21/06 - Arrangements for treating drilling fluids outside the borehole
F17D 1/16 - Facilitating the conveyance of liquids or effecting the conveyance of viscous products by modification of their viscosity
61.
POLYMER GELS AS FLOW IMPROVERS IN WATER INJECTION SYSTEMS
A water injection system that includes a primary water injection line; an injection fluid supply tank; a high pressure injection pump in fluid communication with the injection fluid supply and primary water injection line for pumping injection fluid in injection fluid supply tank through the primary water injection line; a polymer gel supply tank; and a high pressure chemical injection pump in fluid communication with the polymer gel supply tank and the water injection line configured to pump polymer gel having a viscosity of at least about 50,000 cP (at 20°C measured using a Bohlin Rheometer CSR 50, cone and plate measuring system CP 4°/ 40 mm, single shear rate 1/s) in the polymer gel supply tank into the water injection line for mixture with injection fluid is disclosed.
B01F 3/12 - Mixing, e.g. dispersing, emulsifying, according to the phases to be mixed liquids with solids
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
F17D 1/16 - Facilitating the conveyance of liquids or effecting the conveyance of viscous products by modification of their viscosity
The invention provides a process for the production of an alcohol which comprises cleaving polysaccharides in a cellulosic material in an aqueous medium at a temperature of at least 45°C using a thermophilic microorganism to yield fermentable sugars, fermenting an aqueous solution of said sugars at a temperature of at least 45°C with a thermophilic microorganism to yield an alcohol or an alkanoate, if necessary reducing said alkanoate to yield an alcohol, and removing said alcohol from said aqueous solution.
Assembly of flexible risers, wherein each riser comprises an upper part extending as a chain line downward and away from position at a sea surface, an intermediate part with a length interval having buoyancy devices provided on or to the riser such that the riser within said length interval obtains positive buoyancy and the intermediate part assume a concave form directed towards the seabed, and the lower part extending as a chain line further downwards and away from the position at the sea surface to a seabed and fastening device provided on each riser in a position between the seabed and said length interval, characterized in that the assembly further comprises: a chain provided from each of the fastening devices to the seabed, wherein the upper end of the chain is fastened to the fastening device and a lower end of the chain is fastened to a fastening point provided at the seabed, wherein the weight of the chain adapted such that a number of chain links will be lifted from the seabed and a number of chain links will lay on the seabed at normal operation, said number varies according to varying loads.
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 natural gas liquefaction comprising first and second nitrogen refrigerant streams, each stream undergoing a cycle of compression, cooling, expansion and heating, during which the first nitrogen stream is expanded to a first, intermediate pressure and the second nitrogen stream is expanded to a second, lower pressure, and the heating occurs in one or more heat exchangers in which at least one of the expanded nitrogen streams is in heat exchanging relationship with natural gas, wherein, in at least one of said one or more heat exchangers, the first and second expanded nitrogen streams are in a heat exchanging relationship with the natural gas and both the first and second compressed nitrogen streams. The liquefaction can occur in three stages: in an initial stage the heated, expanded first nitrogen stream and the heated, expanded second nitrogen stream are used to cool the natural gas; in an intermediate stage the compressed first nitrogen stream is expanded to an intermediate pressure and used to cool the natural gas; and in a final stage the compressed, second nitrogen stream is expanded to a low pressure and used to cool the natural gas.
F25J 1/02 - Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen
F25J 1/00 - Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
The invention relates to a wet gas compression system comprising a compact flow conditioner (21), intended to be placed below sea level in close vicinity to a well head or on a dry installation, said flow conditioner (21) being intended to receive a multi-phase flow through a supply pipe (11) from a sub sea well for further transport of such hydrocarbons to a multi-phase receiving plant, and where preferably avoid sand accumulation or remove as much sand as possible from the multi-phase flow, the gas (G) and the liquid (L) being separated in the flow conditioner (21) whereupon the separated gas (G) and liquid (L) are re-assembled and enters a multi-phase meter (46) prior to boosting by means of a compressor (22). In the combined multi-phase pump and compressor unit (22), as an integrated unit, comprises a combined multi-phase pump and compressor unit (22) functioning on the centrifugal principle, used for trans-porting liquid and gas from a flow conditioner (21) to a remote multi-phase receiving plant.
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
Power plant comprising: a lower level reservoir, a feed-through (line, hose, pipe, channel) for fluid communication from the lower level reservoir to a higher level reservoir, characterised by a pump arranged in connection with the feed- through in order to pump water from the lower level reservoir to the higher level reservoir in order to store energy by emptying the lower level reservoir, and a turbine/generator for power production arranged in or at the lower level reservoir in connection with said feed-through, or additional feed-through, for fluid communication between the lower level reservoir and the higher level reservoir for power production during flow of water from the higher level reservoir to the lower level reservoir. A method for power production. Use of the power plant.
The invention is a method for reflection time shift matching a first and a second set of seismic reflection data (10, 30) comprising first and second seismic reflection traces (1, 3) with series of generally corresponding seismic reflections (11, 31). The first and second sets of seismic data (10, 30) are acquired with a separation in time extending over months or years. The second set of seismic data (30) comprises at least one laterally extending series (40) of new seismic events (4) not present in the first set of seismic data (10). Reflection time shifts (22) are calculated as required for matching seismic reflections (31) of the second reflection traces (3) of the second seismic reflection date (11) of the first reflection traces (1). The calculated time shifts are conducted on said second reflection traces (3). The calculation of the time shifts (22) are made by calculating coefficients of basis function estimates.
A system for recompletion of an old well (24) in order to achieve an increased oil recovery from a reservoir (26), said system comprising a pipe (27) inserted into the old well (24), at least two constrictors or swell packers (29) being arranged along the length of the recompleted well (24, 27) and defining a well section between two successive constrictors or swell packers (29), said system further comprising at least one autonomous valve (2) arranged in said well section defined between said two successive swell packers or constrictors (29). Disclosed is also a method for recompletion of an old well (24) in order to achieve an increased oil recovery from a reservoir (26).
A system for controlling the flow of fluid in a branched well from a reservoir (29), the system comprising a completed main well (27) having at least one uncompleted branch well (25), an annulus (24) defined between the reservoir (29) and a production pipe (1) of the completed main well (27) and at least two successive swell packers or constrictors (26) defining at least one longitudinal section of the main well (27) and within which at least one branch well (25) is arranged, and comprising at least one autonomous valve (2) arranged in said longitudinal section of the main well (27) defined between said two successive swell packers or constrictors (26). The uncompleted branch wells (25) are provided to increase the drainage area, i.e. maximum reservoir contact (MRC). Disclosed is also a method for controlling the flow of fluid in a branched well from a reservoir (29).
A device for fixing a valve (1) to a tubular member (2) being situated in wellbore formed in a subterranean reservoir and is having at least one drainage section (11) including a plurality of such valves as to allow the flow of fluid into and out from the tubular member, respectively. According to the present invention the valve (2) is secured to the tubular member (1) by means of a sleeve portion (3), the sleeve portion being part of the valve or is formed like a separate sleeve (4) into which the valve is to be arranged.
A tubular member having at least one drainage section (1) including a first plurality of self-adjustable valves or flow control devices (2) to control the flow of fluid into the drainage section from a well formed in a subterranean reservoir, each of the valves (2) comprising an inlet or aperture (10), thereby forming a flow path (11) through the control device (2) passing by a movable disc or body (9) designed to move freely relative to the opening of the inlet and thereby reduce or increase the flow-through area (A2) by exploiting the Bernoulli effect and any stagnation pressure created over the disc (9), whereby the valve (2), depending on the composition of the fluid and its properties, autonomously adjusts the flow of the fluid based on a pre-estimated flow design. To allow injection of fluid into the subterranean reservoir, the drainage section (1) is provided with a second plurality of such self-adjustable valves (32), each being situated in a direction opposite of the first plurality.
Assembly to separate a multiphase flow, comprising at least one compact separation unit chosen among an in-line deliquidizer and an in-line phase splitter, said compact separation unit is arranged to receive the multiphase flow for separation thereof to a gas flow and a mainly liquid containing flow, an outlet for gas, arranged to receive the gas flow from the compact separation unit and possible additional gas flows, one or more conduit separators, arranged to receive the mainly liquid containing flow from the compact separation unit and any additional liquid containing flows, having an outlet for liquid from the at least one conduit separator in a low-lying part thereof.
B04C 7/00 - Apparatus not provided for in group , or Multiple arrangements not provided for in one of the groups , , or Combinations of apparatus covered by two or more of the groups , , or
B04C 9/00 - Combinations with other devices, e.g. fans
73.
IMPROVED INTERFEROMETRIC METHODS AND APPARATUS FOR SEISMIC EXPLORATION
Interferometer apparatus for studying the surface of an object, the apparatus comprising: a source producing an object beam of coherent light; a source producing a reference beam which is coherent with the object beam; and a detector or a plurality of detectors arranged in an array; wherein the apparatus is arranged such that the object beam is diverging or substantially collimated; and wherein, in use: the diverging or substantially collimated object beam is directed towards the surface of the object to produce a reflected object beam reflected from the surface of the object; the detector(s) is/are focused to a point beneath the surface of the object; and the reflected object beam is combined with the reference beam and detected by the detector(s). Also provided is a corresponding method for conducting an interferometric study of the surface of an object. The surface of the object may be a sea floor, and the interferometer apparatus may be for studying the movement of particles on the sea floor in response to a seismic event.
A bearing system for a rotor in rotating machines, such as compressors, pumps, turbines, expanders, is characterized in that points of bearing and sealing for the rotor (16) each being in the form of a combined bearing and sealing (17) formed by a stator (18) situated within a rotating machine house and surrounding the rotor (16). The stator (18) is formed with a bore (19), whereby an annular clearance is created between stator and rotor, and the bore (19) is having sectional area gradually increasing in the direction of larger pressure (P2) within the rotating machine.
F16C 32/06 - Bearings not otherwise provided for with moving member supported by a fluid cushion formed, at least to a large extent, otherwise than by movement of the shaft, e.g. hydrostatic air-cushion bearings
F04D 29/04 - Shafts or bearings, or assemblies thereof
Separation device or unit for separating liquid from an inlet flow which mainly contains gas, the separation device comprising a container or a pipe section with an outlet for gas from the container or the pipe section, an outlet for liquid from the container or pipe section and an inlet for the inlet flow to the container or pipe section, characterised in that the separation device further comprises: a flow manifold arranged to receive and put the inlet flow in movement towards a porous pipe body extending towards the gas outlet and arranged to receive all or mainly the whole of the inlet flow, wherein part of said flow is flowing through the tubular body to the gas outlet, while the remaining of said flow is flowing through the porous wall of the tubular body, and an annular space consisting of the volume between the tubular body and the container wall or pipe section, said annular space is open for gas flow towards the gas outlet.
A gas-liquid separator (19) is disclosed, in particular for separating free water at a downhole position of a gas well. The separator (19) comprises a centrifugal separator (37) within a tubular portion (23) defining a gas inlet (27) and a gas outlet (29). Upstream of the centrifugal separator (37), the tubular portion (23) is provided with a plurality of drain holes (47) through which free water which was centrifugated to the tubular portion (23) enters an annular duct (33) allowing the collected water to flow off due to gravity. Upstream of the drain holes (47), a jet pump (51 ) is arranged. The jet pump (51 ) is driven by the gas stream to create underpressure in the duct (33) and to suck back gas which has entered the annular duct (33) through the drain holes (47). The gas-liquid separator (19) has no moving parts and avoids monitoring or controlling of the separating process.
A method for flow control and a self-adjusting valve or flow control device, in particular useful in a production pipe for producing oil and/or gas from a well in an oil and/or gas reservoir, which production pipe includes a lower drainage pipe preferably being divided into at least two sections each including one or more inflow control devices which communicates the geological production formation with the flow space of the drainage pipe. The fluid flows through an inlet (10') and further through a flow path of the control device (2) passing by a non-disc shaped movable body (9') which is designed to move relative to the opening of the inlet and thereby reduce or increase the flow-through area (A2) by exploiting the Bernoulli effect and stagnation pressure created over the body (9'), whereby the control device, depending on the composition of the fluid and its properties, automatically adjusts the flow of the fluid based on a pre-estimated flow design.
Underwater placed assembly (1) for production of gas or gas and oil/condensate from a subsea gaseous reservoir (2), where at least one production well (3) is provided from the seabed (4) to a production zone (5) and at least one water injection well (6) is provided from the seabed (4) to an injection zone (7). The assembly is characterized by comprising: - a pressure increasing device (8) connected to the outlet of the production well (3) in order to increase the pressure in a production flow from the production well, and - a water turbine (9) which is connected to and driving the pressure increasing device (8), said water turbine (9) has an inlet (10) for water with high hydrostatic pressure according to the placement of the water turbine and an outlet (11) connected to the inlet of the water injection well (6), the water turbine (9) is driven by and withdrawing at least a part of the hydrostatic energy from the water thus delivered with a lower pressure to the water injection well (6), so that water thus delivered to the water injection well (6) has a lower pressure than the hydrostatic pressure at the inlet of the water injection well. Method applying the assembly is also provided.
E21B 43/01 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
A method for injecting a fluid into an oil and or gas reservoir or formation, in which the fluid flows into the reservoir or formation through a plurality of autonomous valves or flow control devices (2) provided along an injector (24), the valves (2) having a substantially constant flow-through volume above a given differential pressure for autonomously adjusting the flow of the fluid in order to ensure a substantially constant volume rate from the injector (24) to the reservoir or formation along an injector length.
A method of drilling is disclosed and includes pumping a wellbore fluid into a wellbore through an earth formation, wherein the wellbore fluid comprises a base fluid and a surface active agent capable of altering wettability of fines located in the earth formation, and allowing filtration of at least a portion of the wellbore fluid into the earth formation.
A passive method is provided for exploring a region below the surface of the earth. The method comprises using a plurality of sensors (20, 21) to obtain seismic data obtained by recording ambient seismic interface waves in a frequency range whose lower limit is greater than 0Hz, and whose upper limit is less than or equal to substantially 1Hz. The sensors (20, 21) may be sensitive to three orthogonal components. Recordings may be made simultaneously by all sensors (20, 21) and normalisation of data is unnecessary. The sensors (20, 21) may be moved and clean data may be selected. Local dispersion curves may be determined to improve vertical resolution. The data are processed (41-44) so as to obtain a measure of the energy in a frequency band within the frequency range. The energy measure may be calculated (44) by integrating the spectrum in the frequency domain over a desired frequency range. The resulting calculated energy provides information about the region of the earth being explored.
A passive method is provided for exploring a region below the surface of the earth. The method comprises using a single sensor located in turn at a plurality of locations to obtain seismic data obtained by recording ambient seismic interface waves in a frequency range whose lower limit is greater than OHz, and whose upper limit is less than or equal to substantially 1 Hz. The data are processed (41-44) so as to obtain a measure of the energy in a frequency band within the frequency range. For example, the seismic data may be filtered (41 ) and may be subjected to amplitude normalisation (42) before being transformed (43) into the frequency domain. The energy measure may then be calculated (44) by integrating the spectrum in the frequency domain over a desired frequency range. The resulting calculated energy provides information about the region of the earth being explored.
A method and equipment for determining (measuring) the level/height, h1 - hx, of one or more interfaces between two or more fluid phases of different density that are contained in a vessel, tank (1) or the like. The position (the level) of the different interfaces in a tank (1) is determined by measuring the pressure and thus indirectly determining the density of the fluid in the tank over the height of the tank by using a pressure measuring rod (2) equipped with pressure sensors (3) which is positioned in and extends over the height of the tank (1). For determining the interfaces, a mathematical model or algorithm is used which calculates how the density and hence the pressure vary over the height of the tank as a function of the fluid properties of the respective fluids in the tank, the interface, on the basis of the density being the same within each layer of the respective fluid, being defined as a respective point (level) at which the density changes from one layer to the next in the tank.
G01F 23/14 - Indicating or measuring liquid level or level of fluent solid material, e.g. indicating in terms of volume or indicating by means of an alarm by measurement of pressure
G01N 9/26 - Investigating density or specific gravity of materialsAnalysing materials by determining density or specific gravity by measuring pressure differences
A process for the preparation of at least one ARN acid or salt thereof comprising: (I) allowing at least one ARN acid salt to form during the production of crude oil in the presence of water; (II) removing at least 5 wt% of the formed at least one ARN acid salt, e.g. from the oil water interface; and optionally (III) converting said salt into an acid.
A method is provided for forming a geological model of a region of the earth. Seismic data are obtained from the region and include seismic traveltime uncertainty. A seismic velocity model of the region is also provided and includes velocity uncertainty. Ray tracing is performed on the seismic data using the velocity model to determine the three dimensional positions of a plurality of points of the region. The three dimensional positional uncertainties (7-12) of at least some of the points are calculated from the traveltime uncertainty, the velocity uncertainty, and uncertainty in the ray propagation direction. This is combined with the positions determined by the ray tracing to form a geological model.
The present invention relates to Method for removal of wax deposited on an inner wall in contact with a fluid stream, the method comprises cooling the inner wall and the fluid stream to a temperature of or below the wax appearance temperature, which will allow for dissolved wax to precipitate on the inner wall, wherein the method further comprises the heating of the inner wall for a short period of time to release the deposited wax from the surface of the inner wall, mainly in the form of solid parts. Further the invention relates to a method of determing the thickness of wax deposits in a pipe section by computing the temperatures obtained upstream and downstream in the said pipe section, before and after applying at heat pulse.
An essentially cylindrical deadleg having a first cross sectional area at one end of said deadleg and a second cross sectional area, said first cross sectional area being smaller than said second cross sectional area.
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
E21B 41/02 - Equipment or details not covered by groups in situ inhibition of corrosion in boreholes or wells
88.
DEVICE FOR THE CONTROL OF PRODUCTION OF OIL AND GAS
Device or arrangement for control of the fluid flow in connection with production of oil and/or gas from geological formations below the surface of the earth comprising one or more wells (1 ). Each well is connected to a fluid production line and further comprising one or more chokes (2) that either may be provided on the production line from each well, from a common production string prior to downstream separation equipment, or as a combination of such provisions. The choke/s (2) is/are in the form of a displacement motor/pump such as screw type (single or twin), radial wing type, gear pump, piston/cylinder pump or a lobe pump.
B21B 43/12 - Devices for positioning workpieces "flushed", i.e. with all their axial ends arranged in line on cooling beds or on co-operating conveyors
01 - Chemical and biological materials for industrial, scientific and agricultural use
03 - Cosmetics and toiletries; cleaning, bleaching, polishing and abrasive preparations
04 - Industrial oils and greases; lubricants; fuels
07 - Machines and machine tools
09 - Scientific and electric apparatus and instruments
17 - Rubber and plastic; packing and insulating materials
29 - Meat, dairy products, prepared or preserved foods
30 - Basic staples, tea, coffee, baked goods and confectionery
31 - Agricultural products; live animals
35 - Advertising and business services
36 - Financial, insurance and real estate services
37 - Construction and mining; installation and repair services
39 - Transport, packaging, storage and travel services
40 - Treatment of materials; recycling, air and water treatment,
41 - Education, entertainment, sporting and cultural services
42 - Scientific, technological and industrial services, research and design
43 - Food and drink services, temporary accommodation
Goods & Services
Unprocessed plastic materials, petro-chemical products;
petro-chemical products, namely polymers, polypropylenes and
polyethylenes; chemical products for industrial and
scientific purposes; fire extinguishing compositions;
hydrogen. Cleaning preparations, carwash, polishing and stain removing
also for rubbing; soaps; cosmetics. Petrol, petroleum products, oil, crude oil, refined oil,
fuel-oil and fuels, dry gas, natural gas condensates; oils
and greases for industrial purposes; lubricants; dust laying
compositions; fuel (including motor spirits) and lighting
fuel; fuel pellets; fuel oil; fuel gas; candles and wicks
for candles. Wind mills, offshore wind mills, wind power plants, offshore
wind power plants, wind turbines, mill towers and mill
masts, vanes. Computer software and computer apparatus and equipment for
wind mills, control and surveillance apparatus for automatic
in and out coupling of generators and for automatic start
after power break, over voltage protection against
lightning; micro processors for control and voltage
regulation, for control of vibrations, phase condition and
rotor speed, for control of efficiency, of temperature, of
wind direction and of wind velocity; all related to wind
mills. Semi-manufactured plastics. Meat, fish, poultry and game; meat extracts; preserved,
dried, frozen and cooked fruits and vegetables, jellies,
jams, compotes, eggs, milk and milk products; edible oils
and fats, and also ready-made meals made of the already
mentioned products. Coffee, tea, cocoa, sugar, rice, tapioca, sago, artificial
coffee; flour and preparations made from cereals, bread,
pastry and confectionery, ices, ice. Agricultural, horticultural and forestry products and grains
not included in other classes; fresh fruits and vegetables. Business management of petrol stations, market surveys and
market analysis, formulation of sales strategies, promotion
strategies, identification of target market and advertising
programs. Payment service for C02-quota, insurance and financial
services. Building, installation, maintaining and repairing services
related to oil-platforms and oil pipelines; oil well
drilling; construction, installation, maintenance and repair
of windmills and wind power plants, of offshore wind mills
and offshore wind power plants and of wind turbines, mill
towers, mill masts and of vanes; maintenance and repair of
vehicles; car wash. Transportation of crude oil, heavy fuel-oil, dry gas and
storage of fuel-oil. Refining of crude oil and processing of the products of that
refining, as well as processing of dry gas, natural gas
condensates, processing of petro-chemical products. Education; providing of training; entertainment; sporting
and cultural activities. Exploitation of oil and gas; oil-field exploitation;
exploration and field development services in the marketing
of petroleum industry technology and products; engineering
services and research related to deep-water technology; oil
prospecting, planning services related to building of
oil-platforms; oil-well testing; development and testing of
wind mills and wind power plants; computer programming for
others; scientific and technological services and research
and design relating thereto; industrial analysis and
research services; design and development of computer
hardware and software. Services for providing food and drink; temporary
accommodation.
A process for the formation of biodiesel comprising: (I) obtaining a biooil containing at least one fatty acid glyceride; (II) contacting the biooil with at least one microorganism capable of hydrolysing at least one ester bond of said at least one glyceride to form a hydrolysed biooil; (III) directly or indirectly using said hydrolysed biooil in biodiesel.
C12P 7/64 - FatsFatty oilsEster-type waxesHigher fatty acids, i.e. having at least seven carbon atoms in an unbroken chain bound to a carboxyl groupOxidised oils or fats
The invention provides a method for increasing the retention of a proppant within a hydrocarbon producing system (e.g. a subterranean formation), said method comprising contacting a formation comprising said proppant with an organosilane. Kits for use in such methods and which comprise a proppant and separately an organosilane are afso provided.
The invention provides a method of enhancing oil recovery from a subterranean hydrocarbon reservoir, said method comprising injecting into said reservoir through a matrix injection section of a well a microorganism capable of digesting oil, and recovering oil from an oil receiving section of a production well, where said injection section is in said production well or is in an injection well arid is above or adjacent said oil receiving section, and wherein microorganism injection is preceded by another oil extraction enhancing procedure.
C09K 8/592 - Compositions used in combination with generated heat, e.g. by steam injection
C09K 8/582 - 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 bacteria
C12N 1/00 - Microorganisms, e.g. protozoaCompositions thereofProcesses of propagating, maintaining or preserving microorganisms or compositions thereofProcesses of preparing or isolating a composition containing a microorganismCulture media therefor
The invention provides a method of enhancing oil recovery from a subterranean hydrocarbon reservoir, said method comprising injecting into said reservoir through a matrix injection section of a well a microorganism capable of digesting oil, and recovering oil from an oil receiving section of a production well, where said injection section is in said production well or is in an injection well arid is above or adjacent said oil receiving section, and wherein microorganism injection is preceded by another oil extraction enhancing procedure.
C09K 8/592 - Compositions used in combination with generated heat, e.g. by steam injection
C09K 8/582 - 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 bacteria
C12N 1/00 - Microorganisms, e.g. protozoaCompositions thereofProcesses of propagating, maintaining or preserving microorganisms or compositions thereofProcesses of preparing or isolating a composition containing a microorganismCulture media therefor
94.
SYSTEM AND PROCESS FOR HANDLING AN CO2 COMPRISING WASTE GAS AND SEPARATION OF CO2
A system and method for handling waste gas (112) including separation of C02 is disclosed. The system comprises a horizontal tunnel with a sequence of sections comprising a cooling section. (104), a CO2 absorption section (105) and a cleansing section (106). The system further comprises- a heat exchanger (103) for heating the CO2 depleted waste gas before it is introduced into the chimney (107) with heat from the incoming untreated waste gas.
B01D 53/14 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by absorption
This invention provides a method of securing to a substrate a metal object having an uncoated surface, which method comprises contacting said substrate and said surface with an unset hydraulic cement composition and allowing said composition to set, characterized in that said surface is an aluminium surface and in that said composition comprises pulverulent aplite.
C04B 28/02 - Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing hydraulic cements other than calcium sulfates
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
The invention provides a method for cementing in a lining tube (5) in a bore hole (1), said method comprising placing said lining tube at a distal end of said bore hole, introducing a liquid hydraulic cement (10) containing a setting retarder into said distal end of said bore hole, and applying a fluctuating electromagnetic or magnetic field from within said lining tube whereby to heat cement outside said lining tube directly or via a electromagnetic radiation transmitter (17) positioned on the outside of said lining tube.
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
E21B 33/14 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
C09K 8/42 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells
97.
METHOD FOR LIQUID CONTROL IN MULTIPHASE FLUID PIPELINES
A method for the control of liquid or liquid slugs in multi phase fluid pipelines, including a multiphase pipeline (1) for the transportation of a fluid, consisting of mainly gas and some liquid such as water an/or gas condensate. The gas is evacuated via a gas separation unit (4) being connected to the multiphase pipeline (1) to a second gas transport pipe (5), whereas the liquid is fed to a dedicated pipeline section acting as a buffer volume pipeline (7), preferably provided as a continued part of the multiphase pipeline (1). The separation unit (4) includes one or preferably several vertical pipes (6) connected at a distance from one another along the multiphase pipeline (1), whereby the gas is transported separately to a downstream processing facility on a platform or onshore (3) or the like, and whereby the liquid proceeds to the loop (7) which may preferably be an extension of the multiphase pipeline, or the liquid and gas may be re-combined and led in a common transport pipeline to the desired destination.
A water-going liquefied carbon dioxide (LCD) transport vessel having a pressurized and refrigerated LCD container, a cargo discharge pump within the container for pumping LCD out of] the container along a conduit, a booster pump for pumping LCD along the conduit to a platform, a first backflow line downstream of the cargo pump to the container, a second backflow line from downstream of the booster pump to the container, and optionally a heater arranged to heat LCD flowing from the vessel along the conduit.
Method for laying a pipeline onto a seabed from a lay barge, the pipeline having an inner corrosion proof metallic cladding that is closely fitted with metallic contact to an outer pipe material that is less corrosion proof, distinguished in that a) a section of the pipeline is reeled onto a pipe laying drum, whilst an overpressure of 5-25 bar is maintained within the section by means of a pressurised fluid inside the section, b) a further pipeline section is joined to the section already reeled onto the pipe laying drum, whilst the pipeline is motionless without mechanical movement, as the overpressure can be relieved as long as the sections are without mechanical movement, c) an overpressure of 5-25 bar is applied within the sections and the further section is reeled onto the pipe laying drum, d) several sections are joined together and reeled onto one or several pipe laying drums by repeating step b) and c) until the predetermined pipeline length is achieved, e) the pipeline is laid from the lay barge onto the seabed using conventional method, whilst an overpressure of 5-25 bar is maintained within the pipeline by means of a pressurised fluid until the pipeline is correctly placed onto the seabed.
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
The present invention relates to seismic exploration techniques and the seismic imaging of subsurface layers, particularly apparatus for seismic exploration near the seafloor. The apparatus enables controlled-depth towing of detectors to be carried out a short distance above the seafloor. The apparatus includes a streamer depth controller and at least one altitude keeper device, attached at intervals along the length of a towed streamer. The streamer carries detectors for measuring, for example, P- and S-waves in the seafloor.
