Abstract: A method 2 of determining the location of deposits in a flowline comprises providing 4 a distributed vibration sensor along the flowline, measuring 6 vibrations along the flowline with the sensor and analyzing 8 the measured vibrations to determine the location of any deposits. The vibration measurements are made using a distributed fiber optic sensor provided on the flowline. The measurements are analyzed in real time to identify deposit formation and location within the flowline.

Abstract: A method, device, and system for determining whether liquid enters a subsea system includes a flow line having an inside bore capable of carrying producing fluids from a subsea wellhead to a floating production storage and offloading vessel (FPSO). An annulus is defined between an innermost sheath that surrounds the inside bore and an outermost sheath at an exterior of the flow line. The device further includes a housing element disposed within the annulus and in hydraulic communication with the annulus; a sensor element disposed at a predetermined location within the housing element; and data acquisition equipment capable of: determining environmental characteristics of the annulus based on measurements made by the sensor element, and determining at least one of the presence, location, and rate of collection of liquids in the subsea system based on the environmental characteristics of the annulus.

Abstract: A method of monitoring a subsea pipeline system connecting one or more wells to a floating production system, wherein the pipeline system is at least partially flexible, the method comprises installing a continuous optical fiber distributed sensor as part of the pipeline system, the sensor capable of providing a distributed measurement of temperature, vibration, pressure or strain, or any combination thereof; using the sensor to obtain a distributed measurement of temperature, vibration, pressure and/or strain along at least part of the pipeline system indexed to a length thereof; and using the distributed measurement to predict the actual condition of the fluid, the pipeline system and/or the adjacent sea water using a model.

Abstract: A system for measuring a parameter within a well comprises a first and second apparatus. The first apparatus comprises a first reel of first wound optic fiber line (or fiber) able to be unwound from the first reel and at least a first sensor able to measure the parameter of the well, wherein information on the parameter can be transmitted through the first optic fiber. The second apparatus comprises a second reel of second wound optic fiber line able to be unwound from the second reel, an extremity of the second optic fiber being fixed to a reference point. A light transmitter or receiver device is linked to the reference point and able to generate or detect a light pulse through the second optic fiber line. Means to exchange the light pulse between first and second optic fiber line are also provided.

Abstract: A method, device, and system for determining whether liquid enters a subsea system includes a flow line having an inside bore capable of carrying producing fluids from a subsea wellhead to a floating production storage and offloading vessel (FPSO). An annulus is defined between an innermost sheath that surrounds the inside bore and an outermost sheath at an exterior of the flow line. The device further includes a housing element disposed within the annulus and in hydraulic communication with the annulus; a sensor element disposed at a predetermined location within the housing element; and data acquisition equipment capable of: determining environmental characteristics of the annulus based on measurements made by the sensor element, and determining at least one of the presence, location, and rate of collection of liquids in the subsea system based on the environmental characteristics of the annulus.

Abstract: A method 2 of determining the location of deposits in a flowline comprises providing 4 a distributed vibration sensor along the flowline, measuring 6 vibrations along the flowline with the sensor and analysing 8 the measured vibrations to determine the location of any deposits. The vibration measurements are made using a distributed fibre optic sensor provided on the flowline. The measurements are analysed in real time to identify deposit formation and location within the flowline.

Abstract: A method of monitoring a subsea pipeline system connecting one or more wells to a floating production system, wherein the pipeline system is at least partially flexible, the method comprises installing a continuous optical fibre distributed sensor as part of the pipeline system, the sensor capable of providing a distributed measurement of temperature, vibration, pressure or strain, or any combination thereof; using the sensor to obtain a distributed measurement of temperature, vibration, pressure and/or strain along at least part of the pipeline system indexed to a length thereof; and using the distributed measurement to predict the actual condition of the fluid, the pipeline system and/or the adjacent sea water using a model.

Abstract: A method for improving the recovery efficiency of storing fresh water into an aquifer, the storing includes injecting the fresh water and extracting the injected fresh water by a single water storage system that includes at least one well penetrating into the aquifer, the method includes: providing a plurality of screens, each screen being located alongside a wall of at least one well, and each screen respectively allowing a flow of fresh water between an associated storage zone in contact with the screen and the well on which the screen is located; controlling the flow of fresh water through each one of the plurality of screens according to parameters provided from a storage model of the aquifer, the storage model describing a behavior of each storage zone.

Abstract: The invention provides a system for measuring a parameter within a well comprising: a first apparatus comprising a first reel of first wound optic fiber line (or fiber) able to be unwound from the first reel, at least a first sensor able to measure the parameter of the well, wherein information on said parameter can be transmitted trough the first optic fiber; a second apparatus comprising a second reel of second wound optic fiber line able to be unwound from the second reel, an extremity of the second optic fiber being fixed to a reference point; a light transmitter or receiver device linked to the reference point and able to generate or detect a light pulse through the second optic fiber line; and means to exchange said light pulse between first and second optic fiber line.

Abstract: A method for storing a liquid into a geological formation uses at least one well penetrating into the geological formation. The geological formation comprises at least one storage zone. A plurality of screens is provided, each screen being located alongside a wall of at least one well. Each screen respectively allows a flow of liquid between an associated storage zone in contact with the screen and the well on which the screen is located. The flow of liquid through each one of the plurality of screens is controlled according to parameters providing from a storage model of the geological formation. The storage model describing a behavior of each storage zone.

Abstract: The invention is related to a method of determininng the instantaneous rotation speed of a drill string or a drill bit in a borehole or the lateral shocks applied to the string or bit. The centripetal acceleration of the drill string is measured at at least two opposite ends of a drill string diameter so as to obtain two centripetal acceleration signals ac1 and ac2; the signals ac1 and ac2 are combined and the instantaneous rotation speed or the lateral shocks are derived from said combined signal. The accelerometers must be of the type delivering a signal with a DC component. An important application of the invention is to transform drill string rotation speed dependent data acquired versus time with a constant sampling time increment T.sub.c separating successive data, into compensated data which would be obtained for a substantially constant drill string rotation speed S.sub.c. The compensated data are obtained either by adjusting the constant sampling time interval T.sub.