Abstract: The invention relates to an apparatus for simultaneously injecting fluids into a plurality of samples of porous media, comprising: a plurality of holders for the samples of porous media, each holder comprising a sleeve and first and second platens, the first platen having an inlet for an injection fluid and the second platen having an outlet for a produced fluid, and the samples of porous media being arranged, in use, in each of the holders such that the first platen and second platen of each holder contact a first and second end of the sample of porous medium respectively, the inlet of each first platen being in fluid communication with an injection line for injecting fluid into the sample of porous medium arranged in the holder, the outlet of each second platen being in fluid communication with a dedicated effluent line for removing fluid produced from the sample of porous medium arranged in the holder, on-line and/or off-line analytical means for analyzing the fluids injected into each of the samples of po

Abstract: A control line protector for use with a tubing string, e.g. production tubing having at least one control line on an outer surface thereof is disclosed. The control line protector comprises a sleeve having a cylindrical rigid outer wall, the sleeve being locatable around the tubing string and the at least one control line, and a polymeric scaling element disposed, in use, between an inner surface of the outer wall of the sleeve and the tubing string, operable to substantially seal the space between the outer wall of the sleeve and the tubing string.

Abstract: Hydrocarbons are recovered from subterranean formations by waterflooding. The method comprises passing an aqueous displacement fluid via an injection well through a porous and permeable sandstone formation to release oil and recovering said released oil from a production well spaced from said injection well, wherein (a) the sandstone formation comprises at least one mineral having a negative zeta potential under the formation conditions; (b) oil and connate water are present in the pores of the formation; and (c) the fraction of the divalent cation content of the said aqueous displacement fluid to the divalent cation content of said connate water is less than 1.

Abstract: Computerized method and system for deriving a statistical reservoir model of associations between injecting wells and producing wells. Potential injector events are interactively identified from time series measurement data of flow rates at the wells, with confirmation that some response to those injector events appears at producing wells. Gradient analysis is applied to cumulative production time series of the producing wells, to identify points in time at which the gradient of cumulative production changes by more than a threshold value. The identified potential producer events are spread in time and again thresholded. An automated association program rank orders injector-producer associations according to strength of the association. A capacitance-resistivity reservoir model is evaluated, using the flow rate measurement data, for the highest-ranked injector-producer associations.

Abstract: Physical models of wells are used to determine rate and phase composition for fluid produced from or injected into the wells on a near real time and continuous basis. The method can be used to alert operators or others of conditions in a well or field to permit more immediate response. The method can be more tolerant of sensor faults, sensor drift, anomalous data or other occurrences which could otherwise lead to incorrect output. More than one model can be used to permit a hierarchy of calculation such that the rate and phase determination is more tolerant of anomalous data. The calculated rate and phase values from one or more wells can be reconciled against facility data.

Abstract: A device for inhibiting severe slug flow in a multiphase fluid stream flowing through a pipeline and into a riser, wherein, the device is positioned immediately upstream of the riser and comprises at least one unit comprising (i) an upwardly inclined section of pipe having a lower end and an upper end and (ii) either a substantially horizontal section of pipe having a first end and a second end or a downwardly inclined section of pipe having an upper end and a lower end, wherein the lower end of the upwardly inclined section of pipe is connected either directly or indirectly with the pipeline, the upper end of the upwardly inclined section of pipe is connected either directly or indirectly with the first end of the horizontal section of pipe or with the upper end of the downwardly inclined section of pipe, and the second end of the horizontal section of pipe or the lower end of the downwardly inclined section of pipe is connected either directly or indirectly with the riser, and wherein the angle of inclinati

Abstract: A method for capping a subsea wellbore comprises (a) identifying a subsea landing site on the BOP or LMRP for connection of a capping stack. In addition, the method comprises (b) preparing the subsea landing site for connection of the capping stack. Further, the method comprises (c) installing a capping stack on to the subsea landing site. Still further, the method comprises (d) shutting in the wellbore with the capping stack after (c).

Abstract: Process for converting synthesis gas to hydrocarbons in a slurry reactor in the presence of a Fischer-Tropsch catalyst comprising cobalt and zinc oxide. The process is carried out by a) activating the Fischer-Tropsch catalyst with a reducing gas consisting of hydrogen and an inert gas at a temperature between 330 and 400° C., and b) contacting the activated Fischer-Tropsch catalyst from step a) with synthesis gas in the slurry reactor in order to convert the synthesis gas into hydrocarbons.

Abstract: A motor assembly comprising a motor unit having a first end and a second end and being couplable adjacent the first end of the motor unit to an external electrical device, the motor unit comprising at least one motor winding extending between the first and second ends and an electrical return path extending from the second end to the first end, the electrical return path being in electrical contact at the first end with an electrical connector for supplying impressed secondary power to the external electrical device, wherein the first end of the motor unit is provided with means for coupling a power source to the motor winding and the second end of the motor unit is provided with means to electrically couple the motor winding to the electrical return path.

Abstract: A method for predicting the effect of microbes injected into an oil-bearing reservoir, the oil-bearing reservoir being capable of being represented by a first computer-generated grid comprising a first plurality of grid blocks, is provided. Measurement data representing the effect of injecting the microbes into a multiple coreflood apparatus is received. The multiple coreflood apparatus comprises at least first and second material samples indicative of a rock formation associated with said oil-bearing reservoir, the first and second samples being capable of being represented by a second computer-generated grid comprising a second plurality of grid blocks, the first and second samples being representative of different regions of the reservoir and being connected such that microbes injected into the first sample are able to flow to the second sample.

Abstract: Sensor and communications systems are disclosed for communicating measurements from subsea equipment, such as at an offshore well, to the surface. A sensor for a physical parameter, such as pressure or temperature at a blowout preventer, capping stack, or conduit in communication with the same, is electrically connected to a subsea acoustic transponder. An acoustic communications device, for example an acoustic transducer and transceiver electronics deployed on a remotely-operated vehicle, interrogates the acoustic transponder with an acoustic signal, in response to which the acoustic transponder transmits an acoustic signal encoded with the measurement. The acquired measurement data are then communicated to a redundant network at the surface. The sensor and acoustic transponder systems can be installed after an event at the subsea equipment, such as blowout of the well.

Abstract: A subsea pressure relief valve includes a water-filled nozzle fluidly connected to a hydrocarbon distribution manifold. A valve body is connected to the distribution manifold, with an outlet of the nozzle coincident with an interior water-filled chamber of the valve body. A first seal element is removably seated against the nozzle outlet and an arm is hinged to the body and configured to apply a force along a seal axis and bias the first seal element into sealing engagement with the nozzle outlet until hydrocarbon pressure exceeds a sealing pressure of the applied force and unseats the first seal element from the nozzle outlet such that excess hydrocarbons exit through an outlet of the valve body. A weight is disposed on the arm at a distance from the seal axis.

Abstract: Load bearing assembly for suspending a load from a wellhead assembly, having a connector for suspending jointed production tubing therefrom and a fluid-to-air connector seals around an electrical conductor extending therethrough. The assembly has a jointed production tubing section with a first connector for connecting the tubing to the wellhead assembly connector. The assembly has a second connector for connecting the jointed production tubing section to a load bearing part of an electrical conduction section of the assembly. The load bearing part suspends the weight of the electrical conduction section and a load in a well from the second connector. The electrical conduction section includes an electrical conductor part for supplying electrical power to the load. The electrical conductor part is connected to an electrical cable which extends outside and along the jointed production tubing section away from the second connector and towards the well head in use.

Abstract: Physical models of wells are used to determine rate and phase composition for fluid produced from or injected into the wells on a near real time and continuous basis. The method can be used to alert operators or others of conditions in a well or field to permit more immediate response. The method can be more tolerant of sensor faults, sensor drift, anomalous data or other occurrences which could otherwise lead to incorrect output. More than one model can be used to permit a hierarchy of calculation such that the rate and phase determination is more tolerant of anomalous data. The calculated rate and phase values from one or more wells can be reconciled against facility data.

Abstract: Oil-based wellbore fluid in the form of an emulsion having a continuous phase containing an oil and, dispersed therein, a first dispersed liquid phase and a second separate dispersed liquid phase. The first dispersed liquid phase is a brine phase containing at least 5% by weight of a dissolved salt or a mixture of salts, and the second dispersed liquid phase is a polar organic liquid which is insoluble or sparingly soluble in the brine and contains the first dispersed liquid phase, but is soluble in pure water. The second dispersed liquid phase is in the form of droplets having an average diameter of not less than 5 microns.

Abstract: Physical models of wells are used to determine rate and phase composition for fluid produced from or injected into the wells on a near real time and continuous basis. The method can be used to alert operators or others of conditions in a well or field to permit more immediate response. The method can be more tolerant of sensor faults, sensor drift, anomalous data or other occurrences which could otherwise lead to incorrect output. More than one model can be used to permit a hierarchy of calculation such that the rate and phase determination is more tolerant of anomalous data. The calculated rate and phase values from one or more wells can be reconciled against facility data.

Abstract: A free-standing riser system connects a subsea source to a surface structure. The system includes a concentric free-standing riser comprising inner and outer risers defining an annulus there between. A lower end of the riser is fluidly coupled to the subsea source through a lower riser assembly (LRA) and one or more subsea flexible conduits. An upper end of the riser is connected to a buoyancy assembly and the surface structure through an upper riser assembly (URA) and one or more upper flexible conduits, the riser also mechanically connected to a buoyancy assembly that applies upward tension to the riser. The riser may be insulated for flow assurance, either by a flow assurance fluid in the annulus, insulation of the outside of the outer riser, or both. The system may include a hydrate inhibition system and/or a subsea dispersant system. The surface structure may be dynamically positioned.

Abstract: Hydrocarbons are recovered from subterranean formations by waterflooding. The method comprises passing an aqueous displacement fluid via an injection well through a porous and permeable sandstone formation to release oil and recovering said released oil from a production well spaced from said injection well, wherein (a) the sandstone formation comprises at least one mineral having a negative zeta potential under the formation conditions; (b) oil and connate water are present in the pores of the formation; and (c) the fraction of the divalent cation content of the said aqueous displacement fluid to the divalent cation content of said connate water is less than 1.

Abstract: A system for autonomously supplying a chemical dispersant to a subsea hydrocarbon discharge site which comprises a subsea storage vessel configured to store the chemical dispersant subsea is described herein. The storage vessel includes a dispersant outlet in fluid communication with the subsea hydrocarbon discharge site.

Abstract: Automated monitoring and management of well tests of hydrocarbon wells in a production field. Routing of the output of a well to a flow meter, separated from the output from other wells in the field, is detected by a computer system such as a server. Measurement data including the flow as measured by the flow meter, and also other measurements such as temperatures and pressures contemporaneous with the flow meter measurements, are acquired by the computer system; a stable period is identified, over which the flow test measurement data are considered valid. Upon completion of a specified duration or upon a change in the flow environment, the computer system notifies the user of the completion of the flow test. The flow test results can be used to modify predictive well models, with the modification dependent on validation by the user. The system can also plan and schedule future flow tests.