A subsea hydrocarbon flowline system (300) is disclosed. The flowline system has a hydrocarbon flowline (302); an electric trace heating system (304) arranged along at least a part-length of the flowline to control the temperature of hydrocarbon fluid flowing in the flowline; and a power input connector (Pin) configured for receiving electrical power from an electrical power providing system for powering the electric trace heating system. The electric trace heating system has a first three-phase trace heating cable (C′) and a second three-phase trace heating cable (C″), each trace heating cable extending between the power input connector and a cable termination (T′; T″) where phase conduits (L1′, L2′, L3′; L1″, L2″, L3″) of the trace heating cable are Y-connected and terminate in a neutral connection point (L.sub.N′; L.sub.N″). Further, the flowline system has a power output connector (Pout) for providing electrical power to a subsea hydrocarbon production system; a first electrical conduit (306′) extending between the neutral connection point of the cable termination of the first trace heating cable and the power output connector; and a second electrical conduit (306″) extending between the neutral connection point of the cable termination of the second trace heating cable and the power output connector, wherein the first and the second electrical conduits are electrically accessible at the power output connector for powering the subsea hydrocarbon production system.

A subsea hydrocarbon flowline system (300) is disclosed. The flowline system has a hydrocarbon flowline (302); an electric trace heating system (304) arranged along at least a part-length of the flowline to control the temperature of hydrocarbon fluid flowing in the flowline; and a power input connector (Pin) configured for receiving electrical power from an electrical power providing system for powering the electric trace heating system. The electric trace heating system has a first three-phase trace heating cable (C′) and a second three-phase trace heating cable (C″), each trace heating cable extending between the power input connector and a cable termination (T′; T″) where phase conduits (L1′, L2′, L3′; L1″, L2″, L3″) of the trace heating cable are Y-connected and terminate in a neutral connection point (L.sub.N′; L.sub.N″). Further, the flowline system has a power output connector (Pout) for providing electrical power to a subsea hydrocarbon production system; a first electrical conduit (306′) extending between the neutral connection point of the cable termination of the first trace heating cable and the power output connector; and a second electrical conduit (306″) extending between the neutral connection point of the cable termination of the second trace heating cable and the power output connector, wherein the first and the second electrical conduits are electrically accessible at the power output connector for powering the subsea hydrocarbon production system.

The present invention relates to a heating cable for extraction pipes of viscous hydrocarbon or paraffinic in conventional wells and tight type wells, with flooded ring in eventual or permanent cases, suitable for use between low and high fluid pressure ranges. The cable, flat type with parallel electric conductors, is also suitable for use in both vertical and directional wells with high operational flexibility in a wide range of variables. Each of the electric conductors (2) is covered by a primary insulation layer (3), and the set of conductors is monolithically coated by a main insulating layer (4) made of fluoropolymer material resistant to the high pressure of the surrounding fluid. Outside of the main insulating layer (4), the structure of the cable is complemented with an external shield (5) defined by a thin metallic material layer.

The present invention relates to a heating cable for extraction pipes of viscous hydrocarbon or paraffinic in conventional wells and tight type wells, with flooded ring in eventual or permanent cases, suitable for use between low and high fluid pressure ranges. The cable, flat type with parallel electric conductors, is also suitable for use in both vertical and directional wells with high operational flexibility in a wide range of variables. Each of the electric conductors (2) is covered by a primary insulation layer (3), and the set of conductors is monolithically coated by a main insulating layer (4) made of fluoropolymer material resistant to the high pressure of the surrounding fluid. Outside of the main insulating layer (4), the structure of the cable is complemented with an external shield (5) defined by a thin metallic material layer.

An electrical tool for well stimulation includes a first electrode and a second electrode. The second electrode being at the level of a first segment and a second segment of the tool. A peripheral electrode insulated electrically from the first electrode. The first segment and the second segment are linked by an articulated link inside which is arranged a coaxial cable running from the first segment to the second segment. The coaxial cable includes an electrically conducting outer envelope insulated electrically from an electrically conducting central core. The tool includes a first electrical contact between the central core of the coaxial cable and the first electrode, and a second electrical contact between the outer envelope of the coaxial cable and the second electrode.

A laser head apparatus that enables switching between a laser beam and a purging stream. The laser head apparatus includes a bracket that provides for translation and rotation of the laser optics and purging nozzle. The laser optics and purging nozzle are located on opposite sides of the bracket and may be rotated to different rotational positions around a center axis of the bracket and translated to different linear positions along a length of the bracket. Methods of removing material using the laser head apparatus to between a laser beam and a purging stream are also provided.

Described herein are methods and system that use electromagnetic heating to heat wellbores and the fluids therein. The heating is achieved by placing one or more permanent magnets in the wellbore and moving a metallic component and/or the one or more permanent magnets relative to each other. This generates eddy currents in the metallic component, which heat the metallic component. This heat is transferred to the fluids in the wellbore from the metallic component by convection. In some embodiments, permanent magnets are installed in the tubing to induce eddy current heating in a well by converting the linear motion of a sucker rod to rotary motion of a conducting tube using a lead or ball screw. The heater may directly integrate with existing pump jack equipment with little or no additional infrastructure required.

A downhole heating apparatus may include a gas separator, a downhole heater, and a thermal barrier. The thermal barrier may retard fluid and heat from flowing between a lower annulus of a wellbore and an upper annulus of a wellbore. The thermal barrier may be formed from one or more thermal barrier subcomponents. The downhole heater may be an electrical heater. The thermal barrier may include one or more vents allowing fluid communication between the lower annulus and upper annulus of the wellbore.

A method of sealing propagating cracks in a sensor-laden cement sheath comprising the steps of monitoring an electrical resistivity of the sensor-laden cement sheath to produce a measured value, wherein the sensor-laden cement sheath comprises a conductive sensor, an on-demand expanding agent, and a cement, activating a heat source when the measured value of the electrical resistivity is greater than an activation threshold, increasing a temperature of the sensor-laden cement sheath with the heat source to an activation temperature, wherein the activation temperature is operable to initiate a reaction between the on-demand expanding agent and water, wherein the activation temperature is greater than a formation temperature, reacting the on-demand expanding agent with water to produce a swelled agent, wherein the swelled agent occupies a greater volume than the on-demand expanding agent, and sealing the propagating cracks in the sensor-laden cement sheath with the swelled agent.

A method of sealing propagating cracks in a sensor-laden cement sheath comprising the steps of monitoring an electrical resistivity of the sensor-laden cement sheath to produce a measured value, wherein the sensor-laden cement sheath comprises a conductive sensor, an on-demand expanding agent, and a cement, activating a heat source when the measured value of the electrical resistivity is greater than an activation threshold, increasing a temperature of the sensor-laden cement sheath with the heat source to an activation temperature, wherein the activation temperature is operable to initiate a reaction between the on-demand expanding agent and water, wherein the activation temperature is greater than a formation temperature, reacting the on-demand expanding agent with water to produce a swelled agent, wherein the swelled agent occupies a greater volume than the on-demand expanding agent, and sealing the propagating cracks in the sensor-laden cement sheath with the swelled agent.