Abstract: A method for removing fouling from a pipeline includes determining the location of fouling in the pipeline. Once determined, the method further includes installing a hot tap in the pipeline. A flex conduit is inserted into the pipeline through the hot tap and a treatment fluid is flowed into the pipeline through the conduit. The treatment fluid is used to remove the fouling from the pipeline. Once the fouling is sufficiently removed, the flexible conduit is removed from the pipeline.

Abstract: A subsea chemical injection system and method for injecting chemicals into a hydrocarbon production assembly adjacent the seabed wherein a seawater volume flowmeter is utilized to measure seawater pumped through the system and a chemical subsea mass flowmeter is used to measure a chemical injected into the seawater, where the chemical subsea mass flowmeter measures the chemical at a pressure less than the seawater pumped through the system. Based on the chemical subsea mass flowmeter measurement, the flowrate of a chemical injected into the seawater can be adjusted to a predetermined setpoint corresponding to the flowrate of seawater pumped through the system. The chemical subsea mass flowmeter includes a Coriolis tube and chemical injection process pump housed within a pressure vessel. The subsea chemical injection system may be carried on a skid.

Abstract: A subsea chemical injection system and method for injecting chemicals into a hydrocarbon production assembly adjacent the seabed wherein a seawater volume flowmeter is utilized to measure seawater pumped through the system and a chemical subsea mass flowmeter is used to measure a chemical injected into the seawater, where the chemical subsea mass flowmeter measures the chemical at a pressure less than the seawater pumped through the system. Based on the chemical subsea mass flowmeter measurement, the flowrate of a chemical injected into the seawater can be adjusted to a predetermined setpoint corresponding to the flowrate of seawater pumped through the system. The chemical subsea mass flowmeter includes a Coriolis tube and chemical injection process pump housed within a pressure vessel. The subsea chemical injection system may be carried on a skid.

Abstract: A hybrid coiled tubing system. The hybrid coiled tubing system may include composite coiled tubing, metallic coiled tubing, and a composite coiled tubing connector coupled to and joining the composite coiled tubing and the metallic coiled tubing.

Abstract: A subsea pump and power system having a base unit positioned on the seabed to which is detachably mounted a power module tethered to a surface power source via a power umbilical. The base unit includes process pumps for carrying out subsea pumping operations and is lowered by a heavy lift cable into position on the seabed adjacent a hydrocarbon production facility prior to lowering of the power module on a tether. The power module includes a power unit which may include an electrical motor, or a hydraulic pump or both, one or more of which are driven by the umbilical extending from the surface. The tether supports the weight of the power module as it is lowered to the base unit and includes an electrical umbilical, a hydraulic umbilical or both.

Abstract: A rapid deployment, subsea chemical injection skid assembly includes a non-buoyant skid lowered on a weight bearing line from a surface vessel. The skid carries a chemical injection pump, as well as at least one chemical tank in fluid communication with the chemical injection pump. The skid assembly may include a recirculation/mixing system to limit separation or solids drop out of chemicals arising from medium or long-term storage of chemicals in the chemical tank. The skid assembly may include a seawater filtration system to supply seawater for mixing with chemicals prior to injection. The skid assembly is operable by a separately tethered remotely operated vehicle.

Abstract: A subsea pump and power system having a base unit positioned on the seabed to which is detachably mounted a power module tethered to a surface power source via a power umbilical. The base unit includes process pumps for carrying out subsea pumping operations and is lowered by a heavy lift cable into position on the seabed adjacent a hydrocarbon production facility prior to lowering of the power module on a tether. The power module includes a power unit which may include an electrical motor, or a hydraulic pump or both, one or more of which are driven by the umbilical extending from the surface. The tether supports the weight of the power module as it is lowered to the base unit and includes an electrical umbilical, a hydraulic umbilical or both.

Abstract: A coiled tubing deployment system includes an offshore rig having a reel positioned thereon and coiled tubing wound on the reel. A guide arch receives the coiled tubing from the reel and a monitoring support guide fixed to the offshore rig receives and directs the coiled tubing into water. The monitoring support guide has a frame and at least two hydraulic rams. A depth counter measures the coiled tubing deployed from the reel and generates length measurement signals, and sensors coupled to the at least two hydraulic rams measure real-time lateral movement of the coiled tubing with respect to the monitoring support guide as the coiled tubing is deployed into the water and thereby generate sensor signals. A data acquisition system receives and processes the length measurement and sensor signals to provide an output signal indicative of real-time bending fatigue of the coiled tubing at select locations along the coiled tubing.

Abstract: A coiled tubing deployment system includes an offshore rig having a reel positioned thereon and coiled tubing wound on the reel. A guide arch receives the coiled tubing from the reel and a monitoring support guide fixed to the offshore rig receives and directs the coiled tubing into water. The monitoring support guide has a frame and at least two hydraulic rams. A depth counter measures the coiled tubing deployed from the reel and generates length measurement signals, and sensors coupled to the at least two hydraulic rams measure real-time lateral movement of the coiled tubing with respect to the monitoring support guide as the coiled tubing is deployed into the water and thereby generate sensor signals. A data acquisition system receives and processes the length measurement and sensor signals to provide an output signal indicative of real-time bending fatigue of the coiled tubing at select locations along the coiled tubing.