Pipelines with a control system and forced circulation of fluids through the annulus between an inner barrier and an outer cover of a pipe use a system configured to force circulation of fluids through the annulus. The pipe includes segments (T1, T2, T3, TN) joined together by means of connectors, wherein each segment of the pipe has an injector pipe (I1, I2, I3, IN) for injecting fluid into the annulus at a first end of the segment, and a return pipe (R1, R2, R3, RN) for removing fluid from the annulus at a second end of the segment.

Pipelines with a control system and forced circulation of fluids through the annulus between an inner barrier and an outer cover of a pipe use a system configured to force circulation of fluids through the annulus. The pipe includes segments (T1, T2, T3, TN) joined together by means of connectors, wherein each segment of the pipe has an injector pipe (I1, I2, I3, IN) for injecting fluid into the annulus at a first end of the segment, and a return pipe (R1, R2, R3, RN) for removing fluid from the annulus at a second end of the segment.

An automated process and accompanying apparatus simultaneously separates and measures the flow rate of any multiphase mixture of immiscible fluids. Such separation and measurement can occur in a single vessel, or multiple vessels. Liquid levels, together with a material balance analysis, are utilized to determine constituent liquid flow rates. The vessel(s) can be remotely operated and monitored in real time, while also allowing for automated or manual calibration.

There is provided synthetic proppants, and in particular polysilocarb derived ceramic proppants. There is further provided hydraulic fracturing treatments utilizing these proppants, and methods of enhance hydrocarbon recovery.

Method for evacuating hydrocarbon from a subsea process module (210), the subsea process module having an upper fluid connection point (222) and a lower fluid connection point (232), the method comprising: connecting (110) a receiving container line (220) to the upper fluid connection point (222) of the subsea process module (210); connecting (120) a liquid adding line (230) to the lower fluid connection point (232) of the subsea process module (210); displacing (130) hydrocarbon by a liquid displacement medium added through the liquid adding line (230); removing (140) the liquid adding line from the lower fluid connection point (232); connecting (150) a gas adding line (260) to either the upper fluid connection point (222) or a lower fluid connection point (232); connecting (160) a receiving container line (220) to the lower fluid connection point (232) and or another lower fluid connection point; diluting (170) the remaining hydrocarbon by a gas medium added through the gas adding line (260).

Method for evacuating hydrocarbon from a subsea process module (210), the subsea process module having an upper fluid connection point (222) and a lower fluid connection point (232), the method comprising: connecting (110) a receiving container line (220) to the upper fluid connection point (222) of the subsea process module (210); connecting (120) a liquid adding line (230) to the lower fluid connection point (232) of the subsea process module (210); displacing (130) hydrocarbon by a liquid displacement medium added through the liquid adding line (230); removing (140) the liquid adding line from the lower fluid connection point (232); connecting (150) a gas adding line (260) to either the upper fluid connection point (222) or a lower fluid connection point (232); connecting (160) a receiving container line (220) to the lower fluid connection point (232) and or another lower fluid connection point; diluting (170) the remaining hydrocarbon by a gas medium added through the gas adding line (260).

Aspects of the present disclosure relates to disruptive coupling systems and methods, and apparatus thereof, for subsea systems. The subsea systems may be subsea oil and gas systems. In one implementation, a subsea system includes a subsea component disposed in seawater, and a disruptive coupling device coupled to the subsea structure and/or surrounding fluid.

Offshore systems and methods may be configured for offshore power generation and carbon dioxide injection for enhanced gas recovery for gas reservoirs. For example, a method may include: providing an offshore facility including a gas turbine, and a gas separator; producing a produced gas from a gas reservoir to the offshore facility; combusting the produced gas in a gas turbine to produce power and a flue gas; at least partially removing nitrogen from the flue gas in a gas separator to produce a carbon dioxide-enriched flue gas and a nitrogen-enriched flue gas; compressing the carbon dioxide-enriched flue gas in a gas compressor to produce a compressed gas; and injecting the compressed gas from the gas compressor into the gas reservoir, wherein 80 mol % or more of hydrocarbon in the produced gas is combusted and/or injected into the gas reservoir.

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.

The invention provides a flow system, a subsea valve (100), and a method of use in a subsea pipeline filling, flooding or pigging operation. The flow system comprises a subsea valve (100) comprising a valve inlet and a valve outlet configured to be coupled to a subsea pipeline (13). A pump (112) comprises a pump inlet connected to a fluid source and a pump outlet connected to the valve inlet. The pump is operable to pump fluid from the fluid source and into the subsea pipeline via the subsea valve. The subsea valve comprises a movable valve member and a biasing mechanism, by which the valve member is urged by a biasing force towards a closed position that prevents flow of fluid through the valve and into the subsea pipeline. The valve member is operable to be moved to an open position on activation of the pump to provide a pressure increase at the valve inlet sufficient to overcome the biasing force. In use, opposing sides of the valve member are exposed to ambient subsea pressure such that the subsea valve is pressure balanced.