A pressure rated well annulus fluid expansion storage device that is capable of managing pressure variation within a well annulus by removing or adding fluid to the well annulus. The well annulus fluid expansion storage device includes an annulus fluid expansion unit containing a well annulus fluid and a working fluid, the annulus fluid expansion unit further includes a moveable partition maintaining the working fluid and the well annulus fluid in separate chambers, a working fluid storage tank that stores the working fluid, an adjustable pressure control valve that maintains a pressure of the working fluid, a working fluid pump that feeds and pressurizes working fluid from the working fluid storage tank into the annulus fluid expansion unit, a check valve that allows flow of working fluid from the working fluid storage tank to the annulus fluid expansion unit, and a flow line for receiving and discharging well annulus fluid.

A pressure rated well annulus fluid expansion storage device that is capable of managing pressure variation within a well annulus by removing or adding fluid to the well annulus. The well annulus fluid expansion storage device includes an annulus fluid expansion unit containing a well annulus fluid and a working fluid, the annulus fluid expansion unit further includes a moveable partition maintaining the working fluid and the well annulus fluid in separate chambers, a working fluid storage tank that stores the working fluid, an adjustable pressure control valve that maintains a pressure of the working fluid, a working fluid pump that feeds and pressurizes working fluid from the working fluid storage tank into the annulus fluid expansion unit, a check valve that allows flow of working fluid from the working fluid storage tank to the annulus fluid expansion unit, and a flow line for receiving and discharging well annulus fluid.

A method of improving natural gas recovery from a subterranean hydrocarbon reservoir includes at least one renewable energy source that is electrically coupled with a heat conducting element. The heat conducting element is positioned in a perforated section of a wellbore that traverses into the subterranean hydrocarbon reservoir. A temperature of the subterranean hydrocarbon reservoir is maintained above a cricondentherm temperature so that liquid condensation may be prevented at a final production time. In order to maintain the temperature within a required temperature range, an internal temperature, an internal pressure, and a set of reservoir properties are monitored and then utilized to plot a phase diagram that can be used to detect liquid condensation. If liquid condensation is detected, an electrical output of the renewable energy source is adjusted in order to control the temperature of the subterranean hydrocarbon reservoir at a producing end of a production tubing.

The present invention provides a centrifugal pump for heating fluid by eddy current comprising a volute (29) and a cover (34), in which internally regarding the volute (29) there are provided: an impeller (33) positioned between two supporting annular disks (32) of magnets each comprising a plurality of permanent magnets (31); and two armatures (30) positioned at the ends of the internal assembly. In addition, the invention also provides a subsea tool for fluid heating by eddy current comprising: a centrifugal pump (1) driven by a hydraulic motor (3) by means of a shaft (11); a fluid storage tank (2) hydraulically connected to the centrifugal pump (1); at least one piloted on-off valve (4); piloted directional valves (12, 13); and a filter (7) hydraulically connected to the centrifugal pump (1).

The present invention provides a centrifugal pump for heating fluid by eddy current comprising a volute (29) and a cover (34), in which internally regarding the volute (29) there are provided: an impeller (33) positioned between two supporting annular disks (32) of magnets each comprising a plurality of permanent magnets (31); and two armatures (30) positioned at the ends of the internal assembly. In addition, the invention also provides a subsea tool for fluid heating by eddy current comprising: a centrifugal pump (1) driven by a hydraulic motor (3) by means of a shaft (11); a fluid storage tank (2) hydraulically connected to the centrifugal pump (1); at least one piloted on-off valve (4); piloted directional valves (12, 13); and a filter (7) hydraulically connected to the centrifugal pump (1).

A method of improving natural gas recovery from a subterranean hydrocarbon reservoir includes at least one renewable energy source that is electrically coupled with a heat conducting element. The heat conducting element is positioned in a perforated section of a wellbore that traverses into the subterranean hydrocarbon reservoir. A temperature of the subterranean hydrocarbon reservoir is maintained above a cricondentherm temperature so that liquid condensation may be prevented at a final production time. In order to maintain the temperature within a required temperature range, an internal temperature, an internal pressure, and a set of reservoir properties are monitored and then utilized to plot a phase diagram that can be used to detect liquid condensation. If liquid condensation is detected, an electrical output of the renewable energy source is adjusted in order to control the temperature of the subterranean hydrocarbon reservoir at a producing end of a production tubing.

A method and an assembly for heating and evaluating a formation of the Earth while drilling a wellbore filled with drilling mud are described. A first drilling mud temperature at a depth in the wellbore is received from a first sensor by a controller. The formation proximal to the depth is heated by a heat source mounted to the assembly to a temperature greater than a formation temperature as the drilling assembly drills the wellbore. A second drilling mud temperature is received from a second sensor by the controller. The heat source is positioned in between the first sensor and the second sensor. A difference between the first drilling mud temperature and the second drilling mud temperature is compared to a threshold drilling mud temperature difference value by the controller. Based on a result of the comparison, the drilling assembly is controlled and directed in the formation.

A method to produce in-situ steam comprising the steps of producing a laser beam in a steam generator segment positioned in a wellbore in a formation; introducing the laser beam to an activated carbon container, where the activated carbon container comprises activated carbon; increasing a temperature of the activated carbon with the laser beam to produce a hot activated carbon; introducing water to the activated carbon container through a water supply line; producing steam in the activated carbon container when the water contacts the hot activated carbon; increasing pressure in the activated carbon container as steam is produced until a pressure set point of an inter-container valve is reached; releasing steam through the inter-container valve to a steam container; increasing a pressure in the steam container until a release set point of one or more release valves is reached; and releasing steam through the release valve to the formation.

A gas extraction system comprising a heater configured to receive a wellbore servicing fluid sample and discharge a heated wellbore servicing fluid sample, wherein the heater comprises an internal heat exchange surface coated with a superhydrophobic coating composition; a gas extractor configured to receive at least a portion of the heated wellbore servicing fluid sample and extract an extracted gas from the heated wellbore servicing fluid sample; and one or more detectors configured to receive at least a portion of the extracted gas and provide an analysis of the extracted gas.

A gas extraction system comprising a heater configured to receive a wellbore servicing fluid sample and discharge a heated wellbore servicing fluid sample, wherein the heater comprises an internal heat exchange surface coated with a superhydrophobic coating composition; a gas extractor configured to receive at least a portion of the heated wellbore servicing fluid sample and extract an extracted gas from the heated wellbore servicing fluid sample; and one or more detectors configured to receive at least a portion of the extracted gas and provide an analysis of the extracted gas.