A method of conditioning a well bore featuring an annulus (50) between a bore-lining tubing (20) and a surrounding bore wall (110) comprises pumping conditioning fluid through an inner tubing (10) located within the bore-lining tubing (20) and into a portion of the well bore containing the bore-lining tubing to affect the temperature of the portion of the well bore containing the bore-lining tubing. The annulus (50) between the bore-lining tubing (20) and the surrounding bore wall (110) is at least partially filled with settable material (54). The affected temperature of the portion of the well bore containing the bore-lining tubing influences the setting of the settable material. For example, heating the bore may accelerate setting of the material, while cooling the bore may retard setting of the material.

A heavy oil lifting device and a heavy oil lifting method are disclosed. The device includes: a plurality of liquid injection pumps each including a liquid inlet and a liquid outlet and configured to intake in liquid and discharge the liquid after pressurization; a control valve including a first end and a second end, the liquid outlets of the plurality of liquid injection pumps are connected with the first end; a power liquid transmission pipe connected with the second end and configured to transmit the liquid after pressurization; an operation pump connected with the power liquid transmission pipe, and the liquid after pressurization is used as power liquid to drive the operation pump to reciprocate; the control valve is in switchable communication with the liquid injection pump so that the power liquid transmission pipe is in switchable communication with the liquid injection pump.

A method for stimulating heavy oil recovery from CHOPS wells at or nearing the end of productive life but not experiencing water-out, wherein produced water is heated to below boiling point and injected back downhole to reduce heavy oil viscosity in the near-wellbore region and surrounding the wormhole network, enabling existing reservoir pressure to drive the reduced-viscosity heavy oil toward the well for production to surface. The injection-soak-production cycle can be repeated as desired so long as adequate reservoir pressure exists.

Described examples relate to a downhole fluid heater, comprising a fluid heating assembly comprising a heating chamber for receiving a fluid. The fluid heating assembly is configured to agitate a heat transfer fluid in the heating chamber so as to impart thermal energy and heat the heat transfer fluid.

A gas extraction method in which high energy gas fracturing technology is used to form a fracture network in a thermal injection borehole. Then high-pressure, cyclically temperature-changing steam is injected into the borehole using a spinning oscillating-pulse jet nozzle to form oscillating superheated steam, alternatingly impacting and heating the coal body. The high energy gas forms a fracture network that provides channels for passage of the superheated steam, while oscillating changes in steam temperature and pressure also promote crack propagation and perforation of the coal body; the combined effect of alternation of the two enhances gas desorption and extraction efficiency.

A method of hanging a cable within a coiled tubing string includes the steps of determining a length of coiled tubing required within a well having a wellhead; determining a length of a cable required within the coiled tubing, the cable having a structural component along the length of the cable sufficient to support the weight of the cable; cutting the tubing string and installing a hanger sub in the coiled tubing string toward the wellhead attachment section relative to the downhole end, the hanger sub comprising an inner shoulder that extends radially into the hanger sub and defines an opening; and attaching an outer shoulder to the cable and inserting the cable into the coiled tubing string until the outer shoulder of the cable engages the inner shoulder of the hanger sub such that the inner shoulder positions the cable below the outer shoulder.

A subsea riser system with a gas-lift facility has a production riser having a riser conduit and at least one lift gas injection port communicating with the riser conduit. An umbilical is arranged to supply lift gas to the lift gas injection port. A heating unit is positioned to act on a downstream end region of the umbilical adjacent to the lift gas injection port. A method of providing lift gas to a subsea riser system includes the steps of conveying lift gas toward a production riser and, before injecting the lift gas into the production riser, heating the lift gas locally adjacent to the production riser.

A method of conditioning a well bore featuring an annulus (50) between a bore-lining tubing (20) and a surrounding bore wall (110) comprises pumping conditioning fluid through an inner tubing (10) located within the bore-lining tubing (20) and into a portion of the well bore containing the bore-lining tubing to affect the temperature of the portion of the well bore containing the bore-lining tubing. The annulus (50) between the bore-lining tubing (20) and the surrounding bore wall (110) is at least partially filled with settable material (54). The affected temperature of the portion of the well bore containing the bore-lining tubing influences the setting of the settable material. For example, heating the bore may accelerate setting of the material, while cooling the bore may retard setting of the material.

A method of hanging a cable within a coiled tubing string includes the steps of determining a length of coiled tubing required within a well having a wellhead; determining a length of a cable required within the coiled tubing, the cable having a structural component along the length of the cable sufficient to support the weight of the cable; cutting the tubing string and installing a hanger sub in the coiled tubing string toward, the wellhead attachment section relative to the downhole end, the hanger sub comprising an inner shoulder that extends radially into the hanger sub and defines an opening; and attaching an outer shoulder to the cable and inserting the cable into the coiled tubing string until the outer shoulder of the cable engages the inner shoulder of the hanger sub such that the inner shoulder positions the cable below the outer shoulder.

Aspects of a flow balanced frac tank farm are described herein. In one embodiment, the flow balanced frac tank farm includes at least one battery of frac tanks comprising a plurality of frac tank trailers, a header pipe arrangement, and at least one valve between one or more of the frac tank trailers and the header system. The header pipe arrangement may include a header supply pipe to supply water to individual ones of the plurality of frac tank trailers and a header discharge pipe to discharge water from individual ones of the plurality of frac tank trailers. The header pipe arrangement may be relied upon to help balance the flow of heated fluids among the frac tank trailers in frac tank farm.