A heavy oil lifting device and a heavy oil lifting method are provided. 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.

The disclosure provides for systems and methods for removing particle settlement in a heater system. The method includes introducing a fluid into a first heater of the heater system, wherein the first heater is operable to increase the temperature of the introduced fluid. The method further includes actuating a first air agitation unit to discharge a volume of compressed air into the first heater, wherein the compressed air is configured to provide mixing and suspension to particles settled within the first heater through the velocity and expansion of the compressed air to atmospheric pressure. The method further includes discharging a mixture from the first heater comprising the fluid and the particles from the first heater and directing the discharged mixture to a return point in a flow path.

Apparatus and methods for determining a laminar-turbulent transition of a fluid are provided. For example, a measurement tool can receive a set of wellbore conditions received from a wellbore. Measurement tool parameters can be determined based on the set of wellbore conditions. The measurement tool can be set according to the measurement tool parameters such that a fluid received from the wellbore can move through the measurement tool in a laminar state. The measurement tool may be adjusted according to the measurement tool parameters such that the fluid moves in a turbulent state. The measurement tool may determine a laminar-turbulent transition region for the fluid. The measurement tool may output the laminar-turbulent transition region for use in a drilling operation in the wellbore.

A method for forming a sleeve for wrapping around and insulating a joint of a downhole tubing string is provided. The method includes the steps of providing a mold, applying insulation around the mold, winding an interfacing material around the insulation; and applying a polymer onto the interfacing material to bind to the interfacing material to form the sleeve.

A “passive” apparatus and method for isolating flow within a thermal wellbore wherein inflow apertures are plugged with a temporary fusible alloy plug that can be selectively removed by increasing the wellbore temperature.

A method and apparatus are shown for burning crude oil or natural gas extracted from an underground reservoir, or for burning both crude oil and natural gas extracted from an underground reservoir, for providing thermal energy. The method and apparatus are also shown transferring the thermal energy to brine separated from the extracted oil, gas or both, for providing heated brine, or for converting the thermal energy to mechanical work, or for both transferring the thermal energy to the separated brine and converting the thermal energy to mechanical work. The method and apparatus are also shown heating the underground reservoir with the heated brine injected into the underground reservoir, or heating the underground reservoir with a resistive cable energized by electricity generated by converting the mechanical work to electric energy, or heating the underground reservoir with both the heated brine and the energized resistive cable.

Embodiments of the disclosure pertain to a system for production of a hydrocarbonaceous fluid, the system having a tubing string deployed within a wellbore; a first pump system having a pump assembly operably engaged with a motor; and a control system operably engaged with the first pump system. The pump assembly includes a housing with a stator and rotor disposed therein. The first pump system is operable to aid in production of the hydrocarbonaceous fluid from the wellbore to a production facility.

In some embodiments, a method operates a heat pump that uses a ground loop to perform heating or cooling in a site. During the operating of the heat pump over a time period: the method measures a first series of measurements of a ground loop water flow rate by the heat pump; a second series of measurements of a ground loop fluid temperature for the heat pump; and measures a third series of measurements of a local soil or deep earth temperature. The first measurement, the second measurement, and the third measurement are outputted where a ground loop thermal resistance value is calculated for the heat pump based on the first measurement, the second measurement, and the third measurement.

Systems and methods for increasing hydrocarbon production using an electrical submersible pump are described. The methods typically include, for example, configuring an electrical submersible pump comprising a gas separator to induce a gas lift effect in a well comprising a tubing within a casing. Hydrocarbon production from the well is therefore increased using the electrical submersible pump.

A system for supporting a borehole junction includes a device configured to deploy a material in a solid state to a downhole location proximate to the borehole junction, and a heat source configured to apply heat to the material to a temperature sufficient to liquefy the material. The liquified material is configured to flow into a formation region adjacent to the borehole junction and consolidate the formation region.