Abstract: A subsea induction heating system (10) comprising a subsea inline heater module (14) configured for heating a subsea hydrocarbon production or processing component (7) is described. The subsea inline heater module has an induction coil (6) configured for generating a variable magnetic field in the component. The system has a subsea variable frequency drive (4) configured for energizing the induction coil to achieve a desired temperature in the component. A corresponding method is also disclosed.

Disclosed is a spirally heating submarine pipeline including: a conduit which transports a high temperature high pressure fluid from a submarine oil well; and a heating unit disposed in a spiral structure inside based on an outer circumferential surface of the conduit. The heating unit includes an electric heating wire that is installed along the spiral structure to generate heat; a heat insulator that is installed in the form of fully surrounding the electric heating wire and preserves the generated heat; and a heat insulating cap for isolating the heat insulator from the conduit or the heat insulating layer and is provided so as to increase the temperature of the flow in the pipe to prevent the production of a pipe flow interfering material when the fluid is transported in the conduit.

Thermal energy delivery and oil production arrangements and methods thereof are disclosed which heat a subterranean formation, and which comprises positioning concentric tubing strings in a wellbore; heating a heat transfer fluid using a surface thermal fluid heater; flowing a liquid or feedwater downward through an extremely hot innermost tubing string that is inside and concentric to an outermost tubing string and a casing/annulus, which extends below a thermal packer positioned in the wellbore, and continually circulating the heat transfer fluid through the outermost tubing string and the casing/annulus above the thermal packer such that the liquid or feedwater flowing through the innermost tubing string is heated thereby and injected into the wellbore below the thermal packer and out of perforations to heat the subterranean formation to temperatures that allow for hydrocarbon production from the subterranean formation. Emissions may be injected into the subterranean formation with the liquid or feedwater.

Thermal energy delivery and oil production arrangements and methods thereof are disclosed which heat a subterranean formation, and which comprises positioning concentric tubing strings in a wellbore; heating a heat transfer fluid using a surface thermal fluid heater; flowing a liquid or feedwater downward through an extremely hot innermost tubing string that is inside and concentric to an outermost tubing string and a casing/annulus, which extends below a thermal packer positioned in the wellbore, and continually circulating the heat transfer fluid through the outermost tubing string and the casing/annulus above the thermal packer such that the liquid or feedwater flowing through the innermost tubing string is heated thereby and injected into the wellbore below the thermal packer and out of perforations to heat the subterranean formation to temperatures that allow for hydrocarbon production from the subterranean formation. Emissions may be injected into the subterranean formation with the liquid or feedwater.

A system and a process for producing gas and generating power is disclosed herein. The system may be configured to include a produced gas, a production pipe, an indirect heat exchange system, a heat exchange medium, a concentrated solar power system, an energy conversion device, and a heat exchange circulation system. The process may include producing a gas from a reservoir that has a first temperature, heating the produced, via indirect heat exchange with a heat exchange medium, to a second temperature. This indirect heat exchange may produce a cooled heat exchange medium that may be heated again via concentrated solar power. The heated produced gas may be then expanded across an energy conversion device to produce electricity.

A method of optimizing production of a hydrocarbon-containing reservoir by measuring low-frequency Distributed Acoustic Sensing (LFDAS) data in the well during a time period of constant flow and during a time period of no flow and during a time period of perturbation of flow and simultaneously measuring Distributed Temperature Sensing (DTS) data from the well during a time period of constant flow and during a time period of no flow and during a time period of perturbation of flow. An initial model of reservoir flow is provided using the LFDAS and DTS data; the LFDAS and DTS data inverted using Markov chain Monte Carlo method to provide an optimized reservoir model, and that optimized profile utilized to manage hydrocarbon production from the well and other asset wells.

An apparatus for processing components of a fluid having a first fluid component and a second fluid component in a fluid property-dependent fluid device includes an energy device configured to input energy to the fluid, the energy selectively changing a property of one of the first and second components more than the other of the first and second components.

Methods, apparatus and systems for in-situ heating fluids with electromagnetic radiation are provided. An example tool includes a housing operable to receive a fluid flowed through a flow line and a heater positioned within the housing. The heater includes a number of tubular members configured to receive portions of the fluid and an electromagnetic heating assembly positioned around the tubular members and configured to generate electromagnetic radiation transmitted to heat the tubular members. The heated tubular members can heat the portions of the fluid to break emulsion in the fluid. Upstream the heater, the tool can include a homogenizer operable to mix the fluid to obtain a homogenous fluid and a stabilizer operable to stabilize the fluid to obtain a linear flow. Downstream the heater, the tool can include a separator operable to separate lighter components from heavier components in the fluid after the emulsion breakage.

A subsea hydrocarbon production field includes a number of first subsea christmas trees, a first manifold, a number of first flexible flowline jumpers, each of which is connected between the first manifold and a corresponding first tree. Each first flowline jumper includes a first flow conduit and a number of first umbilical lines, and each first flowline jumper includes a first end which is removably connected to a corresponding first tree by a first multibore hub and connector arrangement and a second end which is removably connected to the first manifold by a second multibore hub and connector arrangement.

A system and method for monitoring fluid flow in a downhole reservoir, characterized by at least one energy source (1), which simultaneously sends two or more utility pulses. The pulse can be a fast propagating and flow-independent acoustic pulse, a somewhat slower propagating and flow-dependent pressure pulse, a slow propagating heat pulse or a slow-propagating tracer pulse. The energy sources are connected via said pulses, without cable, and at least an upper heat source (1′) is connected to equipment on the surface via a cable (4).