1085results about "Insulation" patented technology

A process is disclosed for the in situ conversion and recovery of heavy crude oils and natural bitumens from subsurface formations using either a continuous operation with one or more injection and production boreholes, which may include horizontal boreholes, or a cyclic operation whereby both injection and production occur in the same boreholes. A mixture of reducing gases, oxidizing gases, and steam are fed to downhole combustion devices located in the injection boreholes. Combustion of the reducing gas-oxidizing gas mixture is carried out to produce superheated steam and hot reducing gases for injection into the formation to convert and upgrade the heavy crude or bitumen into lighter hydrocarbons. Communication between the injection and production boreholes in the continuous operation and fluid mobility within the formation in the cyclic operation is induced by fracturing or related methods. In the continuous mode, the injected steam and reducing gases drive upgraded hydrocarbons and virgin hydrocarbons to the production boreholes for recovery. In the cyclic operation, wellhead pressure is reduced after a period of injection causing injected fluids, upgraded hydrocarbons, and virgin hydrocarbons in the vicinity of the boreholes to be produced. Injection and production are then repeated for additional cycles. In both operations, the hydrocarbons produced are collected at the surface for further processing.

A method and apparatus is disclosed for heating of formations using fired heaters. The method includes the steps of: providing a wellbore within the formation to be heated, the wellbore comprising a casing within the formation to be heated, a tubular defining, in the inside of the tubular, a flowpath for hot gases from the surface to a point in the wellbore near the bottom of the formation to be heated, and a volume between the tubular and the casing providing a flowpath for hot gases from near the bottom of the formation to be heated to the top of the formation to be heated, wherein the flowpaths are in communication with each other near the bottom of the formation to be heated and the volume between the casing and the tubular at the top of the formation to be heated is in communication with a point above the surface, and insulation for a portion of the length of the wellbore within the formation to be heated between the flowpath for hot gases from the surface to the point in the wellbore near the bottom of the formation to be heated and the flowpath for hot gases from near the bottom of the formation to be heated to the surface; and supplying a flow of hot gases to the flowpath for hot gases from the surface to a point in the wellbore near the bottom of the formation to be heated.

A combustor method and apparatus is provided. The method utilizes flameless combustion with one or more of three improvements to enhance ignition of the flameless combustor. A catalytic surface can be provided within a combustion chamber to provide flameless combustion at least in the vicinity of the catalytic surface at a temperature that is much lower than the autoignition temperature of fuel in air without the presence of the catalytic surface. Nitrous oxide or supplemental oxygen may also be used as an oxidant either instead of air or with air to reduce ignition temperatures. Further, electrical energy can be passed through the fuel conduit, raising the temperature of the conduit to a temperature above which the fuel will ignite when combined with the oxidant.

A hydrocarbon containing formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H.sub.2, and/or other formation fluids may be produced from the formation. Heat may be applied to the formation to raise a temperature of a portion of the formation to a pyrolysis temperature. A heating rate to a selected volume of the formation may be controlled by altering an amount of heating energy per day that is provided to the selected volume.

A method and apparatus are described for creating a fluid seal in a subterranean well structure having a fluid seal defect. The method comprises introducing a meltable repair material proximate a structure in a subterranean well which has a fluid seal defect or enhanced seal capacity is required or it is desired to temporarily or permanently hydraulically isolate a portion the well or strengthen the structural integrity of well tubulars or tubular hangers. Exothermic reactant materials are located proximate the meltable repair material. The exothermic reactant material is ignited or an exothermic reaction otherwise initiated which supplies heat to and melts the meltable repair material into a molten mass. The molten mass flows and solidifies across the structure and the fluid seal defect to effect a fluid seal in the subterranean well structure or the structural integrity is enhanced. Examples of preferred exothermic reactant materials include thermite, thermate, fusible chemical reactants such as ammonium chloride and sodium nitrate, and oxidizers and accompanying hydrocarbon based fuels. Examples of preferred meltable repair materials include solder or brazing materials and eutectic metals which expand upon cooling and solidifying from a molten state.

A system and method of drilling and/or perforating uses a laser beam to remove material, such as to perforate the casing, cement and formation or drill a well bore. The system and method can further or alternately encompass material analysis that can be performed without removing the material from the well bore. The analysis can be performed apart from or in connection with drilling operations and/or perforating the casing, cement and formation. The analysis can be used in a feed back loop to adjust material removal, adjust material analysis, determine the location of future material removal, and for other uses.

Certain embodiments provide a heater. The heater includes a ferromagnetic member. The heater also includes an electrical conductor electrically coupled to the ferromagnetic member. The electrical conductor is configured to conduct a majority of time-varying electrical current passing through the heater at about 25° C. The heater is configured to provide a first heat output below the Curie temperature of the ferromagnetic member. The heater is configured to automatically provide a second heat output approximately at and above the Curie temperature of the ferromagnetic member. The second heat output is reduced compared to the first heat output.

A Drill-To-The-Limit (DTTL) drilling method variant to Managed Pressure Drilling (MPD) applies constant surface backpressure, whether the mud is circulating (choke valve open) or not (choke valve closed). Because of the constant application of surface backpressure, the DTTL method can use lighter mud weight that still has the cutting carrying ability to keep the borehole clean. The DTTL method identifies the weakest component of the pressure containment system, such as the fracture pressure of the formation or the casing shoe leak off test (LOT). With a higher pressure rated RCD, such as 5,000 psi (34,474 kPa) dynamic or working pressure and 10,000 psi (68,948 kPa) static pressure, the limitation will generally be the fracture pressure of the formation or the LOT. In the DTTL method, since surface backpressure is constantly applied, the pore pressure limitation of the conventional drilling window can be disregarded in developing the fluid and drilling programs. Using the DTTL method a deeper wellbore can be drilled with larger resulting end tubulars, such as casings and production liners, than had been capable with conventional MPD applications.

A process may include providing heat from one or more heaters to at least a portion of a subsurface formation. Heat may transfer from one or more heaters to a part of a formation. In some embodiments, heat from the one or more heat sources may pyrolyze at least some hydrocarbons in a part of a subsurface formation. Hydrocarbons and/or other products may be produced from a subsurface formation. Certain embodiments describe apparatus, methods, and/or processes used in treating a subsurface or hydrocarbon containing formation.

Certain embodiments provide a system including a heater. The heater includes one or more electrical conductors. The heater is configured to generate a heat output during application of electrical current to the heater. The heater includes a ferromagnetic material. A conduit at least partially surrounds the heater. A fluid is located in a space between the heater and the conduit. The fluid has a higher thermal conductivity than air at standard temperature and pressure (STP) (0° C. and 101.325 kPa). The system is configured to provide (a) a first heat output below a selected temperature when time-varying electrical current is applied to the heater, and (b) a second heat output near or above the selected temperature when time-varying electrical current is applied to the heater.

A closed loop system for increasing yield, reducing post process pollution, reducing energy consumed during and after extraction of fuels or contaminants in formations and for sequestering of carbon dioxide C0₂ from various sources is converted to a critical fluid for use as a flushing and cooling medium. Electrical energy heats a hydrocarbon rich formation resulting in the extraction of hot fluids which are fed to heat exchangers, gas/liquid separator, and steam turbine whereby oil, electric power, carbon dioxide and methane are produced for reuse in the system or for external use. Further, a method for sequestering of carbon dioxide in a formation comprises the steps of injecting CO₂ into the reservoir, flushing with cool pressurized CO₂ for heat removal, infiltrating with ultra-fine low density suspended catalyst particles of dry sodium hydroxide in CO₂, pumping water moistened CO₂ into the reservoir to activate the catalysts, binding the CO₂ with reacting materials and capping the reservoir.

Systems, methods, and heaters for treating a subsurface formation are described herein. At least one method for producing hydrocarbons from a subsurface formation includes providing heat to the subsurface formation using an in situ heat treatment process. One or more formation particles may be formed during heating of the subsurface formation. Fluid that includes hydrocarbons and the formation particles may be produced from the subsurface formation. The formation particles in the produced fluid may include cenospheres and have an average particle size of at least 0.5 micrometers.

Xanthan gels hydratable in brine, methods of making these xanthan gels, and methods of using these compositions in subterranean formation applications, such as gravel packing, are provided herein.

Well treatment is disclosed that includes injecting a well treatment fluid with insoluble polyol polymer such as polyvinyl alcohol (PVOH) dispersed therein, depositing the insoluble polymer in the wellbore or an adjacent formation, and thereafter dissolving the polymer by reducing salinity and/or increasing temperature conditions in the environment of the polymer deposit. The method is disclosed for filter cake formation, fluid loss control, drilling, hydraulic fracturing and fiber assisted transport, where removal of the polyol at the end of treatment or after treatment is desired. The method is also disclosed for providing dissolved polyol as a delayed breaker in crosslinked polymer viscosified systems and viscoelastic surfactant systems. Also disclosed are well treatment fluids containing insoluble amorphous or at least partially crystalline polyol, and a PVOH fiber composition wherein the fibers are stabilized from dissolution by salinity.

A composition, apparatus and method for use in a wellbore is described. In one aspect, a composition may include a shape-conforming material and nanoparticles sufficient to absorb a selected form of energy to heat the shape-conforming material to near or above a glass transition temperature. A method of deploying an apparatus using such a composition may include placing the apparatus at a suitable location in a wellbore and exposing the composition to the selected energy to deploy the apparatus in the wellbore.

Certain embodiments provide a method for treating a hydrocarbon containing formation. The method includes applying electrical current to one or more electrical conductors located in an opening in the formation to provide an electrically resistive heat output. The heat is allowed to transfer from the electrical conductors to a part of the formation containing hydrocarbons so that a viscosity of fluids in the part and at or near the opening in the formation is reduced. Gas is provided at one or more locations in the opening such that the fluids are lifted in the opening towards the surface of the formation. The fluids are produced through the opening.

Certain embodiments provide a method for treating a subsurface formation. The method includes providing one or more explosives into portions of one or more wellbores selected for the explosion in the formation. The wellbores are formed in one or more zones in the formation. The explosives are controllably exploded in one or more of the wellbores such that at least some of the formation surrounding the selected wellbores has an increased permeability. One or more heaters are provided in the one or more wellbores.

A process for utilizing microwaves to heat H₂O within a subterranean region wherein the heated H₂O contacts heavy oil in the subterranean region to lower the viscosity of the heavy oil and improve production of the heavy oil.

A method for heating heavy oil inside a production well. The method raises the subsurface temperature of heavy oil by utilizing an activator that has been injected below the surface. The activator is then excited with a generated microwave frequency such that the excited activator heats the heavy oil.

The present invention overcomes many of the disadvantages of prior art mobile oil field heat exchange systems by providing an improved frac water heating system. The present invention is a self-contained unit which is easily transported to remote locations. In one embodiment, the present invention includes a single-pass tubular coil heat exchanger contained within a closed-bottom firebox having a forced-air combustion and cooling system. In another embodiment, the present invention includes multiple, single-pass heat exchanger units arranged in a vertically stacked configuration. The rig also includes integral fuel tanks, hydraulic and pneumatic systems for operating the rig at remote operations in all weather environments. In a preferred embodiment, the improved frac water heating system is used to heat water on-the-fly (i.e., directly from the supply source to the well head) to complete hydraulic fracturing operations. The present invention also includes systems for regulating and adjusting the fuel/air mixture within the firebox to maximize the combustion efficiency. The system includes a novel hood opening mechanism attached to the exhaust stack of the firebox.

An economic method for in situ maturing and production of oil shale or other deep-lying, impermeable resources containing immobile hydrocarbons. Vertical fractures are created using horizontal or vertical wells. The same or other wells are used to inject pressurized fluids heated to less than approximately 370° C., and to return the cooled fluid for reheating and recycling. The heat transferred to the oil shale gradually matures the kerogen to oil and gas as the temperature in the shale is brought up, and also promotes permeability within the shale in the form of small fractures sufficient to allow the shale to flow into the well fractures where the product is collected commingled with the heating fluid and separated out before the heating fluid is recycled.

A method and apparatus for providing fluid flow into a wellbore in which an apparatus having at least one laser energy output is lowered into the wellbore and the at least one laser energy output is directed at a wall of the wellbore. At least a portion of the wall is heated using the at least one laser energy output, whereby flow of a fluid into the wellbore is initiated and/or- enhanced.

Certain embodiments provide a method for treating a subsurface formation. The method includes using heaters to form a heated portion of the subsurface formation. A production conduit is used to direct formation fluid in a vapor phase from the heated portion of the subsurface formation towards a surface of the subsurface formation. Condensate of the vapor phase formation fluid is formed in or near the production conduit. Condensate of the vapor phase formation fluid is diverted to a desired location.

A method of servicing a wellbore, comprising providing a fluid diode in fluid communication with the wellbore, and transferring a fluid through the fluid diode. A fluid flow control tool, comprising a tubular diode sleeve comprising a diode aperture, a tubular inner ported sleeve received concentrically within the diode sleeve, the inner ported sleeve comprising an inner port in fluid communication with the diode aperture, and a tubular outer ported sleeved within which the diode sleeve is received concentrically, the outer ported sleeve comprising an outer port in fluid communication with the diode aperture, wherein a shape of the diode aperture, a location of the inner port relative to the diode aperture, and a location of the outer port relative to the diode aperture provide a fluid flow resistance to fluid transferred to the inner port from the outer port and a different fluid flow resistance to fluid transferred to the outer port from the inner port.

A method of producing liquid hydrocarbons from a hydrocarbon-bearing rock in situ in a geological formation begins with exploring the formation by drilling a plurality of boreholes into the formation and taking core samples of the hydrocarbon-bearing rock and at least one overburden layer. Electrical parameters of the hydrocarbon-bearing rock and the overburden layer are determined, as well as a roughness of a boundary between the hydrocarbon-bearing rock and the at least one overburden layer. These electrical parameters are used to construct a computer model of a portion of the hydrocarbon-bearing rock and at least one overburden layer, the computer model based upon modeling the formation as a rough-walled waveguide. This computer model is used to simulate propagation of radio frequency energy within the hydrocarbon-bearing rock, including simulation of radio frequency wave confinement within the hydrocarbon-bearing rock, at several frequencies and temperatures. A frequency for retorting is selected based upon simulation results. Radio frequency couplers are installed into at least one borehole in the hydrocarbon-bearing rock and driven with radio frequency energy to heat the hydrocarbon-bearing rock. As the rock heats, it releases carbon compounds and these are collected.

A thermally conductive cement-sand grout for use with a geothermal heat pump system. The cement sand grout contains cement, silica sand, a superplasticizer, water and optionally bentonite. The present invention also includes a method of filling boreholes used for geothermal heat pump systems with the thermally conductive cement-sand grout. The cement-sand grout has improved thermal conductivity over neat cement and bentonite grouts, which allows shallower bore holes to be used to provide an equivalent heat transfer capacity. In addition, the cement-sand grouts of the present invention also provide improved bond strengths and decreased permeabilities. The cement-sand grouts can also contain blast furnace slag, fly ash, a thermoplastic air entraining agent, latex, a shrinkage reducing admixture, calcium oxide and combinations thereof.

A heating tool used for heating cement and/or a ground formation zone and melting billets in a down hole application for sealing oil and gas wells from gas migration. The heating tool has a billet loader which allows a plurality of billets to be loaded into the top of the tool and which billets then pass downward into a magazine and the lowermost heating area of the tool to rest on a billet retainer.

Filtration devices may include a shape-memory material having a compressed run-in position or shape and an original expanded position or shape. The shape-memory material may include an open cell porous rigid polyurethane foam material held in the compressed run-in position at the temperature below glass transition temperature (T_g). The foam material in its compressed run-in position may be covered with a fluid-dissolvable polymeric film and/or a layer of fluid-degradable plastic. Once filtration devices are in place in downhole and are contacted by the fluid for a given amount of time at temperature, the devices may expand and totally conform to the borehole to prevent the production of undesirable solids from the formation.

In one aspect a apparatus is provided that in one embodiment may include a permeable member made by combining a particulate additive to one or more materials, which materials when processed without the particulate additive form a substantially impermeable mass, wherein the permeable member inhibits flow of solid particles above a particular size through the permeable member.

A method for preheating a formation prior to beginning steam assisted gravity drainage production. The method proceeds by forming a steam assisted gravity drainage production well pair within a formation. A preheating stage is then begun by injecting an activator into the formation. The preheating stage is then accomplished by exciting the activator with radio frequencies. This is followed by beginning the steam assisted gravity drainage operation.