Abstract: A hydrocarbon containing formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, 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. Heat may be allowed to transfer from one or more heat sources to a selected section of the formation such that superimposed heat from the one or more heat sources pyrolyzes a relatively large portion of hydrocarbon material within the selected section of the formation.

Abstract: A hydrocarbon containing formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, 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. The mixture may be produced from the formation through a plurality of production wells. A selected number of heat sources may be positioned in the formation for each production well.

Abstract: A hydrocarbon containing formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, 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. The formation to be treated may be chosen so that the mixture produced from the formation will have a desired amount of condensable hydrocarbons and non-condensable hydrocarbons. The formation to be treated may be chosen based on an initial vitrinite reflectance of the formation.

Abstract: A hydrocarbon containing formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, 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. Heating may be controlled such that at least a selected amount of a total organic carbon content of the hydrocarbon material in the formation may be converted into formation fluids.

Abstract: A coal formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, 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 formation may be selected that will produce a relatively large amount of condensable hydrocarbons and/or a relatively large amount of non-condensable hydrocarbons. Hydrocarbons within the formation may have a relatively low initial elemental oxygen weight percentage. The formation to be treated may be selected based on initial elemental oxygen to carbon ratio of the formation.

Abstract: A hydrocarbon containing formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, 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. The formation to be treated may be selected based on initial elemental oxygen to carbon ratio of the formation.

Abstract: A coal formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, 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. Heat may be allowed to transfer from one or more heat sources to a selected section of the formation such that superimposed heat from the one or more heat sources pyrolyzes a relatively large portion of hydrocarbon material within the selected section of the formation.

Abstract: A hydrocarbon containing formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, 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. Heat sources within a relatively thin layer of hydrocarbon material may be positioned in a staggered pattern near to edges of the layer so that superposition of heat from the heat sources allows a large percentage of the layer to reach a desired temperature.

Abstract: A hydrocarbon containing formation may be treated using an in situ thermal process. Hydrocarbons, H2, 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. Heat input into the formation may be controlled to raise a temperature of the formation at a selected rate.

Abstract: An oil shale formation may be treated using an in situ thermal process. Heat may be provided to a portion of the formation from one or more heat sources. Heat may be allowed to transfer from the heat sources to a selection of the formation. Hydrocarbons, H2, and/or other formation fluids may be produced from the formation. A recovery fluid may be provided to the formation to recover one or more components remaining in the portion.

Abstract: Carbon dioxide emissions into the atmosphere are reduced and activities requiring CO2, such as enhanced oil field recovery, are promoted, by collecting CO2 in a pipeline from at least two different CO2 production facilities and delivering the CO2 through the pipeline to one or more CO2 consumption facilities. Carbon dioxide emission reduction credit associated with the transfer of CO2 through the pipeline is tracked.

Abstract: A oil shale formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, 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. Heat sources may be used to heat the formation. The heat sources may be positioned within the formation in a selected pattern.

Abstract: An oil shale formation may be treated using an in situ thermal process. Heat may be provided to the treatment area. Fluids may be injected into the formation to remove a component within the formation. Hydrocarbons, H2, and/or other formation fluids may be produced from the formation. In some embodiments, fluids may be injected prior to production of formation fluids. Alternatively, fluids may be injected after production of formation fluids.

Abstract: An oil shale formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, 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 desired temperature. In some embodiments, the formation to be treated may be selected based on formation characterisitics.

Abstract: A hydrocarbon containing formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, 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 formation to be treated may produce a relatively large amount of condensable hydrocarbons and/or a relatively large amount of non-condensable hydrocarbons. Hydrocarbons within the formation may have a relatively low initial elemental oxygen weight percentage.

Abstract: A coal formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, 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. The formation to be treated may be chosen so that the mixture produced from the formation will have a desired amount of condensable hydrocarbons and non-condensable hydrocarbons. The formation to be treated may be chosen based on an initial vitrinite reflectance of the formation.

Abstract: A coal formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, 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. Heat and pressure applied to the formation may be controlled so that a majority of the hydrocarbons produced from the formation have carbon numbers less than 25. Conditions may be controlled to produce low quantities of olefins in condensable hydrocarbons produced from the formation and low quantities of olefins in non-condensable hydrocarbons produced from the formation.

Abstract: A method for treating a relatively permeable formation containing heavy hydrocarbons in situ may include providing heat from one or more heat sources to a selected section of the formation. The heat provided to the selected section may pyrolyze at least some hydrocarbons in a lower portion of the formation. A mixture of hydrocarbons may be produced from an upper portion of the formation. The mixture of hydrocarbons may include at least some pyrolyzed hydrocarbons from the lower portion of the formation.

Abstract: An oil shale formation may be treated using an in situ thermal process. Heat may be provided to a portion of the formation from one or more heat sources having a horizontal orientation in the formation. Heat may be allowed to transfer from the heat sources to a section of the formation. Hydrocarbons, H2, and/or other formation fluids may be produced from the formation.

Abstract: A method for treating a relatively permeable formation containing heavy hydrocarbons in situ may include providing heat from one or more heat sources to a selected section of the formation. The heat provided to the selected section may pyrolyze at least some hydrocarbons in the selected section. A blending agent may be produced from the selected section. A portion of the blending agent may be adapted to blend with a liquid to produce a mixture with a selected property.

Abstract: A method for treating a relatively permeable formation containing heavy hydrocarbons in situ may include providing heat from a first set of heat sources to a first section of the formation. The heat provided to the first section may pyrolyze at least some hydrocarbons in the first section. Heat may also be provided from a second set of heat sources to a second section of the formation. The heat provided to the second section may mobilize at least some hydrocarbons in the second section. A portion of the hydrocarbons from the second section may be induced to flow into the first section. A mixture of hydrocarbons may be produced from the formation. The produced mixture may included at least some pyrolyzed hydrocarbons.

Abstract: An oil shale formation may be treated using an in situ thermal process. Fluid migration into and/or out of a treatments area in the formation may be inhibited. In some embodiments, a barrier may be used to inhibit migration of fluids into and/or out of the treatment area. Heat may be provided to the treatment area and subsequently, hydrocarbons, H2, and/or other formation fluids may be produced from the formation.

Abstract: A hydrocarbon containing formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, and/or other formation fluids may be produced from the formation. A formation to be treated may produce a relatively large amount of condensable hydrocarbons and/or a relatively large amount of non-condensable hydrocarbons. The formation to be treated may be chosen based on a initial total organic carbon content of the formation.

Abstract: A system for recovery of hydrocarbons or thermal energy from host-rock fotions bearing coal, oil-shale, tar-sands or oil by use of a hydrologic cell which conveys a reacting fluid under pressure to a source-aquifer, thereafter extracting thermal energy or hydrocarbons from said host-rock, moving said hydrocarbons or thermal energy to said sink-aquifer and then removing the hydrocarbons or thermal energy to the surface for ultimate use.

Abstract: A method and assembly for igniting a burner using a pyrophoric liquid. A quantity of pyrophoric liquid is first transported from a container to a slug launching chamber and then transporting into a fuel gas stream for the burner. The slug launching chamber is flushed with a hydrocarbon liquid to remove any of the quantity of pyrophoric liquid from the launching chamber, while the assembly can be purged with an inert gas prior to removing the pyrophoric liquid container and replacing it with a new container.

Abstract: A method for improving hydrocarbon flow from a consolidated, tight reservoir rock having authigenic clay cementation includes thermally heating the reservoir rock in-situ surrounding a production well to change the mode of occurrence of clay cements within the rock so as to enhance reservoir permeability and carrying out rapid flowback into the production well.

Abstract: Subterranean mineral seams, such as coal, which have been penetrated by gas production wells are stimulated to produce additional gas by placing a liquid, such as a solvent for coal, in the wellbore and in communication with a tubing extending within the wellbore and having a frangible shear disk assembly disposed therein. Pressure is increased inside the tubing string by pumping gas and/or liquid into the tubing string in sufficient quantity to cause the shear disk to release fluid pressure to act on the fluid in the open hole wellbore portion so that a substantial pressure pulse is exerted on the coal seam to effect rubblization of the coal to form a cavity and release entrapped or adsorbed gas for production up through the well. Imposition of rapid and cyclic pressure pulses on the coal seam at pressures up to 5000 psi above the in situ stress improves production of gas therefrom.

Abstract: The invention is a closed-loop, thermal process for remediating soil contaminated with hydrocarbon chemicals; it is particularly well suited for the remediation of soils containing hydrocarbons with relatively high boiling points and for the remediation of soils which contain clays or silts. The process uses a combination of at least one extraction well which is used to withdraw vapors from contaminated soil and at least one injection well, called a "fire" well which is used to burn both a source of hydrocarbon fuel and all of the hydrocarbons present in the recovered vapors and then inject the combustion gases into contaminated soil. The heat in the combustion gases is used to raise the temperature of the contaminated soil and volatilize hydrocarbons in the soil. Dielectric heating can be used to supplement the heating performed by the combustion gases.

Abstract: A method for underground gasification of coal or browncoal in an inclined coal seam, in which a substantially uniform gasification or combustion front is maintained by filling the cavity generated by gasification of coal with a filler so as to drive the front in an upward direction through the coal seam. The gases for maintaining the gasification are introduced through a first borehole and the combustion gases being discharged through a second borehole. The first of these boreholes is used for introducing the filler and this borehole following the coal seam, preferably in a more or less horizontal direction. The other borehole being connected in the coal seam at to the lower end of the first borehole.

Abstract: A method is disclosed for improving the effectiveness of fluid transport in a petroleum reservoir. That method comprises increasing the permeability of a portion of the reservoir by removing liquid water from that portion by evaporating off the liquid water. Preferably, substantially all of the liquid water is removed. In one embodiment, the liquid water is evaporated off by heating the portion to a temperature above the boiling point of water for the ambient pressure of the portion. In another embodiment, the liquid water is evaporated off by injecting into the reservoir a gas (such as heated nitrogen) that is undersaturated with respect to water. In a third embodiment, steam is injected into a well within the portion, and the steam is blown down to vaporize substantially all of the liquid water and to cause the vaporized water to leave the portion. In still another embodiment, superheated steam is injected into the reservoir.

Abstract: Complexes of underground batch retorts, designed to duplicate surface retort prototypes proven successful in use, which may extend for miles on branch drifts intersecting central main drifts above and below the retorts, the main drifts emerging at surface. The batch retorts are very large, deep, planned mine cavities, with relatively small upper and lower openings, remaining after shale oil ore has been extracted by vertical crater retreat stoping and free-fall controlled at the bottom opening. Resort openings are sealed after they have served their purposes, which enables the symmetrical progression of the upper and lower branch drifts along which the retorts are mined. The drifts provide access to blasting sites, conveyors for removing fragmented ore to be crushed and screened, and conveyors for returning processed ore to the retorts. Loading is accomplished through a retracting device which deposits processed ore with minimal free-fall, to avoid creating fines in the loading process.

Abstract: An in-situ coal gasification process for practice on a formation having one or more dipping coal seams that involves, directionally drilling a production wellbore into a burn module designated in each coal seam each from a separate surface location and, from one surface location, directionally drilling injection wellbores to a designated burn module in a coal seam.

Abstract: New controlled retracting gasifying agent injection point process for UCG sites.The process consists of a retraction of the gasifying agent injection point achieved by gradually plugging the tubing ends either by pneumatic injection of inert granulated material with a thermosetting binder, or by closing valves set at regular intervals inside the tubings.

Abstract: Disclosed is a process for controlling subsidence during underground gasification of coal. Prior to the complete coal gasification step, holes are provided extending from the bottom to the top of the coal seam and these holes filled with heat resistant support material. Thereafter, the complete gasification process is carried out.

Abstract: The process consists of a retraction of the gasifying agent injection point achieved by gradually plugging the tubing ends either by pneumatic injection of inert granulated material with a thermosetting binder, or by closing valves set at regular intervals inside the tubings.

Abstract: Enhanced oil recovery from a crude oil reservoir is promoted following primary oil production, by subjecting the reservoir to water flooding, discontinuing the water flooding, preferably when the remaining oil is at an OIP level above 0.10, and then subjecting the reservoir to fireflooding with gas having an O.sub.2 content of at least 50%, preferably above 85%.

Abstract: Process and apparatus are set forth for ascertaining and controlling the flammability of produced gas from an in-situ combustion enhanced petroleum production well whereby the produced oil is sampled, the produced gas is periodically sampled, the temperature, pressure and produced gas flow rate are sensed, and a moderant gas is added to the production well to avoid flammability when the sampled and sensed parameters indicate a flammability condition exists.

Abstract: The combustion front in an in situ combustion oil recovery operation is stabilized by cyclically varying the injection rate of the gaseous oxidant which is injected through the injection well. Periodic reduction in the injection rate of the oxidant halts the advance of the combustion front through the formation and permits the formation fluids to flow in a reverse direction back towards the front so that burned through fingers or streaks collapse and any overriding tendencies of the front are corrected. In this way, the vertical conformance of the front is increased to improve the sweep efficiency of the process. The process is most effective in externally pressured formations.

Abstract: An improved tertiary recovery method for obtaining medium and high gravity crude oil from subsurface formations is disclosed wherein the gravity of the crude oil is downgraded. An in-situ combustion method is used where the boiling temperature of a light viscous crude is altered to provide residual coke, enabling sustained combustion.

Abstract: A method for identifying the location of the extent of travel of a combustion front following an in situ oil recovery operation employs a source of seismic energy and at least one seismic receiver for detecting seismic reflection signals from boundaries between subterranean formations on either side or opposite sides of such location. The properties of these seismic reflection signals are changed by the reduction in water saturation in the oil reservoir caused by the drying effect of the combustion front, and any such change is detected as an identification of the location of the extent of travel of the combustion front through the oil reservoir.

Abstract: A method of underground gasification of a coal seam comprises the steps of opening it by drilling injection and production wells, interconnecting said wells, setting the coal afire and gasifying the coal by supplying a gaseous medium into the first wells and removing the produced gas from the second wells. The seam is gasified successively layer by layer in the direction from the roof of the seam to its bottom. Each subsequent layer is gasified after gasification of the preceding layer is completed and rock overlying the gasified layer is no longer shifted. The thickness of said layer is chosen so that the height of a zone containing cracks formed as a result of rock shift does not exceed the depth of occurrence of the gasified layer.

Abstract: A method and apparatus for generating heat from in situ in ground burning of coal. The method described involves lowering a boiler connected to a water line and a steam line into burning coal region and heating the boiler to produce steam from water. The steam is useable to drive steam turbine/generator equipment or as a heat source. The apparatus for generating steam includes a boiler with a number of heat circulating tubes to quickly heat the water. The boiler is fed by a small diameter water line. Steam from the boiler is removed through a larger diameter line.

Abstract: This invention discloses a more efficient and more self supporting method of producing oil from a viscous oil-bearing permeability stratified reservoir. In situ combustion with oxygen is carried out near a first injection well in a manner such that carbon dioxide substantially free of nitrogen is produced. The carbon dioxide substantially free of nitrogen produced by in situ combustion is then injected into a second injection well to swell, reduce the vicosity of in-place oil and displace oil from a separate part of the stratified reservoir. Water with or without other mobility and solubility control agents can be injected in either or both the combustion step and carbon dioxide displacement step. In situ combustion with or without nitrogen may thereafter be initiated adjacent the second injection well to produce the less permeable or more viscous oil-bearing strata to either produce oil left by carbon dioxide injection or to produce more nitrogen-free carbon dioxide.

Abstract: A method for controlling the average particle size of a fragmented permeable mass of formation particles formed in an in situ retort in a subterranean formation containing oil shale is provided. At least one void is excavated in the subterranean formation, leaving zones of unfragmented formation above and below the void. Such a zone of unfragmented formation has naturally occurring cleavage planes and a substantially horizontal free face adjoining the void. An array of a plurality of substantially vertical blastholes is formed in at least one of the zones of unfragmented formation and each such blasthole is loaded with explosive for forming a substantially horizontal array of explosive charges. The spacing distance between adjacent blastholes or explosive charges in the array is from about 10 to about 15 times the average distance between cleavage planes when the oil shale formation has an average grade of more than about 20 gallons per ton.

Abstract: Any desired number of alternate parallel rows of injection and production well bores are positioned to establish a block gasification pattern. Combustion links are established between adjacent injection and production well bores in a direction generally perpendicular to said rows. The block pattern is ignited simultaneously through all of the injection well bores such that the pattern is gasified along the multiple linking paths in both directions between each injection well bore and its adjacent production well bores. In this manner the entire area of deposit defined by the block pattern is gasified simultaneously and may be separated from other similar block patterns by a barrier, thereby eliminating the problem of direct contact with burned-out areas.

Abstract: The present invention is directed to a method of enhanced oil recovery by fire flooding petroleum reservoirs characterized by a temperature of less than the critical temperature of carbon dioxide, a pore pressure greater than the saturated vapor pressure of carbon dioxide at said temperature (87.7.degree. F. at 1070 psia), and a permeability in the range of about 20 to 100 millidarcies. The in situ combustion of petroleum in the reservoir is provided by injecting into the reservoir a combustion supporting medium consisting essentially of oxygen, ozone, or a combination thereof. The heat of combustion and the products of this combustion which consist essentially of gaseous carbon dioxide and water vapor sufficiently decrease the viscosity of oil adjacent to fire front to form an oil bank which moves through the reservoir towards a recovery well ahead of the fire front. The gaseous carbon dioxide and the water vapor are driven into the reservoir ahead of the fire front by pressure at the injection well.

Abstract: Disclosed is a method for recovering oil from a dipping subterranean, viscous oil-containing reservoir having an underlying body of water. An in situ combustion operation is initiated using an oxidizing gas injected through an injection well in fluid communication with the lower portion of the reservoir near the oil/water interface. Fluids including oil and effluent gas are recovered from the reservoir through a production well in fluid communication with a shallower portion of the reservoir. After a predetermined amount of time, injection of the oxidizing gas is terminated and the reservoir is allowed to undergo a soaking period for a predetermined amount of time. Thereafter, a water drive is initiated by injecting water into the injection well and fluids including oil are recovered from the reservoir through the production well.

Abstract: A method for gasifying subterranean coal deposits by positioning a cased injection well to extend from the surface into the coal deposit with the injection well extending horizontally through the lower portion of the coal deposit with the horizontal portion of the well being cased with a perforated casing; positioning an injection tubing in the injection well; positioning a production well to extend from the surface to a point near the lower end of the injection well; igniting the coal deposit; gasifying a portion of the coal deposit between the bottom of the production well and the lower end of the injection tubing well by injecting a free-oxygen containing gas into the coal deposit through the injection tubing and recovering product gases through the production well and thereafter gasifying a second portion of the coal deposit by withdrawing the injection tubing a selected distance and thereafter injecting free-oxygen containing gas into the coal deposit and recovering product gases from the production well

Abstract: In a method for injecting a gaseous stream into a hot subterranean zone by positioning a casing means in fluid communication with the hot subterranean zone and the surface; insulating a lower portion of the outer surface of the casing, the insulated lower portion including the portion of the casing in the hot subterranean zone; and injecting the gaseous stream into the hot subterranean zone through the casing at a rate sufficient to maintain the casing below a selected maximum temperature, the improvement comprising: the use of a reduced diameter casing as the lower portion of the casing. An apparatus useful in the practice of the improved method is disclosed.

Abstract: A method for conditioning a coal seam prior to in-situ gasification to increase the permeability of the coal seam to the flow of combustion-supporting gas therethrough and thus increase the efficiency of gasification wherein a wettability alteration fluid is injected into the coal seam via an injection well and fluids including the wettability alteration fluid are recovered from a spaced apart production well. Injection of the wettability alteration fluid is continued into the coal seam until the permeability thereof to the flow of the combustion-supporting gas therethrough has increased to a maximum extent. Suitable wettability alteration fluids include carbon dioxide, volatile amines, aqueous solutions containing phosphates, phenols, flue gas and alcohols, and mixtures thereof.