Abstract: Self-loading systems and methods for disposal of waste materials in a deep underground formation may include at least one wellbore that runs from the Earth's surface to the deep underground formations, wellbore viscous fluid within that at least one wellbore, and at least one waste capsule, wherein the at least one waste capsules houses some waste and is configured to fall within both the at least one wellbore and the wellbore viscous fluid. The systems and methods may also include at least one human-made cavern located in the deep underground formation and connected to the at least one wellbore, wherein the at least one human-made cavern may be configured to receive the at least one waste capsule. The systems and methods may also include a counter for counting waste capsules and/or a robot for dropping waste capsules into a wellhead leading to the at least one wellbore.

Abstract: Self-loading systems and methods for disposal of waste materials in a deep underground formation may include at least one wellbore that runs from the Earth's surface to the deep underground formations, wellbore viscous fluid within that at least one wellbore, and at least one waste capsule, wherein the at least one waste capsules houses some waste and is configured to fall within both the at least one wellbore and the wellbore viscous fluid. The systems and methods may also include at least one human-made cavern located in the deep underground formation and connected to the at least one wellbore, wherein the at least one human-made cavern may be configured to receive the at least one waste capsule. The systems and methods may also include a counter for counting waste capsules and/or a robot for dropping waste capsules into a wellhead leading to the at least one wellbore.

Abstract: Systems and methods for long-term disposal of radioactive or nuclear waste materials, in liquid, solid, and/or other physical forms, into human-made caverns, within deep geologic rock formations, derived from a wellbore, are manufactured by use of drilling and reaming technologies. The radioactive waste may be preprocessed from original surface storage site(s), transported, temporarily surface stored, and then finally further processed at a selected well site before injection into the subterranean deep human-made caverns within the host rock (deep geologic rock formations).

Abstract: Disclosed embodiments include methods of removing carbon dioxide from combustion gas from an engine of a vehicle, systems for removing carbon dioxide from combustion gas from an engine of a vehicle, vehicles, methods of managing carbon dioxide emissions from an engine of a vehicle, and computer software program products for managing carbon dioxide emissions from an engine of a vehicle.

Abstract: A carbon dioxide tank (3) is connected to a pump device (5). The pump device (5) is joined and connected with an infusion well (9), which is a tubular body. The infusion well (9) extends downward beneath the ground (7) and is provided so as to reach a saltwater aquifer (11). Part of the infusion well (9) forms a horizontal well (10) in a substantially horizontal direction. In other words, the horizontal well (10) is a location in which part of the infusion well (9) is formed in a substantially horizontal direction within a saltwater aquifer (11). The horizontal well (10) is provided with filters (13), which are porous members. For the filters (13), for example, a fired member in which ceramic particles are mixed with a binder that binds those particles can be used. Moreover, if the hole diameter for the filters (13) is small, microbubbles with a smaller diameter can be generated.

Abstract: Methods and systems are provided for sulfur disposal through preparation of a micro-sized sulfur slurries. Micro-sized sulfur slurries are created for downhole disposal by forming sulfur particulates, which are then combined with a carrier fluid. The micro-sized sulfur slurries may be introduced to a subterranean formation, in some cases, to an unconsolidated sand formation by way of a dilation mechanism. Some embodiments comprise forming micro-sized sulfur slurries through a conversion process that converts molten sulfur to powder sulfur by gas cooling of atomized sprays of molten sulfur. Advantages of the embodiments disclosed herein as compared to many conventional methods include higher efficiencies, lower cost, and enhanced disposal of sulfur material. Furthermore, forming a micro-sized sulfur slurry allows for a more convenient form of transport. Additionally, high sulfur loading rates may be achieved, ultimately allowing for more economical sulfur transport.

Abstract: The methods disclosed herein relate to sequestering carbon dioxide in an aquifer by trapping the CO2 in interstitial pores of the aquifer. Trapping the CO2 in the interstitial pores of the aquifer prevents the sequestered CO2 from escaping back to the surface and allows a much larger percentage of a CO2 to be stably sequestered compared to techniques that rely on dissolving the CO2 to achieve stable sequestration.

Abstract: Techniques for reducing a carbon emissions intensity of a fuel includes injecting a carbon dioxide fluid into a first wellbore; producing a hydrocarbon fluid from a second wellbore to a terranean surface; and producing a fuel from the produced hydrocarbon fluid, the fuel including a low-carbon fuel and assigned an emissions credit based on a source of the carbon dioxide fluid.

Abstract: The present invention is directed to methods for removing CO2 from air, which comprises exposing sorbent covered surfaces to the air. The invention also provides for an apparatus for exposing air to a CO2 sorbent. In another aspect, the invention provides a method and apparatus for separating carbon dioxide (CO2) bound in a sorbent.

Abstract: A method and arrangement are proposed for introducing a CO2 composition into a subterranean geological formation for storage of CO2 therein. The CO2 composition is initially injected into the formation using a first set of injection parameters at which the CO2 composition is a supercritical fluid having first viscosity and density values. The injection parameters are then modified such that the CO2 composition is injected into the formation using at least one second set of injection parameters at which the CO2 composition is a supercritical fluid having second viscosity and density values that are different from said first viscosity and density values, wherein said injection parameters include the injection temperature, injection pressure and hydrocarbon content of the CO2 composition.

Abstract: A method for disposal of desalination concentrated brine waste product from a desalination process provides that the desalination concentrated brine waste product is injected, along with a carbon dioxide waste product, typically into an imperviously capped porous rock formation, typically including a saline aquifer. The desalination concentrated brine waste product and the carbon dioxide waste product (i.e., which may be injected as a supercritical liquid) may be injected simultaneously or sequentially. The method provides for environmentally acceptable disposal of the desalination concentrated brine waste product and the carbon dioxide waste product.

Abstract: The present invention relates to a novel method of mining underground coal and recovering coal seam gas, the method including locating a seam of coal; digging a mine shaft to reach the seam of coal; constructing a ventilated underground control center which includes a computerized control panel, wherein the computerized control panel controls the movement of a drill head, a hollow drill shaft, a movable hydraulic shield, a movable resin roof bolting machine, and a movable waste extrusion device; providing mining personnel to the ventilated underground control center; wherein the mining personnel operate the computerized control panel to perform the tasks of moving the drill head into the seam of coal to obtain aggregate coal and coal seam gas; extruding waste material into mined-out space of the coal seam; and transferring the aggregate coal and coal seam gas to the surface of the earth.

Abstract: Methods and systems for gas sequestration are provided. The systems include a porous storage reservoir containing a dense fluid; a first tubing string, configured to provide and inject a gaseous emissions (GE) stream at or near the top of the porous storage reservoir above the base portion of the porous storage reservoir; and a second tubing string configured to withdraw the dense fluid from the base portion of the porous storage reservoir. In some embodiments, the first and second tubing strings may be encased in a single well bore and may include measurement and control equipment for pressure management of the injection locations. The withdrawn dense fluids may be re-injected into an overlying porous reservoir or may be sent to the surface for treatment. Methods are provided for injection of GE and withdrawal of dense fluids for safe, long term gaseous sequestration of significant portions of carbon dioxide (CO2) and associated gases (gaseous emissions, GE).

Abstract: A method for in situ heating of a subsurface formation is provided. The method includes receiving hydrocarbon fluids produced from the subsurface formation as a result of heating. The method also includes processing the produced fluids to generate a hydrocarbon stream. A portion of the hydrocarbon stream is then delivered to a combustor along with an oxygen-containing stream as a combustion mixture. A diluent gas stream may also be provided for cooling. The mixture is then combusted to generate electricity, and to release an exhaust stream comprising carbon dioxide. The method also includes using at least a portion of the exhaust gas stream generated from the combustion for injection or for sequestration, thereby minimizing atmospheric release. In addition, at least a portion of the electrical power is delivered to a plurality of electrically resistive heating elements to deliver heat to the subsurface formation. A low emission power generation system is also provided.

Abstract: A system for disposing of aggregate material in a mine cavern between a mine ceiling and a mine floor includes a first pump for pumping water from the cavern, a second pump for pumping emulsion to the cavern, a gated proportioning mechanism, and a water line extending between the first and second pumps and being accessible at the gated proportioning mechanism such that aggregate in the gated proportioning mechanism is introduced into the water line to form the emulsion. The second pump is configured such that the emulsion is pumped into the cavern at a pressure between about 20 pounds per square inch and about 30 pounds per square inch and settles on the mine floor in a pile having an angle of repose between about 1:1.5 and about 1:3.5. The pressure is insufficient to fracture the mine floor and insufficient to fracture the mine ceiling.

Abstract: An engineered, scalable underground containment system and method for storing compressed gases or liquids in permeable rock formations using conventional drilling techniques. The porosity and permeability of the formation may be enhanced to maximize reservoir capacity and increase the rate at which gases and liquids can be introduced into and removed from the reservoir. In some embodiments, layers of cap rock in the formation are utilized as containment barriers, and in some, containment barriers are constructed around the storage zones.

Abstract: Underground sequestration system and method in which a liquid or gas is stored in a sequestration zone of enhanced porosity in an underground geological formation, with a containment barrier around the sequestration zone. Conditions within the formation are monitored to verify the integrity of the sequestered substance, and any necessary repair or maintenance is done through wells that extend into the formation. In some disclosed embodiments, the porosity of the formation in the sequestration zone is enhanced by boreholes and laterals that are drilled with high velocity hydraulic cutting jets, and the sequestered liquid or gas is injected into the sequestration zone through the boreholes and laterals. Additional boreholes and laterals are employed in the containment barrier, and the barrier is formed of a thixotropic material that is injected into the formation through the additional boreholes and laterals.

Abstract: A process and system for release and recovery of methane from subterranean methane hydrate deposits in which heated CO2 is used to displace methane from the methane hydrate deposits and a portion of the displaced methane is routed to a combustion device proximate the deposit for combustion in-situ, generating heated CO2 which is introduced into the deposit, displacing additional methane, a portion of which is routed to the combustion device, thereby providing a substantially self-sustaining process. Portions of the displace methane not routed to the combustion device are captured for use elsewhere.

Abstract: A method for recovering natural gas from a group of subterranean zones containing natural gas, including injecting an amount of a displacing gas into a first subterranean zone, producing a first produced gas from the first subterranean zone, collecting an amount of the first produced gas wherein the quality of the collected first produced gas is higher than or equal to a threshold production quality for the first produced gas, injecting an amount of the first produced gas into a second subterranean zone wherein the quality of the injected first produced gas is higher than or equal to a threshold injection quality for the first produced gas, producing a second produced gas from the second subterranean zone, and collecting an amount of the second produced gas wherein the quality of the collected second produced gas is higher than or equal to a threshold production quality for the second produced gas.

Abstract: A system and series of methods, which utilize Geopressured-Geothermal (GPGT) energy for the enhanced recovery of formation crude oil. The system is designed to interface with a conversion system which concentrates the GPGT brine while recovering H2O distillate and gas, e.g., as taught by Nitschke in U.S. Pat. Re. 36,282. The system promotes enhanced oil recovery (EOR) from an oil formation via steamflood and optional gas injection, powered by the GPGT gas and using the recovered H2O distillate for source water. The system optionally reuses the bulk of the injected EOR fluids via thermal regeneration and volume replenishing, alleviating disposal costs and environmental stresses. The system manages the concentrated GPGT brine byproduct by optionally producing solid salt for sale, flowing to an appropriate end-user, or disposing in a suitable subterranean formation.

Abstract: A method of treating particulate hard materials driven to the surface of a well in a returning well flow in connection with a producing well or well stimulation operations in the petroleum production industry, the method including fragmentation of the hard particles by means of a crushing device, whereupon the fragmented hard particles are turned into a slurry which is then re-injected into an injection well.

Abstract: 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.

Abstract: Methods for forming a barrier around at least a portion of a treatment area in a subsurface formation are described herein. Sulfur may be introduced into one or more wellbores located inside a perimeter of a treatment area in the formation having a permeability of at least 0.1 darcy. At least some of the sulfur is allowed to move towards portions of the formation cooler than the melting point of sulfur to solidify the sulfur in the formation to form the barrier.

Abstract: Systems, methods, and heaters for treating a subsurface formation are described herein. At least one method for providing acidic gas to a subsurface formation is described herein. The method may include providing heat from one or more heaters to a portion of a subsurface formation; producing fluids that include one or more acidic gases from the formation using a heat treatment process. At least a portion of one of the acidic gases may be introduced into the formation, or into another formation, through one or more wellbores at a pressure below a lithostatic pressure of the formation in which the acidic gas is introduced.

Abstract: A method for the disposal of sludge and collection of byproduct gases of decomposition uses a crisscross trenching pattern, excavated, filled and covered in a sequential and cyclic manner. Once the crisscrossing trenches have been completely filled with sludge, evolving gases are captured under an impermeable sheeting placed over the disposal site and then drawn off for use.

Abstract: A process for treating produced water to generate high pressure steam. Produced water from heavy oil recovery operations is treated by first removing oil and grease. Feedwater is then acidified and steam stripped to remove alkalinity and dissolved non-condensable gases. Pretreated produced water is then fed to an evaporator. Up to 95% or more of the pretreated produced water stream is evaporated to produce (1) a distillate having a trace amount of residual solutes therein, and (2) evaporator blowdown containing substantially all solutes from the produced water feed. The distillate may be directly used, or polished to remove the trace residual solutes before being fed to a steam generator. Steam generation in a packaged boiler, such as a water tube boiler having a steam drum and a mud drum with water cooled combustion chamber walls, produces 100% quality high pressure steam for down-hole use.

Abstract: A process for treating produced water to generate high pressure steam. Produced water from heavy oil recovery operations is treated by first removing oil and grease. Pretreated produced water is then fed to an evaporator. Up to 95% or more of the pretreated produced water stream is evaporated to produce (1) a distillate having a trace amount of residual solutes therein, and (2) evaporator blowdown containing substantially all solutes from the produced water feed. The distillate may be directly used, or polished to remove the trace residual solutes before being fed to a steam generator. Steam generation in a packaged boiler, such as a water tube boiler having a steam drum and a mud drum with water cooled combustion chamber walls, produces 100% quality high pressure steam for down-hole use.

Abstract: Systems and methods are disclosed for disposing of aggregate material in the mine caverns from which these materials were originally obtained. In an apparatus for combining aggregate material, for example, chat or tailings, with water, an emulsion is formed. The water is drawn from the cavern, through a casing. The emulsion is pumped back into the cavern below ground level, through another casing, the pumping at pressures that overcome the forces of the water in the cavern and create turbulence in the water, such that the emulsion spreads throughout the cavern, at a good angle of repose, to maximize the amount of material disposed of.

Abstract: Invert emulsion compositions including an oleaginous, a non-oleaginous and an amine surfactant that are useful in the oil and gas well drilling art are disclosed. The amine surfactant is selected so that the invert emulsion can be converted form a water-in-oil type emulsion to a oil-in-water type emulsion upon the protonation of the amine surfactant. Deprotonation of the amine surfactant reverses the conversion. This solution also permits the conversion of oil-wet solids in the fluid into water-wet solids.

Abstract: A method of optically determining a change in magnitude of at least one dimensional characteristic of a sample in response to a selected chamber environment. A magnitude of at least one dimension of the at least one sample may be optically determined subsequent to altering the at least one environmental condition within the chamber. A maximum change in dimension of the at least one sample may be predicted. A dimensional measurement apparatus for indicating a change in at least one dimension of at least one sample. The dimensional measurement apparatus may include a housing with a chamber configured for accommodating pressure changes and an optical perception device for measuring a dimension of at least one sample disposed in the chamber. Methods of simulating injection of a gas into a subterranean formation, injecting gas into a subterranean formation, and producing methane from a coal bed are also disclosed.

Abstract: A process for treating produced water to generate high pressure steam. Produced water from heavy oil recovery operations is treated by first removing oil and grease. If necessary, the pH is then adjusted, normally downward, releasing at least some carbonate alkalinity as free carbon dioxide. Pretreated produced water is then fed to an evaporator. Up to 95% or more of the pretreated produced water stream is evaporated to produce (1) a distillate having a trace amount of residual solutes therein, and (2) evaporator blowdown containing substantially all solutes from the produced water feed. The distillate may be directly used, or polished to remove the trace residual solutes before being fed to a steam generator. Steam generation in a packaged boiler, such as a water tube boiler having a steam drum and a mud drum with water cooled combustion chamber walls, produces 100% quality high pressure steam for down-hole use.

Abstract: This invention is method of recovering gas from a gas-bearing subterranean formation in which gas is produced from an upper portion of the formation and a waste gas is injected into a lower portion of the formation to dispose of the waste gas. The waste gas is injected within a 3000 foot (914 m) radial distance from the production of the gas. The injection and production can be carried out using one well or a plurality of wells.

Abstract: A method is provided for simultaneously developing caverns while depositing wastes or other materials in them. A well is first drilled into a salt formation and the development of a salt cavern by means of solution mining is initiated. When the development of the cavern has been carried out to an extent sufficient to accommodate the injection of a prescribed amount of wastes or other materials, injection of the wastes or other materials through the well is started while continuing to develop the cavern by solution mining. The injection of the wastes or other materials may be carried out continuously or intermittently. The proportion and rates of wastes or other materials and mining water injected into the well are monitored and regulated so that cavern development continues at a rate that allows the cavern to reach an intended prescribed size while the wastes or other materials are injected and deposited into the cavern.

Abstract: An evaporation based method of treating produced water from heavy oil production. A produced water from heavy oil recovery operations treated by first removing oil and grease to a desired level, preferably to about twenty parts per million, or less. If necessary, the pH is then adjusted, normally downward and by acid addition, to release at least some carbonate alkalinity as free carbon dioxide. Preferably, all non-hydroxide alkalinity is removed, or substantially so, by introducing the feedwater into a decarbonator. Feedwater is introduced into an evaporator, and the feedwater is evaporated to a selected concentration factor to produce (1) a distillate having a small amount of residual solutes, and (2) evaporator blowdown containing residual solids. Distillate may be directly used for steam generation in a once-through steam generator, or polished by ion exchange or electrodeionization prior to feed to a packaged boiler.

Abstract: A process for enhanced oil recovery from an extraction operation comprises the steps of selection of an appropriate hydrocarbon bearing stratum; providing at least one production well and one injection well; and injecting into the target stratum a slurry formed from sand, viscous liquids or oily sludge, which is delivered at or near formation fracture pressures. Monitoring of bottom hole pressure is carried out, to permit delivery of the slurried wastes in a series of injection episodes, in which the length of the episodes and interinjection periods is determined by maintaining the bottom hole pressure within a preselected range. The position and spread of the slurried wastes within the target stratum may be monitored through the use of additional monitoring steps.

Abstract: A method for the disposal of biosolids, the method comprising providing a supply of biosolids; selecting an introduction formation below a ground surface, the introduction formation comprising a natural gas formation in a gas accumulation zone; introducing the biosolids into the introduction formation at a pressure sufficient to create and maintain fractures within the selected introduction formation; and allowing degradation of the introduced biosolids.

Abstract: The present invention relates to subterranean cementing operations and, more particularly, to cement composition that include improved lost circulation materials, and methods of using such cement compositions in subterranean formations. In certain exemplary embodiments, the improved lost circulation materials include inelastic particles of polyethylene, polystyrene and/or polypropylene. Optionally, the cement compositions also may include additives such as fly ash, a surfactant, a dispersant, a fluid loss control additive, a conventional lost circulation material, an generator, a retarder, a salt, a mica, fiber, a formation-conditioning agent, fumed silica, bentonite, expanding additives, microspheres, weighting materials, or a defoamer.

Abstract: In monitoring a stratum disposal field for wastes, running tubes installed in the vicinity of a gallery or disposal holes, in a nearby rock bed, or within a gallery support or buffer members in the disposal holes have installed therein a movable monitoring device provided with various sensors, a water sampling device and the like. The monitoring device may be movable or fixed in a predetermined position, for measurement of the temperature, displacement, strain, stress and underground water in connection with the rock bed, the gallery support or the disposal space buffer members. Measurement of the clearances in the rock bed, the gallery support back or the disposal space buffer members is monitored. Also, sampling of underground water in the rock bed, the gallery support or the buffer members is effected, thus reducing the number of sensors, drilled holes, communication cables to facilitate the exchange or maintenance of the sensors, communication cables and the like.

Abstract: Sealant compositions and methods of using the same to isolate a subterranean zone are provided. The compositions include partially polymerized furfuryl alcohol/aldehyde, a coupling agent, a diluent, a curing agent, a ductility imparting agent, and a filler for increasing the compressive strengths of the sealant compositions. Methods of isolating a subterranean zone include pumping the foregoing sealant composition into a well bore down through a conduit and up through an annulus disposed between the conduit and the walls of the well bore. The sealant composition exhibits a sufficiently long cure time such that it does not harden until it reaches the annulus. Thus, the sealant composition effectively attaches the conduit to the walls of the well bore. The sealant composition is substantially resistant to degradation by waste chemicals disposed of in the well bore.

Abstract: In a method and apparatus for transferring material in a wellbore in an earth formation, a pipe is inserted into the wellbore. A conduit is inserted alongside the pipe into the wellbore. The conduit is fixed to the pipe and has a first section with a perforated wall located adjacent a non-production interval of the formation, and has a second section with an unperforated wall located adjacent a production interval of the formation. The material is injected into the conduit and out the perforated wall of the first section of the conduit.

Abstract: An improved method and apparatus for processing deleterious material on a floating vessel during transportation from a well to a disposal site. The vessel contains equipment for the slurrification and agitation of the deleterious material. Such equipment includes storage tanks, slurrification units, and agitation units, as well as transfer equipment such as flow lines and vacuum or pump means. The deleterious material is transferred from the drill site to the storage tanks on the vessel. The vessel then transports the material to a disposal site, such as an injection well. During transportation, the deleterious material is processed. Such processing can include slurrification and/or agitation of the deleterious material to maintain the slurry, adding fluid if necessary. Once at the disposal site, the deleterious material slurry is then transferred from the vessel to the disposal site.

Abstract: A water-base fluid for use in drilling wells and other drilling operation includes a shale which swells in the presence of water. The fluid preferably includes: an aqueous based continuous phase, and a shale hydration inhibition agent having the formula: H2N—R—{OR′}x—Y in which R and R′ are alkylene groups having 1 to 6 carbon atoms and x is a value from about 1 to about 25. The Y group should be an amine or alkoxy group, preferably a primary amine or a methoxy group. The shale hydration inhibition agent should be present in sufficient concentration to reduce the swelling of the shale. The fluid may be used for formulating drilling fluids such as invert emulsion drilling muds or clear brine drilling fluids. The fluid may also be used in the slurrification and disposal of drill cuttings that contain water swellable clays or shales.

Abstract: A method for the disposal of biosolids, the method comprising a) providing a supply of biosolids; creating a slurry of the biosolids suitable for injecting; selecting an injection formation below a ground surface, the injection formation comprising a natural gas formation in a gas accumulation zone; injecting the biosolids slurry into the injection formation at a pressure sufficient to create and maintain fractures within the selected injection formation; and allowing degradation of the injected biosolids slurry.

Abstract: A method for the disposal of biosolids, the method comprising a) providing a supply of biosolids; creating a slurry of the biosolids suitable for injecting; selecting an injection formation below a ground surface, the injection formation comprising a natural gas formation in a gas accumulation zone; injecting the biosolids slurry into the injection formation at a pressure sufficient to create and maintain fractures within the selected injection formation; and allowing degradation of the injected biosolids slurry.

Abstract: A method for the disposal of biosolids, such as municipal sewage waste, comprising injecting the biosolids into a subsurface injection formation. The method can include recovering methane generated from the degradation of the biosolids.

Abstract: The present invention includes a system of decomposing municipal solid waste (MSW) within a landfill by converting the landfill to aerobic degradation in the following manner: (1) injecting air via the landfill leachate collection system (2) injecting air via vertical air injection wells installed within the waste mass; (3) applying leachate to the waste mass using a pressurized drip irrigation system; (4) allowing landfill gases to vent; and (5) adjusting air injection and recirculated leachate to achieve a 40% to 60% moisture level and a temperature between 120° F. and 140° F. in steady state.

Abstract: A method for covering a lagoon, manure storage basin, waste water retention pond, water reservoir, open top material storage tank, stacks or piles of commodities, having a perimeter and a containment portion, wherein the method acquires the placement of a perforated tubular member about the perimeter, laying a resilient cover on the containment portion such that an edge of the cover is covering the tubular member and is sealed at the edge. A pumping device attached to the tabular member for extracting air through the tubular member with the pumping device which forces the cover downwardly by the use of negative air pressure.

Abstract: Improved methods of completing wells penetrating subterranean corrosive fluid disposal zones are provided. The methods basically comprise the steps of preparing a pumpable, water compatible, corrosion resistant, hardenable epoxy sealing composition comprised of a hardenable epoxide containing liquid and a hardening agent, placing the epoxy sealing composition in the annulus between a string of pipe and a well bore penetrating a disposal zone and allowing the epoxy sealing composition to harden.

Abstract: Acid gas is liquified by compression and cooling, mixed with water under pressure and flowed into a disposal well.

Abstract: Acid gas is liquified by compression and cooling, mixed with water under pressure and flowed into a disposal well.