Mobil Oil Corporation

Earl S Snavely, Jr

Timothy A Jones

Daniel N Hopkins

John L Hen

Paul L Caldwell, Jr

James M Paul

William R Foster

Herbert P Singleton

A process for oxidizing a metal from a lower valence state to a higher valence state comprises contacting the metal, usually contained in a solution, with a sufficient amount of an oxygen-containing gas to provide at least about 300% excess of stoichiometric oxygen with respect to the metal at the lower valence state. The metals are preferably used as chelated solutions thereof. Some of the representative metals are iron, copper, manganese, lead or mercury.

Process for oxidizing multivalent metals

Hydrogen sulfide can be removed selectively from a gas stream also containing carbon dioxide at high pressure, such as those found at natural gas production wellheads, by contacting the gas stream with an alkaline liquid for a time period of less than about 80 milliseconds.

Process for selectively removing hydrogen sulfide from a gas stream at

A method for inhibiting the formation of scale and corrosion in a well penetrating a subterranean formation for the production of fluids from the formation comprising injecting a predetermined amount of microparticles of a basic anion exchange resin providing a source of polycations into the formation about the well and that are trapped and retained by the interstices of the formation without rendering the interstices or the formation impermeable to the flow of fluids. Thereafter a predetermined amount of an aqueous solution of scale and corrosion inhibitor is injected into the formation about the well that contacts the basic anion exchange resin and becomes fixed in a slightly soluble state either by complexation with the polycations or is precipitated by the polycations in the exchange resin. The scale and corrosion inhibitor is released slowly at effective concentration into fluids produced by the well to inhibit scale formation and corrosion.

Method for scale and corrosion inhibition in a well penetrating a

A cyclic process for removing H.sub.2 S from a gaseous stream comprising contacting the gaseous stream with a solution of a chelated polyvalent metal to produce elemental sulfur, removing the elemental sulfur, and regenerating the reaction solution, e.g., by contacting it with oxygen, and recycling the regenerated solution to the reaction zone, is modified by introducing into the solution a free chelating agent. The introduction of the free chelating agent eliminates the loss of the polyvalent metal and the chelated polyvalent metal from the reaction solution. There is also disclosed an aqueous reaction solution comprising a chelated polyvalent metal, sulfur, and a free chelating agent in the amount equal to at least about 0.1% by weight of the amount of the chelated polyvalent metal in the solution.

Method of stabilizing solutions of chelated polyvalent metals

A method for inhibiting the formation of scale and corrosion in a well penetrating a subterranean formation for the production of fluids from the formation comprising injecting a predetermined amount of microparticles of a cation exchange resin loaded with the desired cations into the formation about the well that are trapped and retained by the interstices of the formation without rendering the interstices or the formation impermeable to the flow of fluids. Thereafter a predetermined amount of an aqueous solution of scale and corrosion inhibitor is injected into the formation about the well that contacts the cation exchange resin and becomes fixed in a slightly soluble state either by complexation with the cations or is precipitated by the cations in the exchange resin. The scale and corrosion inhibitor is released slowly at effective concentration into fluids produced by the well to inhibit scale formation and corrosion.

The invention relates to a process for the selective removal of hydrogen sulfide from a gaseous stream additionally containing carbon dioxide by contacting the gaseous stream with a polyvalent metal chelate solution for a time sufficient to allow the polyvalent metal chelate to oxidize the hydrogen sulfide to elemental sulfur without allowing the polyvalent metal chelate solution to absorb appreciable amounts of carbon dioxide. The pH of the metal chelate solution should be greater than 7 and the contact time between the polyvalent metal chelate and the gaseous stream is between 0.006 and 0.08 second.

Process for the selective removal of hydrogen sulfide from gaseous

Viscous oil is recovered from a subterranean, viscous oil-containing formation by a steam flooding technique wherein steam is generated in a downhole steam generator located in an injection well by spontaneous combustion of a pressurized mixture of a water-soluble fuel such as sugars and alcohols dissolved in water or a stable hydrocarbon fuel-in-water emulsion containing an anti clay-swelling agent and substantially pure oxygen. The generated mixture of steam and combustion gases pass through the formation, displacing oil and reducing the oil's viscosity and the mobilized oil is produced from the formation via a spaced-apart production well. Suitable anti clay-swelling agents include metal halide salts and diammonium phosphate.

Steam drive oil recovery method utilizing a downhole steam generator and

Stem drive oil recovery method utilizing a downhole steam generator and

Hydrogen sulfide is removed from a gas stream by injecting an alkaline solution into the gas stream. The velocity of the gas stream is such that it has a Reynolds number of at least 50,000 and the Weber number for the injected alkaline solution is at least about 16. Alkali metal hydroxides and polyvalent metal chelates are useful alkaline solutions.

In-line injection of alkaline absorbant to remove H.sub.2 S

Viscous oil is recovered from a subterranean, viscous oil-containing formation by a steam flooding technique wherein steam is generated in a downhole steam generator located in an injection well by spontaneous combustion of a pressurized mixture of a water-soluble fuel such as sugars and alcohols dissolved in water or a stable hydrocarbon fuel-in-water emulsion and substantially pure oxygen. The generated mixture of steam and combustion gases pass through the formation, displacing oil and reducing the oil's viscosity and the mobilized oil is produced from the formation via a spaced-apart production well.

Steam drive oil recovery method utilizing a downhole steam generator

Viscous oil is recovered from a subterranean, viscous oil-containing formation by a steam flooding technique wherein steam is generated in a downhole steam generator located in an injection well by spontaneous combustion of a pressurized mixture of a water-soluble fuel such as sugars and alcohols dissolved in water and substantially pure oxygen. The generated mixture of steam and combustion gases pass through the formation, displacing oil and reducing the oil's viscosity and the mobilized oil is produced from the formation via a spaced-apart production well.

This specification discloses a method of treating water which contains oxygen dissolved therein to scavenge the oxygen therefrom and reduce the corrosiveness of the water. A sulfur-containing fuel is burned in a flue gas generator to generate a flue gas containing sulfur oxides and the flue gas is scrubbed with an aqueous sodium hydroxide solution to convert the sulfur oxides to a mixture of sodium sulfite and sodium bisulfite, the mixture being referred to generally as sodium sulfites. Ascorbic acid is included in the reaction to prevent the oxidation of the sodium sulfites to sodium sulfates and the sodium sulfites and ascorbic acid are recovered for use as an additive to scavenge oxygen from water. This additive is injected into an oxygen-containing water in an amount sufficient to scavenge the dissolved oxygen from the water. A catalyst may also be added to the water to catalyze the reaction of the sodium sulfites and oxygen.

Water treatment method to remove dissolved oxygen therefrom

This specification discloses a method of producing petroleum from a petroleum-bearing formation. A hot aqueous fluid is generated in a hot aqueous fluid generator that is fired with a sulfur-containing fuel and the hot aqueous fluid is injected into the petroleum-bearing formation and petroleum is produced therefrom. The firing of the hot aqueous fluid generator with the sulfur-containing fuel produces a flue gas which contains sulfur oxides. The flue gas is treated with alkaline water in a system comprised of a venturi scrubber vessel and a trayed emission scrubber vessel to scrub the sulfur oxides from the flue gas and the scrubber flue gas is discharged from the trayed emission scrubbers.

Petroleum production technique utilizing a hot aqueous fluid

A method of treating a subterranean formation which has undergone an in situ leaching operation which utilized an ammonium carbonate and/or bicarbonate lixiviant. In such a leach operation, ammonium ions will absorb into the clay in the formation and will present a threat of contamination to any ground waters that may be present in the formation. The present method involves flushing the formation with a strong, alkaline solution, e.g., sodium or calcium hydroxide, to convert the ammonium ions to ammonia which is easily carried from the formation by the alkaline solution. The alkaline solution is modified by adding a monovalent metal salt, e.g., sodium chloride, which prevents the clay from swelling which decreases the permeability of the formation. After substantially all of the ammonium ions are removed, the formation is then flushed with water to remove any alkaline solution which may remain in the formation.

Method of treating formation to remove ammonium ions without decreasing

A method of treating a subterranean formation which has undergone an in situ leaching operation which utilized an ammonium carbonate and/or bicarbonate lixiviant. In such a leach operation, ammonium ions will absorb onto the clay in the formation and will present a threat of contamination to any ground waters that may be present in the formation. The present method involves flushing the formation with a strong, basic solution, e.g., sodium or calcium hydroxide, to convert the ammonium ions to ammonia which is easily carried from the formation by the basic solution. After substantially all of the ammonium ions are removed, the formation is then flushed with water to remove any basic solution which may remain in the formation.

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Arlington, TX, United States of America

Earl S Snavely, Jr