Union Oil Company of California

Southern Pacific Land Co.

Mono Power Company

Tosco Corporation

Darrell L Gallup

John L Featherstone

John W Jost

Jessie P Reverente

Philip H Messer

Morton M Wong

Kevin R Kitz

Allen W Doty

Manuel E Obando

Charles F Wong

Donald M Fenton

Daniel P Hoyer

Dennis L Saunders

Gregory A Gritters

Brian J Kelly

G Todd Ririe

Carl E Flint

D Stephen Pye

David G Newell

Paul A Peaden

Richard K Glanzman

Danilo M Capampangan

Tim G Rossknecht

Michael L Barnes

Thomas S Powell

John K Leong

Douglas Cope

S Timothy Spang

Quirino S Kolimlim

Crystalline magnesium silicates are synthesized from silica-containing brines, preferably spent geothermal brines, by mixing the brine with a magnesium-containing compound, adjusting the pH of the resultant mixture between 8.0 and 14, and crystallizing the magnesium silicate from the mixture at a temperature between 50&deg; C. and 200&deg; C. Kerolite is preferably synthesized from brine by adjusting the pH in a range between 9.5 and 10.5 and heating the mixture to between 100&deg; C. and 170&deg; C. to precipitate the crystalline kerolite. The brine remaining after the crystallization step is depleted in silica and can be further processed without significant problems caused by silica scaling.

Method for synthesizing crystalline magnesium silicates from geothermal brine

The emissions of hydrogen sulfide during the production of natural gas, oil or geothermal fluids from subterranean formations and the subsequent processing of these fluids is reduced by converting the hydrogen sulfide into a hydrogen halide or a halogen acid and then using the hydrogen halide or halogen acid for scale control and/or well acidizing. In a preferred embodiment, hydrogen sulfide produced with geothermal fluids is converted into hydrochloric acid, which is then used to reduce pH and control scale formation during the extraction of energy from geothermal fluids in a geothermal power plant.

Hydrogen sulfide abatement with scale control and/or well acidizing

A method for removing selenocyanate from aqueous waste water containing a reducing agent by adding a water soluble cupric salt, said waste water containing a reducing agent having a potential to reduce the cupric ion to the cuprous ion, and removing the resulting selenocyanate precipitate from said waste water.

Method for removing selenocyanate ions from waste water

Boron, silicon and/or arsenic in geothermal steam is removed by contacting the steam with an alcohol containing at least four carbon atoms or polyols having at least two carbon atoms.

Method for removing contaminants from geothermal steam

A corrosive acid sulfate geothermal brine is mixed with a near neutral, bicarbonate geothermal brine containing above about 300 ppm silica to produce a relatively benign mixed brine of pH from about 4.5 to about 6.5 having reduced corrosivity as compared to the acid sulfate brine and a reduced tendency as compared to the near neutral, bicarbonate brine for depositing silica in equipment during brine processing.

Geothermal brine processing

A method for continuously acidizing a geological rock formation for at least 3 months comprising adding a dilute acid to a geothermal carrier fluid in a concentration less than 0.1 weight percent to produce an acidified fluid and continuously contacting the rock formation with the acidified fluid until the permeability of the formation is increased.

Slow acidizing of geological formations

Sulfurous acid and/or sulfurous acid precursors, such as sulfur dioxide, are introduced into a hydrogen sulfide-containing geothermal brine or fluid prior to extracting energy from the resulting mixture by, e.g., passing the mixture through a flash vessel or a heat exchanger. The introduction of the sulfurous acid or its precursors into the geothermal brine or fluid inhibits scale formation and/or removes previously formed scale during processing of the brine or fluid.

pH modification of geothermal brine with sulfur-containing acid

One or more contaminants selected from the group consisting of acidic gases, inert particulates, and mixtures thereof are removed from steam by contacting the contaminated steam with a nonaqueous sorbent such as crystalline molecular sieves, silica gels, soda ash, carbonaceous adsorbents, and amine liquid ion exchange resins.

Method and apparatus for reducing the acid gas and/or inert particulate

A method for controlling fouling of a production or reinjection well, a flashing vessel or a heat-exchange surface exposed to a high-enthalpy geothermal brine that forms metal/silicon-containing scale comprises the addition of a metal complexing agent to the brine to form a fluid mixture containing a soluble metal/silicon component complex that inhibits the amount of scale formation when the temperature of the fluid mixture is reduced. The addition of a preferred metal complexing agent such as forms of EDTA, citric acid or acetic acid maintains dissolved aluminum species in the brine and inhibits the formation of aluminum silicate precipitate.

Inhibition of silicate scale formation

Emulsified oil contained in oil-in-water emulsions is removed from waste water by mixing cationic polyacrylamide high polymers with the waste water, forming oil-containing aggregations and separating the aggregations from the demulsified water. The demulsified water can then be more effectively polished, typically by contact with adsorbent particles, and subsequently passed to environmentally acceptable disposal locations.

Method for remediation of water containing emulsified oils

A method for controlling fouling of a flashing vessel or heat-exchange surface exposed to a high-enthalpy geothermal brine tending to form silicon-containing scale. The method adds a silicon-complexing amount of fluoroborate species to the brine to form a fluid mixture that does not produce substantial amounts of the scale when the temperature of the fluid mixture is reduced. The addition does not significantly increase corrosion rates of mild steel heat-exchanger materials of construction.

Inhibition of silica precipitation

Sulfur-containing acid is produced at a geothermal energy source from hydrogen sulfide produced as part of a geothermal process and introduced into aqueous liquid brine to lower the pH of the liquid brine. The lowered pH of the brine inhibits silica, metal sulfide and/or calcite formation on the surfaces of geothermal energy processing equipment or in subterranean formations in which the brine is injected.

The emissions of nitrogen dioxide and ammonia from cooling towers in geothermal power plants are controlled by contacting the steam condensate used as make-up water for the cooling tower with a zeolite or other molecular sieve to remove ammonia and/or ammonium ions from the condensate before it is passed into the cooling tower.

Process for controlling nitrogen dioxide and/or ammonia emissions from

Large volumes of waste water stream containing oil, greases, sometimes ferric ions, and dissolved contaminant hydrocarbons such as BTEX are rapidly treated in two stages. Initially, the oils and greases are separated, then the dissolved contaminant hydrocarbons are removed by countercurrent adsorption on powdered resinous polymeric adsorbents in an exchange zone, preferably in the absence of ferric ions. The contaminant laden adsorbents are regenerated and continuously recycled to the exchange zone.

Method for water remediation

BTEX and other hydracarbons are removed from oil field and refinery waste streams by countercurrent extraction techniques. The contaminated waste water is contacted with adsorbent particles, selected to adsorb BTEX and other hydrocarbons, circulating in counter current fashion to the waste water stream.

Growing community of inventors

Chino Hills, CA, United States of America

Darrell L Gallup