Consolidated Natural Gas Service Company, Inc.

Breen Energy Solutions

Energy Systems Associates

Duquesne Light Company

Gas Research Institute

Esa Corrosion Solutions, LLC

Esa Environmental Solutions, Inc.

Duquesne Light Company and Energy Systems Associates

Cinergy Technology, Inc.

Kvb, Inc.

Bernard P Breen

James E Gabrielson

Robert A Schrecengost

Anthony Hallo

John P Bionda

Harjit Singh Hura

Roger W Glickert

James C McMichael

John H Pohl

Dennis Tobias

Howard B Lange

David Eden

John W Bjerklie

John M Koltick, Jr

Arlen W Bell

Ralph W McConnell

Steve Winberg

Chetan Chothani

Jeffrey J Sweterlitsch

Richard C Booth

Steven E Winberg

Keith S Lochart

Stephen Niksa

Joseph A Urich

Gerard F Gretz

Edward D Kramer

Charles A Lockert

Eugene Berkau

Joseph Cavello

In a method of determining amounts of condensable species present in a gas containing condensable species a probe is placed into a gas containing condensable species. The probe has a plurality of spaced apart contacts on an outer non-conductive surface. That surface is heated at a selected heating rate and then cooled at a selected cooling rate over a selected time period. During that time period current flow between the contacts and the temperature of the non-conductive surface is monitored over the selected time period. Peaks in a plot of the current flow over the selected time period and the temperature for the time corresponding to each peak are then correlated to the condensable species has a kinetic dew point at each identified temperature. The identified temperature for each identified species is compared to a predetermined correlation of dew point temperature and concentration for that species to determine the concentration of that condensable species present in the gas.

Method and apparatus for detection, measurement and control of sulfur-trioxide and other condensables in flue gas

Ammonia and optionally carbon monoxide are injected into the flue gas containing metals such as mercury in a manner so that there are sufficient amounts of these materials in the flue gas when the flue gas is at a temperature of from 900&#xb0; F. to 1,450&#xb0; F. to oxidize the metals within the flue gas. The oxidized metals are then attracted to particulates present in the flue gas. Oxidation is facilitated by a reaction zone stabilizer through which the flue gas flows. The stabilizer provides a stable continuous ignition front. These particulates bound with oxidized metals are removed from the flue gas by a particulate removal device such as an electrostatic precipitator or baghouse. After the ammonia is injected, the flue gas can be rapidly cooled to a temperature below 500&#xb0; F. to minimize decomposition of oxidized metals in the flue gas.

Control of mercury and other elemental metal emissions using reaction stabilization device

In a method for removing NOfrom the flue gas using a coal water slurry, other carbon containing fuel and water, or unburned carbon existing in the furnace itself due to continuing combustion, the ratio of carbon to water is adjusted so that a portion of the carbon forms activated carbon after injection of the fuel slurry into the flue gas. The activated carbon is then available to collect mercury chloride from the flue gas which has been formed through the enhancement of the mercury and chlorine oxidation reaction, enhanced through the heterogeneous reaction mechanism of this same activated carbon in the primary combustion fuel.

Method to decrease emissions of nitrogen oxides and mercury through in-situ gasification of carbon/water slurries

In a method of removing metals such as mercury from flue gas produced by combustion devices, water or water including a calcium-containing component or water including Clanion formers or water including both a calcium-containing component and Clanion formers is injected into the flue gas in a manner so that there are sufficient amounts of these materials in the flue gas when the flue gas is at a temperature from about 250&#xb0; F. to about 350&#xb0; F. to retain the mercury within the aqueous phase. After the water evaporates, the oxidized mercury is retained on the dry flyash particles present in the flue gas. These flyash particles bound with the oxidized mercury are removed from the flue gas by a particulate removal device, such as an electrostatic precipitator, baghouse filter or cyclone.

Dry adsorption of oxidized mercury in flue gas

In a method of measuring heat flux and corrosion in a furnace, pairs of thermocouples are attached to the back side of the furnace wall. One thermocouple of each pair is attached to a tube and the second thermocouple is attached to a web connected to that tube. A temperature differential is determined for each pair at selected time intervals. A decrease in the difference between temperature differentials indicates slag on the furnace wall has melted indicating corrosion can be occurring.

Method of monitoring heat flux and controlling corrosion of furnace wall tubes

In a method of removing metals such as mercury from flue gas produced by combustion devices, ammonia and optionally carbon monoxide are injected into the flue gas in a manner so that there are sufficient amounts of these materials in the flue gas when the flue gas is at a temperature of from 900&deg; F. to 1350&deg; F. to oxidize the metals within the flue gas. The oxidized metals are then attracted to particulates present in the flue gas. These particulates bound with oxidized metals are removed from the flue gas by a particulate removal device such as an electrostatic precipitator or baghouse.

Control of mercury and other elemental metal emissions from combustion devices by oxidation

A tubular probe has spaced apart bands or patches of the same material as the probe body attached to the probe body by an electrically insulating, high temperature material. A series of cooling tubes are provided within the probe body to direct cold air to the regions near each band. One or more probes is placed in a furnace or boiler above the ammonia injection zone. When ammonium bisulfate forms on the probe it completes an electrical circuit between the probe body and the bands and will also cause corrosion of the probe. The presence of ammonium bisulfate is detected by a change in resistance between the bands and the probe body. Electrochemical noise is generated during the corrosion process. A corrosion rate can be determined from the level or amount of electrochemical noise that is detected.

Detection, measurement and control of ammonia in flue gas

A method for monitoring and reducing corrosion in furnace boiler tubes measures electrochemical noise associated with corrosion mechanisms while corrosion is occurring at the surface of the tubes as they are exposed to combustion products. This noise is detected using a probe at the boiler waterwall surface that is connected to a corrosion monitor. The monitor contains a computer and software which determines a corrosion rate from the measured electrochemical noise. That rate is compared to a standard to determine if the rate is within acceptable limits. If not, the operator of the furnace or an Adaptive Process Controller (APC) is notified and adjusts one or more burners to change the combustion products that are responsible for the corrosion. Such an adjustment could be made by changing the amount of air or fuel being provided to the burner or other air slots or air ports. After that adjustment is made the furnace emissions could be checked for NOx, SOx and particulate emissions and further adjustments could be made to the burners to reduce those emissions.

Method of monitoring and controlling corrosion of furnace boiler tubes

A method is provided for controlling the operation of a furnace. A furnace generally includes a boiler having a combustion zone, a plurality of burners burning a mixture of fuel and air in the combustion zone producing a gaseous by-product, and an electrostatic precipitator in fluid communication with the boiler removing particulates from the gaseous by-products. The method includes the steps of monitoring operating conditions of the electrostatic precipitator on a section-by-section basis, and controlling a select one or more of the burners based upon the section-by-section monitored operating conditions.

Method of operating a furnace based upon electrostatic precipitator operation

In an improved method for reducing nitrogen oxide emissions from a furnace wherein at least one injector is attached to the furnace above the primary combustion zone a biomass or biowaste and water slurry is injected into the flue gas through the injectors. The biowaste or a biomass material can be supplemented with a fixed nitrogen source.

Method for NOx reduction by upper furnace injection of biofuel water slurry

In a furnace having a primary combustion zone for combustion of a fuel and oxidant, an in-furnace method for reducing nitrogen oxides in combustion products generated in the primary combustion zone in which at least one fluid fuel selected from the group consisting of natural gas, hydrogen, C,H,compounds, C,H,O,compounds and mixtures thereof in an amount in a range of about 2.0% to about 25% of a total heat input to the furnace and at least one nitrogenous compound selected from the group consisting of ammonia, amines, urea, cyanuric acid and mixtures thereof are injected into the furnace downstream of the primary combustion zone, forming an overall fuel-lean NO,-reduction zone.

Method and apparatus for NOx reduction in flue gases

An in-furnace method and apparatus reduces nitrogen oxides in flue gas by injecting an oil water emulsion into flue gas so that the oil and water mixes with said flue gas. The emulsion has from 35% to 80% water and is injected in sufficient quantities to provide enough oil to promote a reaction between the nitrogen oxides in the flue gas and the oil, so as to reduce nitrogen oxide content of the flue gas and to maintain overall fuel lean conditions above the primary combustion zone. The emulsion preferably is atomized before injection and may also be injected in jet streams. Other materials such as limestone, ammonia and urea could be added to the oil water emulsion prior to injection.

Use of oil water emulsion as a reburn fuel

In a method of reducing NO.sub.x a water-fixed nitrogen solution is injected into a furnace near the exit from the furnace where the temperatures exceed 2000.degree. F. and combustion is occurring. Preferably the solution is injected through a combination of atomizing nozzles and spray jets into a region of the furnace which does not exceed 2700.degree. F. A calcium compound to react with sulfur dioxide may also be added.

Method for NO.sub.x reduction by upper furnace injection of solutions of

A method of reducing NO.sub.x determines an NO.sub.x concentration profile within a zone of the furnace which is at a temperature below 2600.degree. F. A stream of fluid fuel is injected into at least one region of relatively high NO.sub.x concentration so that the fluid fuel mixes therein with the flue gas. The fluid fuel is natural gas, hydrogen, C.sub.x H.sub.y compounds, C.sub.x H.sub.y O.sub.z compounds or mixtures primarily of those compounds, in sufficient quantity to promote a reaction between nitrogen oxide in the flue gas and the fluid fuel, so as to substantially reduce nitrogen oxide content of the flue gas. The injector through which the fluid fuel is injected can be moveable and may have valves or deflectors to aid in directing the fluid fuel to regions of relatively high NO.sub.x concentration.

Apparatus and method for NO.sub.x reduction by selective injection of

A process and apparatus for combustion of a solid carbonaceous material, for example coal, in which a mixture of the solid carbonaceous material and combustion air is injected into a combustion chamber and ignited, thereby forming a fuel-lean primary combustion zone. A gaseous fuel is injected into the combustion chamber in a region downstream of the primary combustion zone, thereby forming a fuel-lean secondary combustion zone. Temperature in the secondary combustion zone is in the range of about 1800.degree. F. to 2400.degree. F.

Growing community of inventors

Pittsburgh, PA, United States of America

Bernard P Breen