# MCW_WW_Treatment

Clean_desc:
Cleaning procedure consists of a multi-stage process consisting of an initial copper removal stage using sodium bromate, aqua ammonia and ammonium bicarbonate, followed by an iron oxide removal stage consisting of ammoniated EDTA and sodium nitrite for metal passivation.


Clean_desc:
The plant mixes a 4 to 1 ratio of water to Compressor Wash (80 gal water to 20 gal compressor wash) prior to starting the compressor wash.  After insuring the turbine is on gear, the IGV's are opened and the turbine is over 700 RPM the compressor wash begins.  The compressor is washed at a rate of 6 gal/min until the operator runs out of water.  After a 30 minute soak, the turbine is then rinsed with 400 gal of RO water at a rate of 18 gal/min.  The residual water is evaporated during the drying process.


Clean_desc:
The plant uses chemical trade name product 'Zok 27" to remove airborne deposits from gas turbine compressor blades. The product is mixed with demineralized water to wash the blades and then followed by a longer period of rinsing with pure demineralized water only. The resultant waste is collected in a dedicated tank and shipped off site by an approved waste disposal  company.

MCW_Dest_Other_desc:
Waste disposal company hauls off-site and seperates the oil from the water.


Clean_desc:
The Plant performs a Heat Recovery Steam Generator (HRSG) Fire-Side wash approximately once a year on the two Unit 2 HRSGs, usually during an annual maintenance outage. Well water is used and the amount of cleaning waste generated was averaged from those washes performed from 2005 through 2009.  The waste water wash is collected in RCRA Permitted triple lined Surface Impoundments with leachate detection, collection and removal systems between each of the two top liners.  Sodium hydroxide is added to raise the pH and precipitate the metals to the bottom of the Surface Impoundments.  The supernatant is discharged per the Plant NPDES Permit to Discharge 002 in Monterey Bay.  The precipitated sludge at the bottom of the Impoundments is removed annually through a filter press with the filter cake transported to a Class I Landfill as Hazardous Waste due to metals.

MCW_Cmgld_Other_desc:
Units 6&7 Air Pre Heater, Stack and Boiler wash water and Unit 1 HRSG Washes.

MCW_Dest_Other_desc:
The precipitated sludge at the bottom of the Impoundments is removed annually through a filter press with the filter cake transported to a Class I Landfill as Hazardous Waste due to metals.


Clean_desc:
The Plant performs an On-Line distilled water wash of the two Unit 2 Gas Turbine compressors twice a day or once per each twelve hour shift.  Approximately 10 gallons for distilled water is used and there is no waste generated as the distilled water is vaporized into the gas turbine exhaust.

MCW_Dest_Other_desc:
Distilled water cleaning material is vaporized into the gas turbine exhaust.


Clean_desc:
Hydrochloric acid plus a foaming agent was used to remove calcium carbonate scale from the condenser tubes.  An added volume of treated water was used to rinse any residual from the tubes.

MCW_Dest_Other_desc:
Product was beneficially used to remove calcium carbonate scale from the bottom ash system at another power plant.


Clean_desc:
Raw water wash of the air pre-heater on Unit 3 to remove solid build up.


Clean_desc:
Cleaning chemical is added to boiler water and heated.  pH values are measured to determine cleaning reaction.  Additional chemical is added as needed.  When the cleaning is completed, the water is drained to trucks and burned in the boiler.  Rinse water is sent to the ponds and metals are precipitated out.


Clean_desc:
The unit uses ammoniated EDTA to remove iron oxide and copper deposits from steel tube surfaces of the boiler in a two stage process.  The first stage injects EDTA and a corrosion inhibitor to remove iron oxide deposits.  In the second stage, an anti-foam agent, ammonia and oxygen are added to the cleaning solution to increase the pH to 9.0 - 9.5 and decrease the bulk solution's ORP to -220mV to enable the removal of copper deposits. After completion of the copper stage an oxygen scavenger is added to enable the passivation of metal surfaces.


Clean_desc:
The unit uses a high pressure hose to spray filtered water to wash slag deposits from the external fireside of steel boiler tubes.


Clean_desc:
The plant contacts services for boiler tube cleaning. The cleaning method is based on sufficient quantities of chemicals for a two stage cleaning. First stage will be sodium bromated for copper removal followed up with a second stage of hydrochloric acid with thiourea and nitrogen rinse. Typically the cleaning waste is pumped to a zero discharge evaporation pond and hauled off in waste containment tanks to a disposal facility.

MCW_Dest_Other_desc:
Hauled off plant site or pumped to evaporation pond.


Clean_desc:
The plant uses Ammoniated EDTA in a two stage process to remove copper and iron deposits from the inside tube surfaces of the boiler.  The EDTA is added at a 10% concentration in the first stage for iron removal.  In the second stage the solution is cooled and compressed air is injected for the copper removal stage.


Clean_desc:
Boiler fireside cleaning activities are initiated 5 times per day.  Three times through a sootblowing system using steam as the cleaning medium, and 2 times using treated well water as the cleaning agent at operator selected locations within the boiler.  During both cleaning operations, the cleaning process is completed while the boiler is in operation; thus, leaving no identifiable cleaning waste products.


Clean_desc:
Air heater cleaning activities are initiated 12 times per day through a sootblowing system using steam as the cleaning medium.  During the cleaning process, the boiler is in operation and all cleaning products are dischargd back to the furnce leaving no identifiable cleaning waste products.


Clean_desc:
During major outages, the plant uses fire hoses to wash down the outside of the boiler.   Wash water comes off the fire header system which is supplied by cooling tower blowdown.  This wash procedure typically lasts for 24 hours.

MCW_Cmgld_Other_desc:
All sources of process wastewaters are commingled in wastewater treatment lagoons.


Clean_desc:
During major outages, the plant uses fire hoses to rinse off the outside of the boiler tubes and economizer.  In most areas, this involves opening the boiler access doors to point the fire hoses inside.  In some cases, scaffolding must be erected inside the boiler to reach the boiler tubes.  Wash water comes off the fire header system which is supplied by cooling tower blowdown.  This wash procedure typically lasts for 24 hours.


Clean_desc:
The plant uses cooling tower blowdown wash water to physically remove ash and deposits from the air heater.  The air heater is flooded/washed using internal spray equipment for 12 - 24 hours.


Clean_desc:
During major outages, the plant uses fire hoses to wash down the electrostatic precipiator.   Wash water comes off the fire header system which is supplied by cooling tower blowdown.  This wash procedure typically lasts for 24 to 36 hours.


Clean_desc:
The unit uses a high pressure hose to spray filtered water to wash slag deposits from the external fireside of steel steam generator tubes.


Clean_desc:
The contractor foams copper solvent over 4 hours at 180 degrees through the heater. This amount of solvent will dissolve about 600 pounds of copper, while the foam has the ability to carry out any loose sludge. The waste solution is drained to a storage tank and disposed of properly.

MCW_Dest_Other_desc:
Mixed with ash and disposed of in ash landfill.


Clean_desc:
The plant uses EDTA to remove copper deposits and iron oxides from the steel tube surfaces of the boiler in a two stage process.  In the first stage, the EDTA dissolves iron oxides.  In the second stage ammonium hydroxide is added to raise the cleaning solution between 9.0 and 10.0.  Oxygen gas is bubbled through the solution to dissolve copper deposits, and to provide a protective passivation layer on the boiler tube surfaces.


Clean_desc:
Major turbine components are dust blasted with Aluminum Oxide to remove scale.  Smaller parts exposed to oil are cleaned with Safety Clean solvent in self contained cleaning stations.

MCW_Dest_Other_desc:
Cleaning fluid is disposed thru licensed waste hauler.


Clean_desc:
The plant used filtered water to wash (high pressure, low volume) river/raw water scum build up out of the house service heat exchanger tubes.


Clean_desc:
The unit uses ammoniated EDTA to remove iron oxide deposits from steel tube surfaces of the steam generator in a two stage process.  The first stage injects EDTA, Formic Acid and a Corrosion Inhibitor at a pH of 4.5 - 5.5 to remove iron oxide deposits.  In the second stage ammonia and hydrazine are added to the cleaning solution to increase the pH to 10.0 and decrease the ORP to -250mV to enable the passivation of metal surfaces.

MCW_Cmgld_Other_desc:
Steam generator drains, air heater cleaning


Clean_desc:
For Unit 1 chemical cleaning, the chemical cleaning agent will be circulated through the boiler tubes from the lower header via the temporary piping to the upper water wall headers and to the economizer.  The cleaning agent is used to remove iron oxide, copper, and other metal deposits to clean the tubes.  The waste water is collected and pumped to the Metal Cleaning Waste Pond internal Outfall 102.

MCW_Dest_Other_desc:
Boiler tube cleaning waste is transferred to internal Outfall 102


Clean_desc:
Circulate and heat the system.  Inject fist stage copper removal using sodium bromate, ammonium bicarbonate, and aqua ammonia.  Soak and circulate.  Drain, Rinse-fill, circulate and drain. Fill, heat, drain, inject inhibitor, hydrochloric acid, and ammonium bifloride for iron removal.  Soak, circulate, and drain.  Fill, rinse circulate and drain. Fill, circulate, inject citric acid, heat, soak and circulate.  Drain, fill and heat and inject second stage copper removal.  Soak, circulate, and drain.  Rinse, fill, circulate, drain, fill, heat, and inject passivation chemicals.  Drain and neutralize each stage including passivation chemicals.


Clean_desc:
The unit utilizes temporary storage tanks (60000 gallons total) that are filled with potable city water to wash air heater internals to remove any particulate pluggage due to the incoming combustion air.  The water is circulated at high pressure through the tanks to the air heater until the procedure is complete.

MCW_Cmgld_Other_desc:
Steam generator drains, Steam generator tube chemical cleanings


MCW_Cmgld_Other_desc:
Steam generator drains, Air heater cleaning


MCW_Cmgld_Other_desc:
Steam generator drains, Steam generator tube chemical cleaning


Clean_desc:
The combustion and compressor portion of the turbine are cleaned with a low foam concentrate water based chemical, at approximately 1 part chemical to 4 parts water.  This cleaning helps to remove deposits commonly found on gas turbine compressor blades and help to increase the efficency of the turbine and can be performed both on line and off line. Additionally, motor foundations are cleaned of dirt and debris with a 1 part simple green to 10 parts water solution.

MCW_Dest_Other_desc:
The wastewater is directed to a closed sump and picked up by a liquid waste hauler for disposal.


Clean_desc:
Demineralized water is used under high pressure to remove corrosion product material located at the steam generator secondary side top of the tubesheet area. Water and debris is extracted by suction then filtered to remove sludge and repeated for each of 4 steam generators per unit.

MCW_Dest_Other_desc:
discharged to a pond that in turn discharges via 103 to receiving stream via outfall 101


Clean_desc:
Demineralized water is used under high pressure to remove corrosion product material located at the steam generator secondary side top of the tubesheet area. Water and debris is extracted by suction and filtered to remove sludge and repeated for each of four steam generators per unit.

MCW_Dest_Other_desc:
discharged to a pond which in turn discharges via 103 to receiving stream via outfall 101


Clean_desc:
The plant used a three step process to complete the Unit 4 HRSG initial cleaning.  All three steps were completed with the original solution.  The first step used sodium hydroxide in a 160 degree DI water to a pH around 13 for removal of oil and grease.  The second step used citric acid to adjust the pH to around 3.5 - 4.5 for the removal of iron scale.  The third step used soda ash to bring the pH to around 9 - 9.5 before adding sodium nitrite for passivation of the metal. The solution was drained to waste holding tanks along with 2-3 rinses of DI water.  The waste holding tanks were discharged to evaporation ponds after pH adjustment to 6.5 -8.5 with sulfuric acid.


seunit_id:
3, 4, 5 and FSV Units 5 & 6 (FSV Units 2,3,4,5&6)

Clean_desc:
The plant usesTurbotect 2020 Non-Ionic Surfactant to clean the compressor parts by hand washing.  The original solution consists of dilution of the neat product by 10-1, using approx. 1-2 gallons of the diluted product applied by hand and then a final rinse of approx. 1,000 gallons of demineralized water.


Clean_desc:
The plant uses ammoniated-EDTA to remove copper deposits and iron oxides from the internal tube surfaces of the boiler. The ammoniated-EDTA is diluted to a 10.0% solution and used for cleaning in a two stage process. In the first stage, the ammoniated-EDTA dissolves the iron oxides. In the second stage ammonia may be added to raise the pH of the cleaning solution to between 9.2 and 9.5 and oxygen is bubbled through the solution to dissolve copper deposits.


Clean_desc:
High Pressure Hoses use plant service water to wash slag and dirt out of the boiler.  The hoses are run for approximately eight hours.


Clean_desc:
Drained the system, rinsed the system, filled with condensate and dosde it with hydrazine and ammoniated EDTA(and inhibitor).  That recirculated , monitored the iron and copper, drained the system, rinsed it and passivated it with sodium nitrite. Ph was neutral

MCW_Dest_Other_desc:
transferred to a third party treatment works.  Non-hazardous


Clean_desc:
The plant used Oxy 200 (mixture of ammonium hydroxide, ammonium bicarbonate, and sodium bromate) to remove copper deposits and ammonium EDTA to remove iron oxides.


Clean_desc:
The plant uses Penetone 19, a water soluable surfactant, to remove dust particles from the rotating compressor blades in the combustion turbines. Twenty gallons of penetone is used with fifty gallons of demineralized water and sprayed into the running compressor. The temperature of compression evaporates any liquids and there are no discharges.


Clean_desc:
The plant utilizes Demineralized water to perform online Gas turbine compressor washes.  The water is sprayed into the compressor section.  No waste is generated; the waste stream is evaporated in the process.


Clean_desc:
The combustion turbine engine uses 4078 R-MC Engine cleaner, a non-hazardous cleaning agent based from the MSDS supplied by the manufacturer. The 100 gallon cleaner is mixed with 2500 gallons of raw water. It is injected into the inlet side of the combustion turbine compressor.

MCW_Dest_Other_desc:
the waste is collected into the primary collection tank then transferred to the oil/water separation then disposed to an injection well.


Clean_desc:
Preheater tubes of Heat Recovery Steam Generator were cleaned using soda ash, antifoaming agent, and corrosion inhibitor (alkaline solution) to remove ammonia salts and surface corrosion from the steel tube surfaces until the wash solution effluent is the same pH as the influent. The rinse solution containing anti foaming agent and corrosion inhibitor was then flushed down over the tubes to remove all residual wash solution. The final waste product was then neutralized using 32% hydrochloric acid.

MCW_Dest_Other_desc:
Discharged directly to Evaporation Ponds with NDEP Approval per email dated 4/26/07.


Clean_desc:
Sootblowers are used during daily operation of the plant to keep various tube sections clean. There is no liquid waste generated from this event as it is used in process.

MCW_Dest_Other_desc:
No waste generated as is it used in process.


Clean_desc:
The plant uses dry ice pellets and compressed air to clean the flue gas side of the boiler tubes annually during our maintenance outage.

MCW_Dest_Other_desc:
Dry ice pellets evaporate during cleaning; solid waste hauled to offsite landfill.


Clean_desc:
A. Circulation of 150-200F inhibited liquid sodium citrate solvent will be used to clean and passivate the harps. The chemical cleaning process consists of the following steps. 1. Water flushing to remove debris, particulates, etc. 2. Filling with water, circulating and heating to 200F. 3. Injection of caustic and surfactant and circulation of alkaline solution at 150-200F for 4 hrs. 4. Injection of citric acid and corrosion inhibitor and circulation until iron analyses show 4 consecutive results with no change greater than 0.02% as Fe. Circulate temperature is 150-200F. 5. Cooling of the circulating solution to 125-145F. During cooling, sodium carbonate solution will be injected into the HP Evaporator harp circulating solution, and ammonium hydroxide will be injected into the IP/LP SH 2 harp harp ciculating solution to raise pH to 9.5- 10.0. 6. Passivation is then accomplished by injecting sodium nitrite solution into the system and circulating for four hours. 7. The system is then drained to frac tanks, refilled with demineralized water, circulated for 15min and drained. The cycle will be repeated until conductivity of the circulating solution is within 25uS/cm of influent water conductivity.


Clean_desc:
For Unit 3 chemical cleaning, the chemical cleaning agent will be circulated through the boiler tubes from the lower header via the temporary piping to the upper water wall headers and to the economizer.  The cleaning agent is used to remove iron oxide, copper, and other metal deposits to clean the tubes.  The waste water is collected and pumped to the Metal Cleaning Waste Pond internal Outfall 102.


Clean_desc:
The plant uses about 10 gallons of ZOK 27, which is a proprietary Gas Turbine Compressor Cleaner, diluted with about 1000 gallons of demineralized water. This is then sprayed trough fixed nozzles to the inlet of the 17 stage compressor with the inlet guide vanes completely open. The plant only does offline water washes. All of the waste including the rinses are collected in a tank and sent offsite for disposal.


Clean_desc:
The plant hires subcontractors to use a copper solvent and diammonium EDTA with ammonia to remove copper oxides and iron deposits from the steel tube surfaces of the boiler.  This is done in a three step process.  The first step uses ammonium bicarbonate and ammonia to disolve the copper oxides, and oxygen to oxidize elemental copper to copper oxide.  This mixture is then drained from the boiler.  The second step uses a diammonium EDTA solution at 160 - 180 Deg. F at a pH of approximately 5 to remove any iron, calcium, magnesium, and zinc deposits.  The third step requires elevating the pH with anhydrous ammonia to 9.5 along with an oxygen spurge for further copper removal.  This mixture is then drained and the boiler is flushed.

MCW_Dest_Other_desc:
All cleaning waste is captured in frac tanks and removed from site by the subcontractor performing the work.


Clean_desc:
The plant mixes a 4 to 1 ratio of water to Compressor Wash (80 gal water to 20 gal compressor wash) prior to starting the compressor wash.  After insuring the turbine is on gear, the IGV's are opened and the turbine is over 700 RPM the compressor wash begins.  The compressor is washed at a rate of 6 gal/min until the operator runs out of water.  After a 30 minute soak, the turbine is then rinsed with 400 gal of RO water at a rate of 18 gal/min.  The residual water is evaporated during the drying phase.


Clean_desc:
Hydrochloric Acid was used at 5% to remove iron oxide deposits from the bioler tube suface.  Thiourea was added to remove copper oxide deposits from the boiler tube surface.  Thiourea was added so a single stage cleaning process could be achieved.


Clean_desc:
The plant used hydrochloric Acid to remove iron oxides from the steel tube surfaces of the boiler.  Next the plant used aqua ammonia and ammonium bicarbonate, along with sparging oxygen to remove copper deposits from steel tube surfaces of the boiler.  Then a boiler volume of treated water was used to rinse and nuetralize the boiler for the final stage.

MCW_Dest_Other_desc:
Transported to another power plant to be beneificially used as a pH adjustment in the bottom ash system.


Clean_desc:
The Plant performs a Heat Recovery Steam Generator (HRSG) Fire-Side wash approximately once a year on the two Unit 1 HRSGs, usually during an annual maintenance outage. Well water is used and the amount of cleaning waste generated was averaged from those washes performed from 2005 through 2009.  The waste water wash is collected in RCRA Permitted triple lined Surface Impoundments with leachate detection, collection and removal systems between each of the two top liners.  Sodium hydroxide is added to raise the pH and precipitate the metals to the bottom of the Surface Impoundments.  The supernatant is discharged per the Plant NPDES Permit to Discharge 002 in Monterey Bay.  The precipitated sludge at the bottom of the Impoundments is removed annually through a filter press with the filter cake transported to a Class I Landfill as Hazardous Waste due to metals.

MCW_Cmgld_Other_desc:
Units 6&7 Air Pre Heater, Stack and Boiler wash water and Unit 2 HRSG Washes.


Clean_desc:
The unit uses ammoniated EDTA to remove iron oxide and copper deposits from steel tube surfaces of the boiler.  The first stage injects EDTA and a corrosion inhibitor to remove iron oxide deposits.  In the second stage, anti-foam, ammonia and oxygen are added to the cleaning solution to increase the pH to 9.0 - 9.5 and decrease the bulk solution's ORP to -220mV to enable the removal of copper deposits.  Lastly, the unit is drained, refilled and hydrazine is injected to enable the passivation of metal surfaces.


Clean_desc:
The Plant performs an On-Line distilled water wash of the two Unit 1 Gas Turbine compressors twice a day or once per each twelve hour shift.  Approximately 10 gallons of distilled water is used and there is no waste generated as the distilled water is vaporized into the gas turbine exhaust.


Clean_desc:
The Plant uses Conntect 6000, a gas turbine compressor cleaner with detergents and surfactants suspended in water,  to clean the two Unit 2 gas turbine compressors and combustion chambers.  This process occurs approximately 8 times a years taking approximately 10 hours for each cleaning.  Approximately 2500 gallons of waste cleaning solution is generated from each cleaning and is trucked to the local POTW as Non-Hazardous waste.


Clean_desc:
The air preheater is cleaned using raw well water and collected for waste water processing.


Clean_desc:
The soot blower system is washed using raw well water and drained to the waste water treatment system.


Clean_desc:
The plant uses a high temperature EDTA process to remove iron oxide and copper deposits from the steel tube surfaces of the boiler.

MCW_Dest_Other_desc:
Only part of the waste was evaporated.  A portion was sent to a non-hazardous waste treatment facility


Clean_desc:
Gas turbine compressor section is washed using a compount called Conntect 7000S non foaming detergent.  The compound is diluted in purified water, 5 gallons soap to 20 gallons of water.  With the turbine spinning the mixture is injected into the compressor.  It vaporizes in the process so there is no actual liguid waste.  The compressor is then rinced while spinning using pure water.


Clean_desc:
The Plant uses well water to wash particulates from the Fireside Boiler Tubes as part of our Fallout Type Particulate (FTP) program.  The amount of cleaning waste generated was only from one wash in 2001. No other washes have been performed since then to the present.  The waste water wash is collected in RCRA Permitted triple lined Surface Impoundments with leachate detection, collection and removal systems between each of the two top liners.  Sodium hydroxide is added to raise the pH and precipitate the metals to the bottom of the Surface Impoundments.  The supernatant is discharged per the Plant NPDES Permit to Discharge 002 in Monterey Bay.  The precipitated sludge at the bottom of the Impoundments is removed annually through a filter press with the filter cake transported to a Class I Landfill as Hazardous Waste due to metals.

MCW_Cmgld_Other_desc:
Unit 7 Air Pre Heater, Stack and Boiler wash water and Units 1&2 HRSG Washes.


Clean_desc:
The plant uses a biodegradable detergent (active ingredient=<10% diethylene glycol monobutyl ether) up to two times a year on the compressor section of each combustion turbine.  Up to 8 gallons of detergent is used with approximately 125 gallons of water.  Any amount of waste water that does not immediately evapoate is discharged to a sump area where it is allowed to evaporate.


Clean_desc:
The Plant uses well water to wash particulates from the steel lined Stack and the Air PreHeaters as part of our Fallout Type Particulate (FTP) program.  The amount of cleaning waste generated was averaged from those washes performed from 2005 through 2008, no washes were performed in 2009.  The waste water wash is collected in RCRA Permitted triple lined Surface Impoundments with leachate detection, collection and removal systems between each of the two top liners.  Sodium hydroxide is added to raise the pH and precipitate the metals to the bottom of the Surface Impoundments.  The supernatant is discharged per the Plant NPDES Permit to Discharge 002 in Monterey Bay.  The precipitated sludge at the bottom of the Impoundments is removed annually through a filter press with the filter cake transported to a Class I Landfill as Hazardous Waste due to metals.


Clean_desc:
The Plant uses well water to wash particulates from the Fireside Boiler Tubes as part of our Fallout Type Particulate (FTP) program.  The amount of cleaning waste generated was from three washes in 2000, 2002 and 2005, with those three averaged for the amount per each wash in Section 2 Unit 7.  The waste water wash is collected in RCRA Permitted triple lined Surface Impoundments with leachate detection, collection and removal systems between each of the two top liners.  Sodium hydroxide is added to raise the pH and precipitate the metals to the bottom of the Surface Impoundments.  The supernatant is discharged per the Plant NPDES Permit to Discharge 002 in Monterey Bay.  The precipitated sludge at the bottom of the Impoundments is removed annually through a filter press with the filter cake transported to a Class I Landfill as Hazardous Waste due to metals.

MCW_Cmgld_Other_desc:
Unit 6 Air Pre Heater, Stack and Boiler wash water and Units 1&2 HRSG Washes.


seunit_id:
SE Unit-1, SE Unit-2, SE Unit-3, SE Unit-4


Clean_desc:
The plant uses EDTA to remove iron oxides and copper deposits from the steel tube surfaces of the boiler.  The 1% solution of EDTA is recirculated for 12-24 hours. In the first stage, EDTA dissolves the iron oxides.  In the second stage anhydrous ammonia is added to reaise the pH of the cleaning solution between 9 and 10 and O2 is bubbled through the solution to dissolve copper deposits.


Clean_desc:
A two step process is used. The first step is an acid cleaning of the internal water side of high pressure evaporator tubes to remove deposits and iron oxides. In the second step, a soda ash solution with a pH of 9 is used for a passivation layer on the tubes and remove any residual iron or hardness deposits


Clean_desc:
Cleaning the compressor section is performed to remove deposits on the blades. First, a water soap mixture is injected around the compressor and it is allowed to soak. Then the compressor is rinsed. Both soapy and rinse water are then pump to the master sump


Clean_desc:
Demineralized water is introduced to the front end of the gas turbine compressor for five minutes. The demineralized water removes deposits on the compressor. The demineralized water is evaporated in the cleaning process, therefore no waste water is generated.


Clean_desc:
Soot blowers use high pressure steam a cleaning medium and rotate a nozzle as the lance is inserted into the boiler.


Clean_desc:
Fly ash on the boiler internal surfaces in the convection pass is washed out with a firehose and service water through the economizer hoppers.


Clean_desc:
The plant uses a naptha-based cleaning solution to clean the first stages of the compressor when the unit is offline.  The cleaning solution is diluted 4:1 with demineralized water before using and is sprayed into the compressor.

MCW_Dest_Other_desc:
Cleaning waste is hauled off-site by waste management facility.


Clean_desc:
The plant uses demineralized water to clean the first stages of the compressor while the unit is online.  The water evaporates as it travels through the compressor and turbine sections of the unit.


Clean_desc:
A water wash skid supplies diluted nonionic surfactant with demineralized water to each gas turbine compressor during off-line water washes.  After the wash cycles, several rinse cycles are initiated with demineralized water only.


Clean_desc:
The plant uses EDTA (with inhibitor) to remove iron oxides from the internal boiler surfaces. pH is maintained at approx. 9.6 S.U.'s. After the iron oxides are removed, additional EDTA, antifoam, and sodium nitrite are injected to remove copper deposits. pH is maintained at approx. 9.5 S.U.'s. Upon completion, wash water is transferred to frac tanks, then shipped off-site to a properly licensed and approved treatment facility.

MCW_Dest_Other_desc:
Initial liquid waste (and 2 subsequent rinses) hauled off-site.


Clean_desc:
Scrub of fuel lines with Trisodium Phosphate.


Clean_desc:
The cleaning of compressor portion of combustion turbine is done with water and Contect mixture of an approximate 20:1, water to detergent ratio. This cleaning is done while the unit is offline. The station needs to perform this cleaning of the compressor approximately 4 times a year. The Offline Water Wash has 8 cycles at various rotor speeds ranging from 8 rpms to 648 rpms.

MCW_Dest_Other_desc:
Waste transported off-site in vac truck for disposal at an approved facility.


Clean_desc:
The steam turbine non-chemical cleaning operation occurs about every 10 years and cleans oxide dust that accumulates on the turbine.  The amount of oxide dust is very minimal and is roughly equivalent to 1/2 lb of iron/copper material.


Clean_desc:
The plant uses steam sootblowers to remove soot and ash from the fireside tube surfaces during boiler operation.


Clean_desc:
The plant uses service water to wash flyash and soot from the surfaces in the electrostatic precipitator.


Clean_desc:
The plant uses ammoniated EDTA to clean the internal boiler tube surfaces in a two-stage process.  The EDTA first chelates the metal oxides, then the pH is adjusted to the alkaline range.  Air and sodium nitrite are added to chelate the copper.


Clean_desc:
High Pressure Hoses use plant service water to wash slag and dirt out of the air heater.  The hoses are run for approximately eight hours.


Clean_desc:
SE Unit 2 uses raw plant intake water to rinse the outside of the boiler tubes to remove fouling.

MCW_Dest_Other_desc:
Disposed of offsite at a qualified treatment, storage and disposal facility.


Clean_desc:
SE Unit 2 uses pneumatic soot blowing to remove fouling on boiler tubes during boiler operations.


Clean_desc:
The plant uses ammonium bromate and hydrochloric acid solvent exposures to remove deposits/oxides from the tube surfaces of the boiler. The solvent exposures are followed by a soda ash boilout and rinse.


Clean_desc:
SE Unit 3 uses raw plant intake water to rinse the outside of the boiler tubes to remove fouling.


Clean_desc:
SE Unit 3 uses raw plant intake water to rinse the air preheaters to remove fouling.

MCW_Cmgld_Other_desc:
other metals cleaning wastewater for onsite treatment


Clean_desc:
SE Unit 3 uses pneumatic soot blowing to remove fouling on boiler tubes during boiler operations.


Clean_desc:
Stage 1 - Aqueous solution of EDTA at 30 degrees F to dissolve iron and copper oxides on boiler tubes. Stage 2 - EDTA and aqueous ammonia at 160 degrees F with injecttion of oxygen and sodium nitrate to remove copper. Stage 3 - passivation to remove all copper


Clean_desc:
Water from the ash recycle ponds is pumped through a piping system to a series of nozzles where water is sprayed onto the rotating air heater.  The water is collected in the air heater housing and returned by gravity to the ash recyle ponds for reuse.  Wastewater from cleaning the primary air heaters goes to WWT-4 via the Units 1 and 2 floor drains.  Wastewater from cleaning the secondary air heaters goes to the POND-1 treatment system. Surface is steel.

MCW_Cmgld_Other_desc:
GR, MRS, BFCW, clarifier sludge, FDW, FLTBW, IXW


Clean_desc:
During boiler outages, a partial cleaning of the boiler with raw plant intake water is performed with high pressure hoses.


Clean_desc:
A chelating agent, ammoniated ethylenediaminetetraacetate (EDTA), is used to remove deposits from the internal surfaces of the boiler tubes.  The boiler will be filled at normal operating levels and heated to approximately 290 degrees F.  The boiler will be drained a calculated amount and refilled with the EDTA.  Boiler circulating pumps and natural circulation will circulate the water and chemical throughout the boiler while taking fires in and out maintain temperature.  Samples are taken every 30 minutes for residual EDTA and to determine amounts of deposits such as Fe are being moved.  Once deposits are removed in the amounts we would expect, we drain the boiler with the chemical back to waste holding tanks for proper disposal.


Clean_desc:
SJRPP uses EDTA to remove iron oxides from the tubes, with a 1% residual above the calculated iron concentration to be removed. The solution is circulated at a temperature of 250- 300 deg F for 24 hours or until the iron concentration in solution  stabilizes. AdditionalEDTA maybe be added if the concentration in the boiler is depleted. Oxygen and air, along with a antifoaming agent, is then injected to passivate the tube surfaces.  After the passivation phase the boiler is drained/rinsed to 8.5 pH/ 50 mmho.

MCW_Dest_Other_desc:
Initial boiler drain transported off site to TSDF-110,000 gallons


MCW_Dest_Other_desc:
Initial boiler drain and 1st & 2nd rinses transported off site to TSDF-173,174 gallons


Clean_desc:
Service water is used to remove ash from the air heater blades. This procedure is completed during a unit outage


Clean_desc:
Steam is blown onto the fireside of the boiler tubes to remove slag and ash that maybe adhereing to the tubes


Operation_ID:
Unit 2 Generator Stator Cooling System Chemical Cleaning

Clean_desc:
85% phosphoric acid is used to remove deposits within the generator stator cooling water system.


Clean_desc:
A high pressure pumper is used to pump ash recycle water to a series of nozzles where water is sprayed onto the rotating air heater.  The water is collected in the air heater housing and returned by gravity to the ash recyle ponds for reuse. Surface is steel.


Clean_desc:
The Station uses diammonium EDTA to remove iron oxide deposits from the internal steel tube surfaces of the boilers. The diammonium EDTA has a pH in the range of 4.5 to 5.5. The cleaning is performed in two stages. During the first stage, the diammonium EDTA removes the iron oxide deposits. During the second stage the pH is raised to about 9.2 with 29% ammonium hydroxide and oxygen is bubbled through the solution to passivate the cleaned tube surfaces. Surface is steel.

MCW_Dest_Other_desc:
Hazardous waste (HW) is generated. The HW portion of the waste is shipped to an approved HW treatment facility. The residual waste (RW), the rinses, are evaporated in one of the other two operating units.


Clean_desc:
The Station uses tetra-ammonium EDTA to remove iron oxide deposits from the internal steel tube surfaces of the boilers. The tetra-ammonium EDTA has a pH range of 9.0-9.5. The cleaning is performed in three stages. During the first stage the tetra-ammonium EDTA removes the iron oxide deposit. During the second stage, antifoam is add and oxygen is bubbled through the solution to dissolve any copper deposits. The third stage consists of adding 19% ammonium hydroxid to the water being used in the two subsequent boiler rinses to minimize corrosion. Surface is steel.


Clean_desc:
The plant uses compressed air to blow soot from the fire-side of the furnance walls formed by the steel boiler tubes.  No wastewaters are generated.  The soot is removed from the flue gas stream with the flyash in the electrostatic precipitator.  Surface is steel.

MCW_Dest_Other_desc:
Collected with fly ash in precipitator hoppers


Clean_desc:
The plant uses compressed air to blow soot from the fire-side of the furnance walls formed by the steel boiler tubes.  No wastewaters are generated.  The soot is removed from the flue gas stream with the flyash in the electrostatic precipitator.

MCW_Dest_Other_desc:
Collected with flyash in precipitator hoppers


Clean_desc:
The plant uses Conntect 7000 or Conntect 5000 to remove the accumulation of deposits on the compressor air foils and gas path surfaces.  The fouling is typically the result of airborne particles such as dirt, dust, pollens, oils and/or unburned hydrocarbons, etc.  The plant uses an off-line washing method where the solution is applied at crank speed for three to five minutes, allwed to soak for 20 minutes, then rinsed with demineralized water at crank speed for an additional 20 minutes.


Clean_desc:
A mixture of demineralized water and detergent (Conntect ® 6000) is used to remove dry contaminants (dirt, dust, insects) and hydrocarbon fumes from the compressor portion of the gas turbines.  The pH of the demin water is between 5.0 and 6.0 and the detergent is mixed as needed (typical amount, approximately 20 gallons).  The solution is mixed for 1 hour then applied to the turbine which is allowed to soaked for 30-60 minutes.  Afterward the turbine is rinsed thoroughly as needed.  The wash water is drained into a holding tank and removed from the site by Shamrock Environmental Corporation.

MCW_Dest_Other_desc:
Hauled off site by Shamrock Environmental Corporation


Clean_desc:
The plant uses Conntect Gas Turbine Compressor Cleaner to remove deposits that accumulate on the compressor blades.  The cleaner is comprised of detergents and surfactants suspended in water with no hazardous ingredients.  The cleaner is diluted with 4 parts demineralized water to one part cleaner to produce a soap solution.  The cleaning operation involves repetitive sequences of soap solution injection and demineralized water rinsing.  The deposits are primarily dust or dirt and pollen.

MCW_Dest_Other_desc:
Collected in onsite water wash tanks and hauled offsite for proper disposal


Clean_desc:
The plant uses brine, sodium hydroxide and muriatic acid solutions to remove deposits from the Process Water Treatment facility electro-deionization unit (EDI).  The EDI in combination with an upstream reverse osmosis unit produces demineralized water from filtered well water and recycled/filtered process water.  The EDI is soaked in cleaning solution and rinsed with demineralized water.

MCW_Dest_Other_desc:
Collected in portable totes and hauled offsite for proper disposal


Clean_desc:
Inhibited EDTA is the basis for the alkaline copper removal process used for the removal of iron oxide and copper deposits from utility boilers in a two stage process. The first stage is initiated as a boiler is coming off line by injecting chemicals into the steam drum. The solvent reacts with iron and copper deposits forming soluble chelates. The copper chelate formed is not stable and copper is rediposited as elemental copper. In the second stage, the solvent temperature is lowered and an oxidant is added to the solvent to oxidize ferrous chelate to the ferric condition. The ferric chelate oxidizes the elemental copper which is solubilized and chelated. At the same time, a protective oxide coating is formed on the boiler metal surfaces. The solvent is drained and the unit is flushed with water.


Clean_desc:
The Waterford 3 plant performed a chemical cleaning of the two steam generators in October of 2000. The plant employed a process to remove iron oxides and copper deposits from the inconel steam generator tube material. The iron removal step was done at ~325 degrees F, using multiple EDTA injections. The pH was maintained between 7.0 and 8.6. Following the iron removal step, the steam generators were drained and dryed. EDA was then injected and sparged with air for the copper removal process while the pH was maintained between 10.2 and 10.4. A series of full volume rinses were performed after draining the copper solvent from the steam generators. The waste from the cleaning was concentrated using a four-pass forced circulation evaporator. the distillate from the evaporator was treated as necessary to meet release limits for the plant outfall. The concentrate was shipped off-site for final processing and disposal.


Clean_desc:
The plant contacts services for boiler tube cleaning. The cleaning method is based on sufficient quantities of chemicals for a two stage cleaning. First stage will be sodium bromated for copper removal followed up with a second stage of hydrochloric acid with thiourea and nitrogen rinse. Typically the cleaning waste is pumped to a zero discharge evaporation pond and hauled off in  waste containment tanks to a disposal facility.


Clean_desc:
The plant contacts services for boiler tube cleaning. The cleaning method is based on sufficient quantities of chemicals for a two stage cleaning. First stage will be sodium bromated for copper removal followed up with a second stage of hydrochloric acid with thiourea and nitrogen rinse. Typically the cleaning waste is pumped to a zero discharge evaporation  pond  and hauled off in  waste containment tanks to a disposal facility.


Clean_desc:
Southaven uses conntect 6000, a water based combustion turbine detergent to clean the gas turbine compressor blades on an annual basis.  The detergent is mixed with demineralized water produced in the plant.  The water and detergent mixture is sprayed into the gas turbine while the unit is off line and allowed to soak on the blades.  It is then rinsed off and all of this process water is collected in an underground sump.  This process water is non-hazardous and is tested for copper as required in the MS pretreatment permit MSP091679.


Clean_desc:
A second steam generator chemical cleaning was performed at Waterford 3 in October, 2003. This cleaning was a low temperature process to remove residual iron and copper from the 2000 chemical cleaning.  The iron removal step was done at ~190 degrees F, using multiple EDTA injections. The pH was maintained between 7.00 and 7.83. Following the iron removal step, the steam generators were drained and dryed. EDA was  injected for the copper removal process while the pH was maintained between 9.45 and 10.40. A series of full volume rinses were performed after draining the copper solvent from the steam generators. The waste from the cleaning was concentrated using a four-pass forced circulation evaporator. the distillate from the evaporator was treated as necessary to meet release limits for the plant outfall. The concentrate was shipped off-site for final processing and disposal.


Clean_desc:
Inlet air to the combustion turbine compressor goes through inlet filters to remove dirt, dust, and other contaminants.  Some contaminants pass through the filters and deposit on the compressor blades.  The plant periodically uses a water-detergent solution to wash these contaiminants from the compressor blades.  During the washing operation, demineralized water and detergent is premixed to the proper ratio, and delivered through piping to the gas turbine at the proper  temperature, pressure, and flow rate.  The equipment used to mix and inject the cleaning solution is provided by the turbine manufacturer, and consists of a water tank, detergent tank, piping, valves, and instrumentation.

MCW_Cmgld_Other_desc:
CTG Inlet Evaporative Cooler Blowdown, Boiler Blowdown, Misc. Plant Drains

MCW_Onsite_TS_Other_desc:
Zero Liquid Discharge Wastewater Treatment Process


Clean_desc:
The plant uses a three phase process to remove copper deposits and iron oxides from the steel tube surfaces of the boiler. The first phase consists of an ammonium persulfate solution to remove copper deposition. In the second phase, tetra-ammoniated EDTA is added to chelate the iron oxides. When this phase is complete, the third phase consists of blowing oxygen through the cleaning solution to remove copper oxides.


Clean_desc:
The plant uses a once through cleaning process to remove copper deposits from the high pressure turbine blades surfaces. Ammonium carbonate is foamed through the high pressure section of the turbine to remove copper oxides. After passing through the high pressure turbine, the foam is broken into a liquid and collected. Oxygen gas is also added to ammonium carbonate foam at regular intervals throughout the process to convert any metallic copper to copper oxides.


Clean_desc:
The plant uses service water (treated intake water) to wash the boiler tube walls on the fireside of the boiler during outages.  This type of wash helps reduce the arsenic level in the air to a level that is safe for maintenance personnel to work inside the boiler.  Washing the fireside of the boiler also cleans any additional slag or fly ash build-up allowing for maintenance work to be performed more efficiently.


Clean_desc:
The plant uses service water (treated intake water) to wash the air heater during outages.  This type of wash is to remove any type of pluggage in the air heater to increase air flow once the unit is returned to service after the outage.


Clean_desc:
SE Unit 1 uses pneumatic soot blowing to remove fouling on boiler tubes during boiler operations.


Clean_desc:
The plant used a chelant (ammoniated EDTA) to remove metal deposits (mostly iron) from the interior surfaces of the boiler tubes from each of the two Heat Recovery Steam Generators (HRSGs).  Approximately 36000 gallons of 10% EDTA solution was used to clean each HRSG. This solution was recirculated for approximately 21 hours at elevated temperatures.  During the second stage, ammonium hydroxide was used to raise the pH of the cleaning solution to 9.2.  The spent cleaning solution was then drained to a series of frac tanks. A series of 2-3 rinses followed, which were also drained to the frac tanks.  The spent solution, co-mingled with the rinse water, was then discharged to an on-site zero-discharge 1200 acre cooling pond.  Each HRSG was cleaned, rinsed and discharged in series to the zero surface discharge cooling pond.

MCW_Dest_Recyc_desc:
discharge to closed-cycle cooling water system which is a zero-discharge 1200 acre cooling pond


Clean_desc:
The plant uses a sufactant detergent (Contect 6000) solution to clean both the combustion and compressor sections.  The detergent is mixed with treated service water to make a 20% solution.  Approximately 500 gallons of this solution are used to wash each section followed by an equal amount of clean rinse water generating 1000 gallons per section total wastewater.  This wastewater is collected in drain tanks from which the wastewater is removed and disposed off-site as non-hazardous liquid waste per RCRA requirements.


Clean_desc:
A contracting firm is brought on site.  A plan is devised and safety and procedures are reviewed.  The gears for the preheater are disconnected.  The contractor synchronizes his power washer with the pattern of the preheater rotation and high pressure water is used to blast off material.  The water is collected and sent to the treatment ponds to settle.


Clean_desc:
A contracting firm is brought on site and a plan is devised.  Safety and procedures are reviewed.  Ammoniated EDTA is dulted into the boiler (approx 15000 gallons) to a concentration of 4-5% and recirculated.  The EDTA solution is circulated by pumping and or air blowing.  The waste solvent and rinse is drained to frac tanks, and analyzed to determine if it is hazardous.  Request for approval to evaporate the waste is made to the state and evaporation is performed according to the criteria establised by the state following approval.


Clean_desc:
Westar Employees review safety and procedures.  The ID fans are power washed with plant water.  The water is collected and sent to the treatment ponds.


Clean_desc:
A contracting firm is brought on site and a plan is devised.  Safety and procedures are reviewed.  Citric acid is dulted into the boiler (approx 15000 gallons) to a concentration of 4-5% and recirculated.  A pH is maintained by adding acid and the treatment is done when the pH is maintained with no chemical addiction.  The waste solvent and rinse is drained to frac tanks and analyzed to verify that it is not hazardous.  Request for approval to evaporate the waste is made to the state and evaporation is performed according to the criteria established by the state following approval.


Clean_desc:
Compressor washing is performed on combustion turbines using a detergent and demineralized water.  The washing procedure requires cranking the combustion turbine while adding detergent mixed in water and then allowing a soak interval.  The compressor is then cranked and rinsed until the pH of the effluent is neutral.  All washing waste is collected in a tank to be hauled off for outside disposal.


Clean_desc:
SEU-1 uses ZOK MX at 15 gallons to 85 gallons of demineralized water to clean six aero-derivative gas turbines and 15 gallons of ZOK MX to 80 gallons of demineralized water to clean one industrial gas turbine.  The mixture is injected into the gas turbine and allowed to soak for 15 minutes.  Each aero-derivative turbine is then rinsed seven times with 100 gallons of demin water per rinse.  The industrial gas turbine in rinsed coninuously with 20 gallons per minute of demin water for 45 minutes (900 gallons).  Compressor washes remove only soft materials as composite sample taken at plant combined POTW outfall shows no evidence of elevated metal levels during wash events.


Clean_desc:
Steam turbine condensers have historically been cleaned every other year but will be cleaned every year starting in 2011.  Condenser steam sides are not cleaned, water sides only.  There are two condensers each with 5000 stainless steel tubes that are cleaned by shooting soft plastic plugs through each tube with approximately one gallon of pressurized water creating approximately 10000 gallons of waste water that contains algae-like, soft biological material.  No metal waste is created as evidenced by no elevated metals at POTW outfall sample point.


Clean_desc:
The unit is alignied while not operating under load for a cleaning evolution to remove impurities ingested into the unit to improve overall efficiency. The plant uses demineralized city water co-mingled with the cleaning solution (vacume injected to the water stream at a 3-5 GPM rate) to "soap up" the unit while it is turning at relatively low (crank) speed. Once unit wastwater shows signs of "suds" the unit is stopped and allowed to coast down to zero revolutions and the unit is soaked with the cleaning solution/demin water mix for a 20 -30 min soak period while slowly ratcheting. Afterwards, the unit is then brought back to crank speed and then demineralized water is used to rinse the unit. This continues until the rinse water effluent is within a specified conductivity tolerance (about 5 mumho's) wherafter the water injection is secured and the unit continues to turn at crank speed until the waste drains are dry. The unit is then re-aligned and fire dried.


Clean_desc:
The cleaning of compressor portion of combustion turbine is done using demineralized water only. This Offline Water Wash is done once a day for a period of 5 minutes, while the ambient temperature is above 50 degs F.


Clean_desc:
Internal flush of boiler tubes after tube leak repair(s) to remove impurities. Demineralized water is used for the rinse.


Clean_desc:
The plant performed chemical cleaning of carbon steel steam generators to remove magnetite deposits on the tube support plates.  The two-step cleaning process consisted of 1.) Iron removal step for bulk deposit removal and 2.) Passivation step to form a thin, protective layer of magnetitie on all carbon steel surfaces and minimize flash rusting during subsequent steam generator maintenance activities.  In the first step, EDTA, hydrazine, CCI-801 and ammonium hydroxide are used to dissolve the bulk deposits.  In the second step, the pH is raised to between 9.5 and 10.5 to produce a thin protective magnetite layer on the system surface.

MCW_Dest_Other_desc:
Processed for volume reduction using a four-pass forced-circulation evaporator to produce a concentrated solution and a distillate.  The distillate was discharged to a Settling Pond and discharged through NPDES Outfall 602/001  The concentrated solution was shipped off-site to a waste treatment facility for further treatment and subsequent shipment for disposal.


Clean_desc:
The plant performs high pressure power washing of Service Water Heat Exchangers Tubes and System Piping using demineralized water to remove silt/sediment.


Clean_desc:
Fire water (river water) was used to rinse the boiler tubes prior to maintenance on the boiler. Rinse water was collected and routed to metals ponds


Clean_desc:
The unit uses ammoniated EDTA to remove iron oxide and copper deposits from steel tube surfaces of the boiler in a two stage process.  The first stage injects EDTA and a corrosion inhibitor to remove iron oxide deposits.  In the second stage, ammonia and oxygen are added to the cleaning solution to increase the pH to 9.2 - 9.5 and decrease the bulk solution's ORP to -220mV to enable the removal of copper deposits. After completion of the copper stage an oxygen scavenger is added to enable the passivation of metal surfaces.


Clean_desc:
The unit uses high pressure hoses to spray filtered water to wash slag deposits from the external fireside of steel boiler tubes.

MCW_Cmgld_Other_desc:
Unit 1 Turbine room sump, Unit 2 Wastewater sump


Clean_desc:
Vinegar is used to clean various FGD equipment, mainly pump parts, grit screens, and atomizers. The cleaned equipment is rinsed with service water.


Clean_desc:
The unit uses high pressure hoses with filtered water to wash off flyash and deposit pluggage from the air heater internals. The unit has 2 air heaters and each are cleaned during each cleaning event.


Clean_desc:
The unit uses ammoniated EDTA to remove iron corrosion product deposits from steel steam generator tube surfaces in a two stage process.  In the first stage, EDTA and an inhibitor are used to dissolve iron deposits and then discharged to a metal cleaning waste tank.  In the second stage, in order to passivate steel tube surfaces, the steam generator is refilled with demineralized water, ammonia is added to raise the pH to 9.0 - 9.5 and an oxygen scavenger is added to act as a reducing agent.

MCW_Dest_Other_desc:
All waste is captured in a metal cleaning waste tank and solid by-products are allowed to settle out over time.  Once analysis confims the liquid waste portion is non-hazardous it is transferred to a settling pond where it commingles with other process wastewaters.  The remaining waste containing the solid by-products is then hauled offsite for disposal.


Clean_desc:
Unit uses steam soot blowers to maintain thermal efficiency.  Process is consistent on a daily basis when unit is operating.  Steam evaporates and no liquid waste is generated.  Small amounts of solids are produced.


Clean_desc:
Unit utilizes a single water lance rated at 33 gallons per minute to maintain thermal efficiency.  Steam evaporates and no liquid waste is generated.  Small amounts of solids are produced.


Clean_desc:
Boswell Unit 1 Boiler waterside deposits are chemically cleaned with a five stage process.  Each stage is approximately 20,000 gallons.  Stage one is a HCl Acid wash at 7% HCl.  Stage two is a demineralized water rinse.  Stage three is Citric Acid wash at 0.1% Citric Acid.  Stage four is a passivation wash with Sodium Carbonate at 1% and Hydrazine at 200ppm.  The stage five process removes all metal deposits, most of which are iron.

MCW_Dest_Other_desc:
Stage One sludge sent to Seimens Inc. for treatment.


Clean_desc:
High pressure water is introduced into the Boswell Unit 1 air heaters.  Fly ash residuals are washed out and piped to SPD-1


Clean_desc:
Boswell Unit 2 Boiler waterside deposits are chemically cleaned with a five stage process.  Each stage is approximately 20,000 gallons.  Stage one is a HCl Acid wash at 7% HCl.  Stage two is a demineralized water rinse.  Stage three is Citric Acid wash at 0.1% Citric Acid.  Stage four is a passivation wash with Sodium Carbonate at 1% and Hydrazine at 200ppm.  The stage five process removes all metal deposits, most of which are iron.

MCW_Dest_Other_desc:
Stage one sludge sent to Seimens Inc. for treatment.


Clean_desc:
High pressure water is introduced into the Boswell Unit 2 air heaters.  Fly ash residuals are washed out and piped to SPD-1.


Clean_desc:
Boswell Unit 3 Boiler water-side tube deposits are chemically cleaned with an eight stage process.  The 1st stage is an Ammonia Bromate wash for copper removal.  Stage two is a demineralized water rinse.  Stage three is a HCl wash for iron and general element removal.  Stage four is a demineralized water rinse.  Stage five is a Citric Acid rinse.  Stage six is a passivation stage with Sodium Carbonate (1%) and Hydrazine (300ppm).  Stages seven and eight are demineralized water rinses.


Clean_desc:
High pressure water is introduced into the Boswell Unit 3 air heaters.  Fly ash residuals are washed out and piped to SPD-1.


Clean_desc:
Boswell Unit 4 Boiler water-side tube deposits are chemically cleaned with a six stage process.  Each stage is 70,000 to 80,000 gallons.  The first stage is a HCl wash at 6%.  Stage two is a demineralized water rinse.  The third stage is a Citric Acid(0.1 %) rinse.  Stage four is passivation with Sodium Carbonate (1%) and hydrazine (300ppm).  Stage 5 and 6 are demineralized water rinses.  This process removes all metal deposits, most of which are iron.


MCW_Dest_Other_desc:
Steam evaporated in the boiler; soot is collected as fly ash


Clean_desc:
The plant used EDTA, surfactants, anti-foamers, and oxygen gas to remove copper deposits and iron oxides from the boiler tube inner surfaces.  The chemicals are added in two stages.


Clean_desc:
The boiler cyclones are water-blasted to clean off slag and loose refractory.


Clean_desc:
Soot blowers use boiler steam to clean tubes and pendants.  The soot blowing cycle is run three times per day.


Clean_desc:
The plant uses ammoniated EDTA to remove iron oxides from the steel tube surfaces of the boiler.  The ammoniated EDTA is diluted to approximately 5% by volume and then used for cleaning in a two-stage process.  In the first stage, the EDTA dissolves iron oxides.  In the second stage, oxygen is bubbled through the solution to dissolve copper deposits.


Clean_desc:
The plant uses formic acid to remove iron oxides from the steel tube surfaces of the boiler.  Ammonium bifluoride (ABF) is added to
facilitate the cleaning process.  A corrosion inhibitor is added to inhibit corrosion of the base tube material via the acid solution.  Afterwards, the boiler is neutralized and passivated with ammonia and hydrazine


Clean_desc:
The plant uses raw river water to wash the air pre-heaters.  These heaters are normally washed twice each year.

MCW_Cmgld_Other_desc:
plant blowdown, regeneration waste, boiler drains, coal pile run-off


Clean_desc:
The plant uses compressed air to remove ash from the external boiler tube surfaces and from the boiler internals.  The removed ash is commingled with either bottom ash  and falls into an ash pit or flyash and is carried to precipitator hoppers.


Clean_desc:
The plant uses compressed air to remove ash from the external boiler tube surfaces and from the boiler internals.  The removed ash is commingled with either (1) bottom ash  and falls into an ash pit or (2)  flyash and is carried to precipitator hoppers.


Clean_desc:
The plant hires contractors to sandblast pertinent rotating and stationary turbine components.

MCW_Dest_Other_desc:
The solid waste is drummed and taken to an off-site (non-SCE&G) landfill.


Clean_desc:
The plant uses a sandblasting material to clean rotating and non-rotating steam turbine parts.

MCW_Dest_Other_desc:
Vendor trucks the solid material off site (non-SCE&G) for disposal.


Clean_desc:
Untreated plant intake water is pressurized and used to remove buildup of ash on plates and electrodes on the inside of the precipitators, and occasionaly to remove excessive buildup of ash.  Hot-side precipitators require a water wash  for maintenance.


Clean_desc:
In 2009, the plant used a 2-Stage Chemical Cleaning Process consist of a 1st Stage Cleaning Step using a combination of Aqueous Ammonia (Amm), Sodium Bromate (NaBr), & Ammonium BiCarbonate (ABC) to remove copper deposits.  The 2nd Stage Cleaning Step consisted of a combination of thiourea, ABF, & hydrochloric acid to remove any remaining copper deposits and the iron oxides from the internal steel surfaces of the boiler tubes (66,700 gallons Cleaning Volume).  All boiler waste & water rinses were drained to the ash pond.


Clean_desc:
In 2005, a Single-Stage Chemical Cleaning Process consisting of a combination of Aqueous Ammonia (Amm), & Ammonium BiCarbonate (ABC), and hydrogen peroxide (H2O2) to remove copper deposits.  The chemicals were injected into the HP turbine as a foam. All drains were collected in a temporary storage tank.

MCW_Dest_Other_desc:
Turbine cleaning waste solution was blended into boiler cleaning waste drain steps.


Clean_desc:
High pressure wash the boiler water wall using city water.  All waste collected in ash hopper and then routed to ash pond.


Clean_desc:
Fire water was used to wash the electrostatic precipitator.  The waste material was drained to the cinder pit and to the ash pond.


Clean_desc:
Air Heaters are power washed with city water. Water goes to drain, to sump, and then to POND-1/ SPD-1.


Clean_desc:
Air Heaters are blown with steam from boilers. No wastewater is generated. Steam evaporates during cleaning process.


Clean_desc:
Sootblowing uses air from air compressors to remove soot, slag, and flyash from the tube surfaces.  No wastewater is generated.

MCW_Dest_Other_desc:
Ash from sootblowing combines with the other ash streams.


Clean_desc:
High pressure water is introduced into the Boswell Unit 4 air heaters.  Fly ash residuals are washed out and piped to SPD-1.


Clean_desc:
The unit uses ammoniated EDTA to remove iron oxide and copper deposits from steel tube surfaces of the boiler in a two stage process.  The first stage injects EDTA and a corrosion inhibitor to remove iron oxide deposits.  In the second stage, ammonia and oxygen are added to the cleaning solution to increase the pH to 9.0 - 9.5 and decrease the bulk solution's ORP to -220mV to enable the removal of copper deposits.  See comments page for description of waste handling procedures.


MCW_Dest_Other_desc:
After testing to determine non-hazardous, the cleaning waste is mixed with air heater wash water and used for hydration of ash and dust control within the permitted ash landfill.


Clean_desc:
The backpass of the fire side of the boiler is washed down with well water to remove fly ash and economizer ash prior to maintenance activities.  This is normally done at the start of major unit outages. This work is normally done just before the start of the air heater wash and the water is placed in the same basin where the air heater wash water will be collected.  This water is then used for hydration and dust control within the ash landfill.

MCW_Dest_Other_desc:
The water in the air heater wash pond is used for hydration of ash being disposed in the landfill and also for dust control spray water in the ash landfill.


Clean_desc:
The air heater plugs with ash over time during operation. The air heater wheels are individually cleaned by spraying high pressure water through the wheel from top to bottom to remove the hardened ash imbedded in the wheel.

MCW_Dest_Other_desc:
The water in the air heater wash pond is also used for hydration and dust control spray water in the ash landfill.


Clean_desc:
Potable service water is used via fire hose to water wash ash from the convection side of the boiler (back-pass).  Water is collected in the economizer ash hopper and discharged to the bottom ash pond via normal sluicing.


Clean_desc:
Bottom ash sluice water is pumped into existing piping within the air heater and floods the air heater with water to remove accumulated fly ash.  Drains on the bottom of the air heater divert the water to the main drain line to the bottom ash pond.


Clean_desc:
Vinegar is used to clean various scrubber equipment, mainly cleaning pump parts, screens, and atomizers.  The cleaned equipment is rinsed with service water.  The wastewater is sent to WWT-1.  An estimated 500 gallons of vinegar is used per year.


Clean_desc:
Sootblowing within the boiler and airheater uses either steam or water to remove soot, slag, and flyash from the tube surfaces.  All water evaporates; no wastewater is generated.


Clean_desc:
In 2010,the plant used a Two-Stage Chemical Cleaning Process using diammonium ethylene-diamine tetraacetic acid (EDTA) to remove copper deposits and iron oxides internal deposits on the steel tube surfaces of the boiler (41,500 gallons-center drum).  In the 1st Stage, the EDTA dissolves iron oxides.  In the 2nd Stage, the cleaning solution pH is raised between 9 and 10 by adding amm and oxygen is bubbled through the solution to dissolve copper deposits.  The cleaning solution was drained and the boiler rinsed twice with water.  All boiler drains from this process were collected in temporary storage tanks


Clean_desc:
In 2008, the plant used a Two-Stage Chemical Cleaning process using diammonium ethylene-diamine tetraacetic acid (EDTA) to remove copper deposits and iron oxides internal deposits on the steel tube surfaces of the boiler (35,305 gallons Cleaning Volume).  In the 1st Stage, EDTA dissolves iron oxides.  In the 2nd Stage, the cleaning solution pH is raised between 9 and 10 by adding amm and hydrogen peroxide to the solution to dissolve copper deposits.  The cleaning solution was drained and the boiler rinsed twice with water.  All boiler drains from this process were collected in temporary storage tanks

MCW_Dest_Other_desc:
Boiler Waste was collected in temporary storage (frac tanks).  All boiler waste & 2 rinses were hauled off-site.


Clean_desc:
In 2009, the plant used a Two-Stage Chemical Cleaning process using diammonium ethylene-diamine tetraacetic acid (EDTA) to remove copper deposits and iron oxides internal deposits on the steel tube surfaces of the boiler (35,305 gallons Cleaning Volume).  In 1st Stage, EDTA dissolves iron oxides.  In the 2nd Stage, the cleaning solution pH was raised between 9 and 10 by adding amm and oxygen is bubbled through the solution to dissolve copper.  The cleaning solution was drained and the boiler rinsed twice with water.  All boiler drains from this process were collected in temporary storage tanks

MCW_Dest_Other_desc:
Boiler Waste was collected in temporary storage (frac tanks) prior to being hauled off-site for disposal.


Clean_desc:
The plant uses house service water to assist in the removal of boiler slag.  The water is evaporated during the process.


Clean_desc:
In 2003, the plant used a Single-Stage Chemical Cleaning Process which consisted of a combination of thiourea, ABF, & hydrochloric acid to remove copper deposits and iron oxides from the internal steel surfaces of the boiler tubes (20,400 gallons Cleaning Volume).  All boiler waste and water rinses were drained to the ash pond

MCW_Onsite_TS_Other_desc:
Boiling Cleaning waste was retained within ash pond for 5+ days before discharge

MCW_Dest_Other_desc:
Boiler cleaning waste is retained within ash pond for 5+ days before discharge.  Cleaning chemicals, boiler solids & metals react with flyash & settle out in ash pond.  Co-mingled water leaves ash pond in normal pond effluent


Clean_desc:
In 2010, a Two-Stage Chemical Process consisting of a 1st Stage combination of Hydroxyacetic/Formic/Amm BiFluoride to dissolved iron deposits and a 2nd Stage combination of Aqueous Ammonia (Amm), & Ammonium BiCarbonate (ABC), and Oxygen to remove copper deposits.  The chemicals were injected into the HP turbine as a foam.  All drains were collected in a temporary storage tank.

MCW_Dest_Other_desc:
Turbine cleaning waste solution was neutralized with NaOH, then drained to ash pond.


Clean_desc:
Cleaning process uses citric acid to remove iron oxide deposits from the boiler tubes.  Corrosion inhibitor is added for protection of the base metal.  After the iron is removed from the surfaces, the solvent is slightly cooled,  aqueous ammonia added to raise the pH to 9-10 and air sparged through the boiler for removal of any copper deposits. Sodium Nitrite is used to passivate after cleaning.


Clean_desc:
Condenser cleaning consist of aerating a  5% solution of inhibited hydrochloric acid to make a foam and the foam is pumped into the condenser outlet water boxes.  A solution of soda ash is flushed through the condenser to neutralize the acid and the waste is collected in frac tanks.  Caustic used for the final neutralization and the neutral solution is sprayed on the coal yard to control dust.


Clean_desc:
The plant uses a two-stage process to remove copper, iron, zinc, and nickel deposits from the steel tube interior surfaces of the boiler.  The first stage is an ammoniated bromate process using sodium bromate, aqua ammonia, and ammonium bicarbonate to remove copper deposits.  The second stage is a two-step ammoniated EDTA process. In the first step, ammoniated EDTA is used to remove iron, zinc, and nickel deposits.  In the second step, oxygen is injected to oxidize the solution to remove any residual copper deposits and to passivate the steel surfaces.


Clean_desc:
The plant uses service water to wash ash off the inside surfaces of the boiler.  It is simply a manual operation of rinsing the fire side using wash down hoses.  The water/ash is sent to the ash pond.


Clean_desc:
The plant uses service water to wash ash off the surfaces of the air heater.  It is simply a manual operation of rinsing the air heater using wash down hoses.  The water/ash is sent to the ash pond.


Clean_desc:
The plant uses service water to wash ash off the inside surfaces of the precipitator.  It is simply a manual operation of rinsing the precipitator using wash down hoses.  The water/ash is sent to the ash pond.


Clean_desc:
The plant uses an aqueous solution of ammoniated EDTA and hydrogen peroxide or oxygen to remove iron and copper deposits from the interior of the steel tube surfaces of the boiler in a two stage process.  The aqueous solution exhibits a nominal pH of 9.2 to 9.5.  The first stage removes the iron oxides from the tube surface which are held in solution by the chelating agent.  The second step involves the addition of prescribed amounts of hydrogen peroxide or air to remove any plated or elemental copper.

MCW_Dest_Other_desc:
Collected in tanks and transported to Landfill-1 for disposal


Clean_desc:
The plant uses hydrogen peroxide, ammonium bicarbonate and aqueous ammonia in an aqueous solution to remove copper deposites from the high pressure section of the steam turbine.  The reagents were circulated through the turbine in a foam at a rate of 10 to 15 gpm.

MCW_Dest_Other_desc:
Collected in tanks and transported to Landfill-1 for disposal.


Clean_desc:
The plant used hydrogen peroxide, ammonium bicarbonate and aqueous ammonia in an aqueous solution to remove copper deposites from two of the feedwater heaters.  The reagents were circulated through the heaters in a foam at a rate of approximately 10 gpm.


Clean_desc:
The plant used 28% hydrochloric acid, sodium hydroxide (caustic soda), and A120 inhibitor in an aqueous solution to remove to remove mineral deposits in the condenser and oil cooler.   The acid was diluted to a 5% inhibited acid solution which was injected into the condenser and oil cooler in  a foam.  It was followed by a water foam and then a weak caustic foam to neutralize the tubes.


Clean_desc:
The plant used 28% hydrochloric acid, sodium hydroxide (caustic soda), and A120 inhibitor in an aqueous solution to remove to remove mineral deposits in the hydrogen cooler.   The acid was diluted to a 5% inhibited acid solution which was injected into the cooler in  a foam.   It was followed by a water foam and then a weak caustic foam to neutralize the tubes.


Clean_desc:
The plant uses a combination of high and low pressure water to remove ash deposits from the fireside of the boiler tubes.


Clean_desc:
The plant uses a combination of high and low pressure water to remove ash deposits from the air heater.


Clean_desc:
The plant uses a combination of high and low pressure water to remove mineral and organic deposits from the condenser.


Clean_desc:
The plant uses a combination of high and low pressure water to remove mineral and organic deposits from the bearing cooling heat exchangers.


Clean_desc:
The plant uses a combination of high and low pressure water to remove mineral and organic deposits from the lube oil coolers.


Clean_desc:
The plant uses a combination of high and low pressure water to remove mineral and organic deposits from the hydrogen coolers.


Clean_desc:
The plant uses citric acid to remover primarily iron deposits from the boiler circulating pump motor cooler.


Clean_desc:
The plant uses inhibited tetraammonium EDTA to remove iron oxides from the steel surfaces of the boiler.  The system contains no copper.  Following iron oxide removal, boiler temperature is reduced and oxygen is added to achieve boiler surface passivation.


Clean_desc:
Infrequently, the plant uses raw water to remove clinkers and ash from the exterior of the boiler tubes.  For this operation, a vacuum truck is used to remove the cleaning waste from the boiler.


Clean_desc:
The air heaters are cleaned using low pressure raw water.  This cleaning operation takes place over a 6-hr period and occurs on as 'as needed' basis following a visual inspection or a high differential pressure indication across the heaters.  The cleaning occurs approximately once per year.  The pump design flow rate is 1,620 gpm.  The amount of dirty water produced is approximately 583,200 gals.


Clean_desc:
The plant uses steam to remove ash from the external boiler tube surfaces and from the boiler internals.  The removed ash is commingled with either bottom ash  and falls into an ash pit or flyash and is carried to precipitator hoppers.


Clean_desc:
The plant uses a sandblasting material to clean the steam turbine rotating and stationary parts.

MCW_Dest_Other_desc:
The sandblast material and residue is barreled and landfilled at an off-site non-SCE&G facility.


Clean_desc:
The Plant uses a Diammonium EDTA solution to remove iron and nickel scale deposits from tube surfaces, which are constructed of carbon steel. Ammonia is added to raise pH to 9 to 10 and oxygen is then added for a copper removal stage and initial passivation. Then rinses with ammonia at 9 to 10 pH for final passivation.

MCW_Onsite_TS_Other_desc:
Evaporation ponds, Emergency only never used for chemical cleaning

MCW_Dest_Other_desc:
Containerized, TCLP tested for  hazardous substances by certified lab.  If non-hazardous, used either for dust suppression at ash landfill or put into evaporation pond. If hazardous, it would be shipped off site as a hazardous waste.


Clean_desc:
The plant uses ammoniated EDTA to clean the internal surfaces of boiler tubing; A300 inhibitor and an antifoaming agent is included in the cleaning process.


Clean_desc:
The plant used and inhibited ammoniated EDTA sotoution for initial system chemical cleaning.

MCW_Dest_Recyc_desc:
Recycled to the process water ponds for reuse on site.


Clean_desc:
The inhibited hydrochloric acid cleaning was more successful.  This involves using a 7.5% HCL solution to remove  iron deposits and minor copper deposits.


Clean_desc:
The plant used a citric acid process (pH 3.5) to remove iron deposits followed by ammonia (pH 9.5) to remove copper.


Clean_desc:
A 7.5% HCl solution with thiourea and ABF is circulated through the boiler in a Single Stage Cleaning to remove iron and copper deposits.  (Boiler cleaning volume is 27,500 gallons.)  Then the boiler is rinsed once.

MCW_Onsite_TS_Other_desc:
Waste is stored for later chemical precipitation.


Clean_desc:
A 7% solution of HCl is used to remove iorn and copper deposits from the tube surfaces of the boiler by circulating in a Single Stage Cleaning.  (Boiler cleaning volume is 43,000 gallons)  A single rinse is performed.


MCW_Dest_Other_desc:
Residues captured internally by other systems


# Mercury_Control_Studies

FGMC_process:
Rockport Units 1 and 2 are currently operating an Activated Carbon Injection Syste, upstream of the Electrostatic Precipitator (ACI-ESP) for flue gas mercury control. ACI is injected upstream of the ESP, mercury adsorbs to the surface of the carbon particles, and then the carbon is collected in the ESP with other particulate matter. Solid waste (ash/carbon mixture collected in the ESP) is the only waste product, as ash is conveyed dry at Rockport plant. The ash/carbon mixture is landfilled. There is no process wastewater.

FGMC_pilot_tech:
Rockport plant tested activated carbon injection upstream of the ESP. Both brominated and standard carbon were tested.


FGMC_process:
Bromine activated carbon will be injected into the duct work upstream of the FGD and Fabric Filter.  All carbon injected into the gas path will be recovered (along with the flyash) by the fabric filter and then pnuematically conveyed with compressed air to a silo.  At the silo, the ash/carbon wastestream will be conditioned with water in a pugmill and then transported to a landfill for disposal.  No process wastewaters are expected to result from the Hg removal system.


FGMC_process:
The ACI system provides halogenated powdered activated carbon (PAC) to the Spray Dryer Absorber (SDA) inlet flues. The halogenated PAC absorbs mercury while it is in contact with the flue gas. PAC is metered into educters to provide mixing with air that conveys the PAC to the injection points. PAC is recovered as a solid component of the following process streams: SDA Hopper Ash, FGD Waste Ash, and Recycle Ash. SDA Hopper Ash is collected and trucked for disposal at LANDFILL-1. Waste and Recycle ash are collected from the Fabric Filter Dust Collector [cont'd]...


FGMC_process:
The system is a powdered activated carbon (PAC) dry storage and dosing system. Dry PAC is injected into the flue gas stream upstream of the baghouse. The solid waste is then collected in the baghouse with the fly ash. The fly ash is then taken to an on-site ash disposal facility or sold for various beneficial uses (see Part C, Questions C2-9, C2-25, and C2-28.)  No wastewater is generated.


FGMC_process:
Pursuant to the IL MPS rule, the Hutsonville units will need to inject 5 lbs/Macfm of brominated activated carbon starting 1/1/15.  For units below 90MW, the IL requirement in only to inject the prescribed quantity of sorbent.  The Hg removal noted above is an estimate and is dependent on the interference of the SO3 injection system needed for ESP performance.


FGMC_process:
Activated Carbon Injection Systems (ACI) have been installed on all 4 SE units.  Activiate carbon is injected into the flue gas stream upstream of the electrostatic precipitators (ESP) in order to absorb mercury from the flue gas.  The ESPs remove both the fly ash and the activated carbon.  The solid waste is then transported to the on-site landfill.  There are no wastewater streams generated from the ACI systems.


FGMC_process:
The Newton Plant use an Halogenated activated charcoal system for mercury control.  The system injects the activated charcoal into the waste stream upstream of the Electrostatic Precipitator (ESP) system where the activated charcoal is collected with the fly ash.  For FGMC-1, the activated charcoal is wet sluiced to the primary ash pond.  For FGMC-2 the activated charcoal is handled dry and disposed of in the landfill location on the plant site.


FGMC_process:
Oxidizer injection with coal to furnace followed by Activated Carbon Injection.  Activated Carbon is collected by Multiclone dust collector and Wet Scrubber.  Fly ash is collected dry or transported to ash pond and combined with bottom ash. Scrubber sludge is settled in pond and periodically removed to off site landfill.

FGMC_pilot_tech:
Various oxidizing agents and Activated Carbon injection with/without baghouse for particulate capture


FGMC_process:
SE Unit 2 operates an activated carbon injection (ACI) system with injection upstream of the air heater.  Non-brominated activated carbon is injected because calcium bromide is added to the coal upstream of the boiler (in the coal feeders) to enhance the mercury oxidization process and improve the performance of the ACI system.  A proprietary ADA-ES chemical (tradename ATI-2001) replaced SO3 as the flue gas conditioner on SE Unit 2 to further enhance the performance of the ACI system.  Fly ash laden with mercury and activated carbon is captured by the electrostatic precipitator, conveyed to a fly ash silo and is then typically sold and hauled off-site for beneficial re-use thru a third-party broker.

The planned SE Unit 1 and SE Unit 2 baghouses will operate in conjunction with planned dry FGD systems.  These planned baghouses will capture dry fly ash laden with mercury.  A contract for these systems has not been awarded nor have they been designed however it is anticipated that the fabric filter bags will be periodically pulsed to move the ash to storage silos and the ash will be periodically collected from these silos and hauled to a landfill and/or used beneficially if the ash characteristics allow this.

FGMC_pilot_tech:
Calcium Bromide, ATI-2001 Flue Gas Conditioning, On-Site Milled Activated Carbon Injection


FGMC_process:
Future additions will include a baghouse on all units. The baghouse combined with wet lime scrubbing should allow the plant to meet MACT limits. Use of a coal oxidizer is planned to facilitate additional Hg removal in the wet scrubber. Waste is both dry (baghouse) and wet (scrubber waste) and will be deposited in the local landfill.


FGMC_process:
We are planning on installing an activated carbon injection system upstream of the baghouse.  It will be dry handling and no new waste water stream would be created.

FGMC_pilot_tech:
Calgon multi-carbon injection, EPRI sponsered multi-carbon testing


FGMC_process:
The pulse jet fabric filter baghouse is operated in conjunction with an activated carbon injection system and is a dry system.  Fly ash laden with mercury is captured by the bags within the baghouse and periodically transferred to an ash silo by pulsing the bags on pressure.  This ash is periodically hauled to an on-site landfill.


FGMC_process:
The mercury control plan is to use a combination of coal oxidizer and activated carbon injection (ACI) to remove mercury in the units' ESPs and wet scrubbers.  Waste will be a combination of dry product from the ESPs and wet solution from the scrubbers.  The products will be disposed with ash fly and bottom ash.


FGMC_process:
Activated Carbon Injection is installed after the economizer, in the ductwork.  Prior to the Activated Carbon Injection is Dry Trona Injection.  Activated Carbon Injection occurs prior to the fabric filter baghouse.  This is the configuration for each unit, i.e. Units 67 (SE Unit 1) and 68 (SE Unit 2).  The spent Activated Carbon is trapped in the baghouse with the fly ash and travels pneumatically to the fly ash silo. The solid waste is unloaded into trucks and transported to the Huntley Ash Landfill for disposal.


FGMC_process:
The TOXECON project was initiated as a full-scale mercury removal demonstration project conducted with DOE.  The TOXECON process was developed by EPRI and involves the use of activated carbon as a sorbent followed by polishing baghouses to collect the carbon-ash mixture.  This was installed in a common duct for three 90-MW coal-fueled units burning low-sulfur PRB coal.  Maximum mercury removal rates under test conditions achieved 90 percent removal.  There are no wastewater streams.  Approximately 200 lb/hr of carbon-ash mixture is generated by the process that is subsequently placed in a licensed landfill operated soley for coal ash disposal.  The TOXECON system continues to operate as a PM and Hg control device since the demonstration project ended in January 2010.


FGMC_process:
S.E. Unit 3 uses Activated Carbon Injection.  The injected carbon adsorbs the mercury, is captured in a baghouse, and is deposited in Landfill-1 of table A-6.

FGMC_pilot_tech:
Alstom Mer-cure technology (brominated and un-brominated) with and without KNX (liquid CaBr2),


FGMC_process:
Since the system has not been designed, this information is preliminary and subject to change based on mercury emission rules and mercury removal technologies.  The current plan uses Activated Carbon plus Sorbent Enhancement Additives SEA).  Process waste will be dry and handled by the Electrostatic Precipitator (ESP) with a final destination at the mine landfill.


FGMC_process:
Dry powdered activated carbon (PAC) is stored in a silo.  A PAC dosing system is used to transport the PAC from the silo to a series of injection lances located upstream of the electrostatic precipitator (ESP).  The PAC is dosed gravimetrically, by metering the carbon dosed (lb) per volume of air flow in the stack (mmacf).  The system is designed to achieve a mercury removal rate of 90%.  The PAC along with adsorbed mercury, and fly ash are collected by the ESP.  The material collected in the ESP hoppers is pneumatically conveyed to a fly ash silo.  The material collected in the silo is loaded to tanker trucks for off-site disposal and/or beneficial use.


FGMC_process:
Activated carbon injection ahead of the precipitators.  Activated carbon is mixed with fly ash and disposed at the on-site ash landfill.  It is anticipated that the mercury loading to the FGD system will be reduced resulting in less mercury in gypsum and FGD wastewater.


FGMC_process:
Powdered Activated Carbon is injected into the flue gas upstream of the electrostatic precipitator (ESP) where the mercury adheres to the carbon. The particulates and activated carbon are collected in the ESP and then stored in a silo. The ash/activated carbon is loaded into trucks from the silo and hauled out the East Ash Pond for storage. The ash is sluiced with service water from the trucks through a line that is tied into lines carrying bottom ash to the East Ash Pond.


FGMC_process:
The activated carbon injection (ACI) system has been installed but is not operational.  Once operational, it will inject the ACI particles into the flue gas ahead of the ESPs.   The ACI will be collected in the ESP hoppers and inherently mixed with the fly ash and disposed within the on-site ash landfill.  The injection rate will be 300 lb/h.


FGMC_process:
Each unit uses Activated Carbon Injection (ACI) directly upstream of PM Control to control mercury.  No process wastewater is generated or affected by the use of ACI.  Sold waste (dry carbon and fly ash) from Mercury and PM Controls is sent off-site to a landfill.


FGMC_process:
PAC injection prior to baghouse for mercury adsorbtion.  PAC removed from stream with baghouse in conjunction with PM.  All PM hauled off site inclusive to landfill.

NaBr applied to coal prior to pulverizer.  There is no water used or generated for mercury control.


FGMC_process:
To control Hg, Brandon Shores injects hydrated lime and powdered activated carbon into the duct downstream of the hot side electrostatic precipitator, the primary particulate collection system.  The hydrated lime removes SO3 as an interferent and the PAC removes the mercury from the gas.  A pulse jet fabric filter removes the pac/lime ash from the flue gas stream.  The ash is then conveyed by air to an ash silo.  Trucks are unloaded with ash conditioning water and sent off site.  Our system was designed by Siemens Environmental with Delta Ducon as a subcontractor.


FGMC_process:
Mercury controls will by a dry sorbent injection into the flue gas.  Sorbent will be collected with fly ash in the baghouse and will be hauled off site for beneficial reuse.  No waste water will be generated in this process.


FGMC_process:
DOE funding was approved to Consol Energy to install water injection probes for temperature control of flue gas for increased mercury removal with existing LOI carbon in the flue gas.  This mercury control device was included in the latest title 5.  Also in the latest title 5 modification we permitted activated carbon injection system for future installation if removal rates are less than required to meet NYSDEC part 246.


FGMC_process:
Solid waste generated includes electrostatic precipitator ash and gypsum.  The process wastewater stream generated is a wet flue gas desulphurization stream.  No negative effects of the non-carbon sorbent on fly ash or gypsum have been shown.  Mercury content is increased in the wastewater stream due to this process initially at the sampling location; however the mercury content at the outfall location satisfies environmental requirements.  The solid wastes are hauled off-site and used as and additive for concrete.


FGMC_process:
Two units have a Dry scrubber/Baghouse system for SO2 control.  Two units do not have SO2 control and use an ESP for particulate control. The plan is to add ACI to control Hg to the MACT requirements up to 90% removal with ACI.  Testing will be done to verify this assumption. Waste will be dry from the baghouses and ESPs.


FGMC_process:
Sorbant (Powdered activated carbon) is injected into the flue gas upstream of the fabric filter.  Any mercury captured will exit with fabric filter solid waste (fly ash), it is handled dry and hauled off site.  There are no wastewater streams generated by the mercury control system, nor are any existing wastewater streams affected by it.


FGMC_process:
Powdered Activated Carbon (PAC), often brominated, is injected into the exhaust gas stream after the air preheater and before the existing ESP.  The PAC absorbs the mercury in the exhaust gas stream and is captured and removed by the existing ESP.  Since there is only on ESP in the exhaust stream of each unit, each ESP collects both the ash and PAC together.  These materials are transported via the site's dry ash handling system to ash silos.  The as/PAC combo is then shipped offsite either for disposal or beneficial reuse.  This system does not generate process WW.


FGMC_process:
Pluverized activated carbon is injected into the flue gas downstream of the electrostatic precipitator and upstream of the pulse-jet fabric filter. The fly ash that was not removed by the ESP and the activated carbon are captured by the fabric filter and are disposed of in a landfill.


FGMC_process:
Primary mercury capture is by injecting a halogenated powder activated carbon to absorb Hg.  The activated carbon is removed from the flue gas via the bag house (fabric filter) along with FGD solids and fly ash.  The dry material filtered from the flue gas is collected and trucked to the ash disposal site.

FGMC_pilot_tech:
Conducted in May 2006. Tested CaCl2, powder activated carbon, and combinations of both


FGMC_pilot_tech:
Calcium bromide injection (on the coal feed)


FGMC_process:
Dry powdered activated carbon (PAC) is stored in a silo.  A PAC dosing system is used to transport the PAC from the silo to a series of injection lances located upstream of the electrostatic precipitator (ESP).  The PAC is dosed gravimetrically, by metering the carbon dosed (lb) per volume of air flow in the stack (mmacf).  The system is designed to achieve a mercury removal rate of 70%.  The PAC along with adsorbed mercury, and fly ash are collected by the ESP.  The material collected in the ESP hoppers is pneumatically conveyed to a fly ash silo.  The material collected in the silo is loaded to tanker trucks for off-site disposal and/or beneficial use.

FGMC_pilot_tech:
Activated carbon injection test (4 days)


FGMC_process:
A new baghouse is being installed to improve the SO2 removal ability of the existing spray dryer system. ACI will be added before the baghouse to meet the ulitimate MACT limit.  Waste shall be dry and locally landfilled with the collected fly ash and scrubber waste.


FGMC_process:
Mercury Controlled is planned for WEC2 (SE Unit A) to start October 2010.  Carbon is injected between the ESP and the Dry Scrubber / Baghouse.  Scrubber ash will be collected via dry system.  Scrubber ash will contain carbon, mercury that is captured, Hydrated lime and Acid Gas reactants such as CaF, CaSO2, CaCl, etc.  The ESP will remove approximately 85% of the Fly Ash prior to the Dry Scrubber.  The scrubber ash can be trucked off site for benefical reuse or sluiced to the scrubber ash pond for reclaim and benefical use off site. Fly Ash is handled dry or sluiced to ash pond for reclaim and benficial reuse on and off site.  No waste water is discharged off site unless we experience storm events greater than a 25 year - 24 hour storm.  Amount of Storm water discharge is dependent upon waters released from private farm ground upgradient of the site.


FGMC_process:
Calcium bromide addition system.  A liquid form of 50% calcium bromide is sprayed on to the coal at the inlet to the ball mills used to pulverize the coal.  The bromide addition results in conditions that lead to the oxidation of mercury into a form that increases removal in the wet FGD system.  Mercury is ultimately removed from the wet FGD blowdown at the treatment facility and the dried wastewater sludge is ultimately landfilled.  Increased amounts of flue gas mercury removal (adsorbed to the fly ash) in the precipitators has also been observed.

FGMC_pilot_tech:
Yes, other types of mercury sorbent testing was done in early 2000's.


FGMC_process:
FGMC-1: Activated Carbon Injection system which injects brominated activated carbon upstream of the Spray Dryer Absorbers (SDA's). Carbon is collected along with the fly ash and FGD in the fabric filter and is disposed of in the landfill. FGMC-A and FGMC-B are planned activated carbon injection systems that will inject brominated activated carbon upstream of wet scrubbers/wet ESP's. The carbon will be collected along with the flyash and FGD and disposed of in the scrubber slurry pond.


FGMC_process:
Dry Activated Carbon with Sorbent Enhancement Additive Mercury Capture System -Sorbent Enhancement Additive is injected into the boiler,  Activated carbon will be injected into final stages of existing dry Electrostatic Precipitator Systems.  The carbon contaminated Fly Ash will then be dry (air) transported to a segregated collection bin system where the dry Fly Ash will be collected in trucks for hauling to an off-site land fill.

FGMC_pilot_tech:
Dry Activated Carbon with Sorbent Enhancement Additive Mercury Capture


FGMC_pilot_tech:
TMT-15 and Adsorption Plus(Hg) was tested in the wet FGD system


FGMC_process:
A carbon injection system was installed on SE Unit 6 in July 2010.  The system is still in the prove out stage and has not been released to production.  The system injects carbon upstream of the dry electrostatic precipitators.  The carbon captures the mercury and is combined with the flyash in the precipitators.  No wastewater is generated as a result of this system operation.  The ash/carbon mixture constituents are currently being evaluated and ultimate disposal will depend upon the constituents found and the final approval of the Coal Combustion Residuals from Electric Utilities Rule being proposed by the EPA.  Preliminary results indicate that the current hazardous waste limits will not be exceeded by the material so it can continue to be used for beneficial reuse.


FGMC_pilot_tech:
Northeastern plant tested activated carbon injection upstream of the ESP. Both brominated carbon and standard carbon were tested.


FGMC_pilot_tech:
Conesville plant tested activated carbon injection upstream of the ESP. Standard carbon was used.


FGMC_process:
Sorbent (Powdered Activated Charcoal, PAC) is injected downstream of the Dry ESP.  Spent sorbent containing Hg is collected in the Pulse Jet Fabric Filter, PJFF.  Flyash and sorbent collected in the PJFF are transferred to the Zero Discharge Ash Treatment Basin.


FGMC_process:
The Meredosia Plant use an Halogenated activated charcoal system for mercury control.  The system injects the activated charcoal into the waste stream upstream of the Electrostatic Precipitator (ESP) system where the activated charcoal is collected with the fly ash and wet sluiced to the fly ash pond.

FGMC_pilot_tech:
Onsite sorbent activation of carbon w/ reinjection into the flue gas for HG control.


FGMC_process:
The fuel additive reports to fly ash and is disposed of in a landfill.  No wastewater is generated from this process.


FGMC_process:
Oxidant additon to coal on conveyor prior to coal bunkers.  Oxidized mercury will be removed by the wet scrubber system.


FGMC_process:
The facility plans to install an Activated Carbon Injection (ACI) system by December 31, 2020.  That system is not anticipated to generate a process wastewater stream.  The solid waste generated by the ACI process will be commingled with fly ash and disposed of in the facility's ash landfill.

FGMC_pilot_tech:
Pirkey plant tested activated carbon injection upstream of the ESP. Brominated carbon and standard carbon were both tested.


FGMC_process:
Activated Carbon Injection is installed after the economizer, in the ductwork.  Prior to the Activated Carbon Injection is Dry Trona Injection.  Activated Carbon Injection occurs prior to the fabric filter baghouse.  This is the configuration for each unit, i.e. Units 1-4 (SE Unit 1 to SE Unit 4).  The spent Activated Carbon is trapped in the baghouse with the fly ash and travels pneumatically to the fly ash silo.  The solid waste is unloaded into trucks and transported to the Dunkirk Ash Landfill (SWMF) for disposal.  No process waters are generated from the activated carbon injection system.


FGMC_process:
Fuel selection provides mercury control for the existing Unit 1.  Unit 2 will use activated carbon injection upstream of the Dry absorber and ash will be collected dry without contact to water or wastewater and collected in a silo.  The ash accumulated will be conditioned and landfilled on site.


FGMC_process:
Activated carbon is injected into the flue gas upstream of the baghouse.  Mercury attaches to the carbon which is collected in the baghouse along with the fly ash.  No process wastewater is generated.  Carbon is collected and managed with the fly ash.


FGMC_pilot_tech:
Activated Carbon Injection (one week test using portable, vendor-supplied injection skid)


FGMC_pilot_tech:
Catalyst Removal Technology/ Activated Carbon injection


FGMC_process:
Activated carbon is currently injected into each unit's flue gas stream after its dry electrostatic precipitator but before its baghouse. The activated carbon is collected in a baghouse and hauled dry to the onsite active east ash pond system.


FGMC_process:
ESP: The native removal of mercury by the dry electrostatic precipitators is approximately 50%.  ACI: Injecting brominated powdered activated carbon (PAC) into the flue gas duct downstream of the air preheater and upstream of the ESP increases mercury removal to 90%  The gas-phase mercury in the flue gas contacts the PAC and attaches to its surface.  The PAC with the mercury attached is then collected by the ESP along with the fly ash.  No process wastewater is generated.  The fly ash is injected into abandoned mine shafts.

FGMC_pilot_tech:
Calcium bromide application to coal.  Activated carbon injection.


FGMC_process:
An activated carbon injecion system was installed on SE Unit-4 during construction. It is currently not permited to run in our air permit.  The process is a dry system is will not generate a waste water stream.


FGMC_process:
KNX is added to the coal. Coal combusted with KNX oxidizes the Hg. The Oxidized Hg is removed in the wet FGD. Wastewater from FGD is disposed to evaporation pond SPD-1

FGMC_pilot_tech:
Catalytic oxidation and scrubber removal & KNX treatment scrubber removal


FGMC_process:
No wastewater will be generated from the activated carbon injection process.  Solid wastes generated will be disposed of in the station landfill or hauled off-site.


FGMC_pilot_tech:
1-Bromine Injection for Hg Oxidation, 2-Triple Action Catalyst for Hg Oxidation, 3-Pilot ESP Activated Carbon Injection, 4-Plasma Enhanced ESP, 5-Pilot Baghouse Activated Carbon Injection, 6-Activated Carbon Injection into Pilot FGD, 7-Sodium Tetrasulfide Demonstration, 8-Honeycomb Catalyst Testing


FGMC_process:
PAC Injection upstream of SDA and collected in baghouse, dry transported for disposal to lined landfill on site.


FGMC_process:
Primary mercury capture is by injecting CaCl2 to convert Hg to the oxidized state, then activated carbon is injected to absorb the oxidized Hg.  The activated carbon is removed from the flue gas via the bag house (fabric filter) along with FGD solids and fly ash.  The dry material filtered from the flue gas is collected and trucked to the ash disposal site.

FGMC_pilot_tech:
Powder activated carbon injection - with and without bromine impingement.


FGMC_process:
FGMC-A: Planned for 2012,the system is a calcium bromide liquid fuel treatment method used on incoming fuel prior to combustion. There would be no process wastewater generated.  Solid waste will be hauled offsite.


FGMC_process:
Powdered activated carbon (PAC) is injected upstream of the electrostatic precipitator (ESP) on all six units.  The PAC system was started on July 1, 2009.  The PAC is collected along with fly ash in the ESP.  The material is collected dry and conveyed to silos.  The carbon-ash material is either used offsite for beneficial use or placed in the ash pond.  There is no process waste water or fly ash transport water associated with the carbon-ash handling.

FGMC_pilot_tech:
powdered activated carbon injection upstream of ESP.


FGMC_process:
FGMC-1 & FGMC-2 
The flue gas flow path for Units 1 and 2 from the air heater outlet to the stack is ESP (electrostatic precipitator), SDA (spray dryer absorber FGD), FF (fabric filter) and stack.  
FGMC-1 & FGMC-1 inject PAC (Powdered activated carbon) downstream of electrostatic precipitators and upstream of SDA/FF (FGD-1 & FGD-2).  SDA waste and PAC are collected in the FF and pneumatically conveyed dry to storage silos.  The SDA waste is trucked away and disposed of offsite in lined landfills with enough water added to the SDA waste for dust control.  Any wash water that may be used in the SDA is routed to the adjacent SDA for use as makeup.  Trucks are washed prior to leaving site.  Truck wash water is routed to the wastewater treatment system [SPD-1 (for primary settling and equalization followed by lime and polymer addition.  Waste water is then sent sequentially to   SPD-2 & SPD-3 for metal hydroxide and solids settling prior to discharge via 004B)].
FGMC-3 
The flue gas flow path for Unit 3 from the air heater outlet to the stack is 1st stage ESP , 2nd stage ESP and stack.  
FGMC-3 injects PAC downstream of the 1st stage ESP and upstream of the second stage ESP.  The PAC with mercury is collected in the second stage ESP and is pneumatically transferred dry to fly ash storage silos.  The fly ash is then pneumatically transferred to a CBO (carbon burn out process - fluidized bed combustor) where carbon  is burned off such that the fly ash meets ASTM C618 Using Coal Ash As Cement Replacement.  The flue gas from the CBO process is routed to either Units 1 or 3 boilers.  The processed ash is sold in the concrete market.   There are some waste waters generated when the CBO flue gas cooler is washed.  The wash water is routed to the waste water treatment (SPD-1, SPD-2 & SPD-3).
The facility is planning to add a dry FGD/FF (FGD-3) system to unit 3.  It is expected to be operational in 2014.  At that time the PAC injection point will be moved downstream of the 2nd stage ESP.  If a use for the waste product is not identified then the waste will  be trucked away and disposed of offsite in lined landfills with enough water added to the SDA waste for dust control.  Trucks will be washed prior to leaving the asite.  Truck wash water will be routed to the wastewater treatment (SPD-1, SPD-2 & SPD-3).


FGMC_process:
The mercury removal system is a Wheelabrator Pulse Jet Baghouse with a Powdered Activated Carbon injection system. A mixture of PAC and Ash is collected dry in the baghouse hoppers and transported to a local storage silo. The PAC/Ash is currently being transported dry via truck to a local landfill. An onsite PAC/Ash storage facility is currently under construction. Approximately 20 tons per baghouse per week of dry PAC/Ash is being hauled to a local landfill. There is no process water involved in this system


FGMC_process:
Current system on Unit 2 consists of CaBr2 solution added to oxidize the mercury for capture in the ESP along with the dry fly ash.  The ash is then landfilled.  No process wastewater streams are generated.  The proposed systems on both Units 1 and 2 will also use CaBr2, along with powdered activated carbon, to serve the same purpose.  The fly ash will be landfilled, no process wastewater streams will be generated.


FGMC_process:
The fuel additive reports to fly ash and is disposed of in a landfill or transported off site at the plant's expense.  No wastewater is generated from this process.


FGMC_pilot_tech:
sorbent injection  (17 carbon based sorbents were tested)


FGMC_process:
The facility uses an activated charcoal injection system with a calcium bromide solution additive for the flue gas mercury control system. The activated charcoal is injected into the flue gas, upstream of the particulate filter baghouse. The absorbed mercury compounds are collected in the fly ash from the baghouse.  All of the ash (bottom ash & fly ash) from the facility is combined in a collection silo and handled as a dry material and is either landfilled onsite or sold for oil field reclamation work (seasonal).


FGMC_process:
Activated carbon is currently injected into the Unit 1 and Unit 2 flue gas stream prior to each unit's dry electrostatic precipitator. Baghouses are currently under construction at BEC for Units 1 and 2. When those baghouses become operational, the activated carbon injection points on Units 1 and 2 will be relocated to after the dry ESPs but before the baghouses. A baghouse is already in operation on Unit 3, so the activated carbon for Unit 3 is injected after the Unit 3 dry ESP.


FGMC_process:
It is a Sorbent Injection System with Activated Carbon as the sorbent.  The sorbent is injected into the exhaust ductwork where it adsorbs mercury from the flue gas.  The sorbent is then collected in a fabric filter and handled along with fly ash.  Fly ash and sorbent is transported (dry) to an onsite monofill.  No impact to any process water is anticipated resulting from Mercury removal.  No process wastewater will be generated from this system.


FGMC_process:
Powdered activated carbon is injected in the flue gas duct work upstream of the electrostatic precipitators. The mercury adsorbs to the activated carbon which is then collected along with the fly ash in the precipitator.  The precipitator fly ash/powdered activated carbon is then dry transported via a vacuum/pressure system to intermediate ash storage where it will eventually be transferred to a landfill.


FGMC_pilot_tech:
the plant has experimented with the injection of calcium bromide into the boilers for mercury control


FGMC_process:
Powdered activated carbon (PAC) is injected into the inlet duct of the Turbosorp® Reactor
to absorb the mercury compounds in the flue gas. The PAC System includes:
•One 10-ton storage silo (SILO-1005)
•One truck unloading station
•One feeder train
•Piping and injection nozzles

Powdered Activated Carbon is delivered to the plant by truck. The PAC is unloaded
pneumatically using the truck-mounted blower. The PAC is then transported to the silo
through a 4-inch pipe; an automatic valve in the fill line allows the silo to be
isolated from the fill station.

Normally, the PAC feed rate is controlled as a function of unit load and operator-entered dose rate in lb/MACF. The dose rate to maintain the required outlet mercury level will be based on mercury emission testing and/or the continuous emission monitor.   The amount of PAC required is converted to the speed of the variable speed screw feeder. 

The powdered activated carbon is removed with the dry flash system and ultimately deposited in the AES Greenidge’s Lockwood Landfill.
Powdered activated carbon (PAC) is injected into the inlet duct of the Turbosorp® Reactor
to absorb the mercury compounds in the flue gas. The PAC System includes:
•One 10-ton storage silo (SILO-1005)
•One truck unloading station
•One feeder train
•Piping and injection nozzles

Powdered Activated Carbon is delivered to the plant by truck. The PAC is unloaded
pneumatically using the truck-mounted blower. The PAC is then transported to the silo
through a 4-inch pipe; an automatic valve in the fill line allows the silo to be
isolated from the fill station.

Normally, the PAC feed rate is controlled as a function of unit load and operator-entered dose rate in lb/MACF. The dose rate to maintain the required outlet mercury level will be based on mercury emission testing and/or the continuous emission monitor.   The amount of PAC required is converted to the speed of the variable speed screw feeder. 

The powdered activated carbon is removed with the dry flash system and ultimately deposited in the AES Greenidge’s Lockwood Landfill.


FGMC_process:
SE Unit 5 operates an activated carbon injection (ACI) system with injection ports upstream of the air heater.  Non-brominated activated carbon is injected because calcium bromide is added to the coal upstream of the boiler (in the coal feeders) to enhance the mercury oxidization process and improve the performance of the ACI system.  Fly ash laden with mercury and activated carbon is captured by the electrostatic precipitator, conveyed to a fly ash silo and is then typically sold and hauled off-site for beneficial re-use thru a third-party broker.  SE Unit 4 operates a calcium bromide injection system, adding calcium bromide to coal upstream of the boiler (in the coal feeders).  SE Unit 4's higher LOI provides the necessary carbon to bond with the oxidized mercury which is then captured with the unit's fly ash in the ESP.  Due to the higher LOI of this unit, the fly ash cannot be marketed and is landfilled.

FGMC_pilot_tech:
Activated Carbon Injection, Calcium Bromide, Calcium Chloride, On-Site Milled Activated Carbon


FGMC_pilot_tech:
sorbent injection and powdered activated carbon


FGMC_process:
All units inject 5 lbs/Macfm of brominated activated carbon.  While the target removal rate was 90%, actual Hg control varies as a function of the need for SO3 conditioning for ESP performance.  Current plans are to install a fabic filter for Unit's 2 & 3 in order to meet the IL MPS requirement of 90% removal or a rate of 0.008 lb/GWH.


FGMC_pilot_tech:
Norit Americas Darco HG, ALSTOM Power's Mer-Cure system


FGMC_process:
Activated carbon is currently injected into the Unit 6 (SE Unit-1) flue gas stream after its dry electrostatic precipitator but before its baghouse.


FGMC_process:
The activated carbon is injected in the ductwork preceding thebaghouse. The particulates are mixed with the ash and are conveyed dry with the ash. The ash is then trucked back to the mine for reclaimation. No waste water is generated in this process.


FGMC_pilot_tech:
Dry Sorbent Injection (activated carbon / trona / MgO)


FGMC_process:
The waste product of the sorbent injection has not yet been evaluated for disposal.


FGMC_process:
SE unit 3 is equipped with a powder activated carbon (PAC) injection system installed between the economizer and air heater. SE Unit 4 uses powder activated carbon (PAC) injection at the air heater outlet. Bromiated PAC is used at injection rates required to achieve desired Hg reduction levels while maintaining ash characteristics suitable for concrete sales.  The PAC is collected with the fly ash in the fabric filter and transported using a vacuum system to the fly ash storage silo. Ash from the silo can be sold to the market as a concrete replacement or is removed from the silo using a wet rotary unloader and transported to an on site temporary storage pad. Material on the storage pad is comingled with ash from other SE units 1&2 and used in beneficial reuse projects or land filled at approved sites. There are no wastewater streams.


# Mercury_Controls

FGMC_type:
Activated Carbon Injection System with Pulse Jet Fabric Filter Baghouse


FGMC_type:
Powdered Activated Carbon & Pulse Jet Fabric Filter


# NOx_Controls

nox_other_desc:
Low Excess & Combustion Air Manipulation


nox_other_desc:
Nitrogen Dilluent Injection System and Syngas Moisture Saturation


# Nuc_WW_Treat

nuc_wwts_name:
Condensate Polishing System Waste Treatment


nuc_wwts_name:
Liquid Radwaste Treatment (Outfall No. 171)


nuc_wwts_name:
Sewage Treatment Plant (Outfall No. 079)


nuc_wwts_name:
Deminerallizer & Building Drains for RAW Water Treatment Plant Building (Outfall No. 371)


nuc_wwts_name:
Demineralizer Regenerant Waste Treatment System


nuc_wwts_name:
Laundry Shower and Sump Tanks (LSST) filtration


nuc_wwts_name:
Station Drain Tank 1 treatment system (s)


# Nuc_WWTS_Technology

nuc_wwts_name:
Liquid Radwaste Treatment (Outfall No. 171)


nuc_wwts_name:
Demineralizer Regenerant Waste Treatment System


nuc_wwts_name:
Condensate Polishing System Waste Treatment


nuc_wwts_name:
Sewage Treatment Plant (Outfall No. 079)


nuc_wwts_name:
Deminerallizer & Building Drains for RAW Water Treatment Plant Building (Outfall No. 371)


nuc_wwts_name:
Laundry Shower and Sump Tanks (LSST) filtration


nuc_wwts_name:
Station Drain Tank 1 treatment system (s)


# Plant_Contact_Info

tech1_title:
Manager of Corporate Environmental Policy

tech1_street:
Edison International, GO1, 2244 Walnut Grove


econ1_street:
1515 Arapahoe Street, Tower 1 Suite 1100


plant_name:
Entergy Gulf States Louisiana, LLC - Louisiana Station

tech1_street:
10056 Grogans Mill Road, Parkwood Two, Suite 400

econ1_street:
10055 Grogans Mill Road, Parkwood Two, Suite 400

econ2_street:
10055 Grogans Mill Road, Parkwood Two, Suite 400


tech1_title:
Environmental, Health, and Safety Manager


tech2_title:
Senior Vice President, Factory and Power Plant Operations


plant_street:
C/O Severstal Wheeling, 535 Commercial Ave


plant_name:
NIPSCO D. H. Mitchell Generating Station


tech2_title:
Vice President Environmental Management and Resources


plant_name:
University of Michigan Central Power Plant


plant_name:
Anadarko Plant - Western Farmers Elec Coop


plant_name:
Progress Energy Florida Suwannee Steam Plant


plant_name:
PSEG New Haven Harbor Generating Station


econ2_title:
Sr. Cost Schedule and Power Production Analyst


econ1_title:
Manager of Accounting and Finacial Reporting


econ1_title:
Administrative and Business Services Manager


plant_name:
Dominion Energy Manchester Street Station, Inc.


tech2_title:
Manager, Water and Ecological Resource Services


plant_name:
Entergy Louisiana, LLC - Waterford 1 & 2 Generating Plant

tech1_street:
10055 Grogans Mill Road, Parkwood, Suite 400


plant_name:
Entergy Louisiana, LLC - Ninemile Point Generating Plant

tech1_street:
10055 Grogans Mill Road, Parkwood Suite 400


tech1_street:
10055 Grogans Mill Road, Parkwood Two, Suite 400

tech2_street:
10055 Grogans Mill Road, Parkwood Two, Suite 400


plant_name:
Entergy Operations, Inc.,  Waterford 3 S.E.S.


plant_name:
Consumers Energy - Zeeland Generating Station


plant_name:
Nevada Cogeneration Associates #2, Black Mountain


econ2_title:
Sr. Cost Schedule & Power Production Analyst


tech1_street:
10055 Grogans Mill Road  Parkwood II Suite 400

tech2_street:
425 W. Capitol (A-TCBY-22D)  P.O. Box 551


plant_street:
8 miles NW of Hobbs, NM on Carlsbad Hwy (180)


tech1_title:
Manager, Generation Engineering / Environmental


econ1_street:
1515 Arapahoe Street, Tower 1, Suite 1100

econ2_street:
1515 Arapahoe Street, Tower 1, Suite 1100


plant_name:
Virginia Electric and Power Company - Gordonsville Power Station


econ1_street:
c/o Fortistar LLC, 1 North Lexington Ave., Suite 620


tech1_street:
PPL Susquehanna, LLC - 769 Salem Boulevard

tech2_street:
PPL Generation, LLC, Two N. 9th Street (GENPL6)

econ1_street:
PPL Generation, LLC, Two N. 9th Street (GENLPL8)

econ2_street:
PPL Generation, LLC, Two N. 9th Street (GENLPL8)


plant_name:
Entergy Louisiana, LLC - Perryville Generating Plant


plant_name:
Entergy Louisiana, LLC - Monroe Generating Plant


econ1_street:
Tenaska, Inc. 1044 N 115th Street Suite 400

econ2_street:
Tenaska, Inc. 1044 N 115th Street Suite 400


tech1_street:
10055 Grogans Mill Road - Parkwood II Bldg.

tech2_street:
425 W. Capitol (A-TCBY-22D) P.O. Box 551


plant_street:
4633 Texas Highway 361 @ Sherwin Aluminia Plant

tech1_street:
4633 Texas Highway 361 @ Sherwin Aluminia Plant

tech2_street:
4633 Texas Highway 361 @ Sherwin Aluminia Plant


econ2_title:
Director, Financial Planning & Reporting


econ1_title:
Superintendent, Thermal Assets and Pipeline


plant_name:
Ameren Energy Generating Company - Grand Tower Power Station

tech1_title:
Vice President Environmental Services Department

econ1_title:
Vice President Environmental Services Department


econ2_street:
AES NA Central LLC, 1450 Lake Robbins Drive, Suite 600


tech2_title:
Manager - West Campus Cogeneration Facility Operations and Maintenance

econ2_title:
Senior Director - Accounting and Financial Systems


plant_name:
SABIC Innovative Plastics Burkville Site


tech1_street:
10055 Grogan's Mill Road Parkwood II, Suite 500


econ1_title:
Manager - Financial Accounting & Reporting


plant_name:
Port of Stockton District Energy Facility


tech2_title:
Supervisor, Water and Waste Reg. Programs


plant_name:
CPI USA North Carolina - Southport Plant


tech1_title:
Environmental Health & Safety Coordinator


econ2_street:
Rio Bravo Partnerships, 19100 Von Karman, Suite 570


econ2_title:
Power Plant Operations & Project Development


plant_name:
Wisconsin Power and Light - Nelson Dewey Generating Station


tech2_title:
Environmental Manager - Land and Water Programs


tech1_title:
President-Westmoreland NC Power, LLC, GP Westmoreland Partners


plant_name:
Interstate Power and Light - Sutherland Generating Station


plant_name:
Interstate Power and Light - Burlington Generating Station


tech1_title:
Leader, Environmental and Plant Services


tech1_street:
PPL Martins Creek, LLC, 6605 Foul Rift Road

tech2_street:
PPL Corporation, Two N 9th Street, Mail Stop GENPL6

econ1_street:
PPL Corporation, Two N 9th St, Mail Stop GENPL8

econ2_street:
PPL Corporation, Two N 9th St, Mail Stop GENPL8


tech1_title:
Sr. Director - Operations Environmental Compliance

tech1_street:
Dynegy Midwest Generation, Inc., 604 Pierce Blvd.

econ1_street:
Dynegy Midwest Generation, Inc., 604 Pierce Blvd.

econ2_street:
Dynegy, Inc., 1000 Louisiana St., Suite 5800


plant_name:
Logansport Municipal Utilities Electric Generation


tech1_street:
PPL Montana, LLC, 303 N Broadway, 4th Floor

tech2_street:
PPL Generation, LLC, Two N 9th Street, Mail Stop GENPL6

econ1_street:
PPL Generation, LLC, Two N 9th St., Mail Stop GENPL8

econ2_street:
PPL Generation, LLC, Two N 9th St., Mail Stop GENPL8


econ2_title:
Supervisor, Reports & Property Accounting


plant_name:
Interstate Power and Light - Lansing Generating Station


plant_street:
Approx. 3 mi east of the intersection of St Hwys 59 and 31


plant_street:
Euphrates River Valley Road & Oneida Avenue

tech1_street:
Euphrates River Valley Road & Oneida Avenue

tech2_street:
Euphrates River Valley Road & Oneida Avenue

econ1_title:
Accounting Manager, Power Plant Management Services, LLC

econ2_title:
Projects General Manager, Power Plant Management Services, LLC


econ2_title:
City of Escanaba Electric Superintendent


tech2_title:
Manager - Environmental & Regulatory Compliance


plant_street:
981 Old Augusta Road Central P.O. Box 2507


tech1_title:
Supervisor, Water Quality & Waste Management


plant_name:
Interstate Power and Light - Dubuque Generating Station


tech1_title:
Manager, Engineering and Technical Services


tech2_street:
PPL Corporation, Two 9th St., Mail Stop GENPL6

econ1_street:
PPL Corporation, Two 9th St.,, Mail Stop GENPL8

econ2_street:
PPL Corporation, Two 9th St., Mail Stop GENPL8


tech1_title:
Supervisor, Water Quality and Waste Management


plant_name:
Indianapolis Power & Light Company - Harding Street Station


econ1_street:
120 Tredegar Street-Riverside, 3rd Floor

econ2_street:
120 Tredegar Street-Riverside, 3rd Floor


econ2_title:
Manager, AES North America Generation FP&A


econ1_title:
Manager Energy Supply Business Administration


plant_name:
Wheelabrator Frackville energy Company, Inc.


plant_name:
RRI Energy Inc. Portland Generating Station


plant_name:
Wisconsin Power and Light - Columba Energy Center


econ1_title:
Manager, Financial Accounting & Reporting

econ2_title:
Manager, Financial Accounting & Reporting


plant_name:
Interstate Power and Light - Prairie Creek Generating Station


econ1_street:
Mirant Services LLC, 1155 Perimeter Center West


tech2_street:
PPL Corporation, Two N 9th Street, Mailstop GENPL6

econ1_street:
PPL Corporation, LLC, Two N 9th Street, Mailstop GENPL8

econ2_street:
PPL Corporation, LLC, Two N 9th Street, Mailstop GENPL8


plant_name:
PSEG Bridgeport Harbor Generating Station


econ1_street:
1155 Perimeter Center West, Mail Stop 100 GA


plant_name:
Mt Carmel Cogen (formerly Foster Wheeler)


plant_name:
City of Virginia Department of Public Utilities


plant_name:
Indianapolis Power & Light Co. - Eagle Valley Generating Station


tech2_title:
Supervisor - Environmental and Chemistry


tech2_street:
PPL Corporation, Two N. 9th St. Mail Stop GENPL6

econ1_street:
PPL CorporationTwo N 9th St. Mail Stop GENPL8

econ2_street:
PPL Corporation, Two N. 9th St. Mail Stop GENPL8


tech2_title:
Manager of Planning & Regulatory Affairs


tech2_title:
Manager of Engineering and Technical Services


plant_name:
Interstate Power and Light - Ottumwa Generating Station


plant_name:
Entergy Gulf States, LLC - Roy S. Nelson Station


tech2_title:
Manager - Blount Operations and Maintenance


plant_name:
Muscatine Power and Water Generating Station


tech2_street:
4 Miles West of Kincaid on Route 104, P.O. Box 260


econ1_title:
General Manager and Assistent Controller


plant_name:
Indianapolis Power & Light Company - Petersburg Generating Station


tech1_street:
Dynegy Midwest Generation, Inc., 604 Pierce Blvd

econ1_street:
Dynegy Midwest Generation, Inc., 604 Pierce Blvd

econ2_street:
Dynegy  Inc.,  1000 Louisiana Street Suite 5800


plant_name:
Associated Electric Cooperative, Inc, Thomas Hill Energy Center


plant_name:
City of Orrville, Ohio Department of Public Utilities


tech2_title:
Manager, Water & Ecological Resource Services


econ1_title:
Supervisor - Permitting Services Section


econ1_street:
Towne Center 1, 1450 Lake Robbins, Suite 600

econ2_street:
Towne Center 1, 1450 Lake Robbins, Suite 600


tech1_title:
Supervisor, Natural Resources and Environmental Communications


econ2_title:
Coordinator Operations Accounting - WPSC


econ1_title:
General Manager and Assistant Controller


tech2_street:
HC 76 Box 430 Rt. 93 2 miles west of Bismark


# Plant_General

steam_use_other_desc:
Use steam for sootblowing, and auxiliary steam for pegging steam to the deaerator (DA), and snuffing steam for mill starts and stops.


EAreport_notattach_desc:
EIS done by FERC in late 1970's - electronic copy not available


steam_use_other_desc:
Steam is sold to a neighboring company as process steam for paper recycling.


prime_purpose_desc:
Steam generation for heating and cooling is the principal reason for the operation of the plant and this activity results in the predominant source of revenue for this facility.


steam_use_other_desc:
Since we are a cogeneration facility, we supply steam to a local nursing home for heating purposes. We also use steam to dry our fuel.


steam_use_other_desc:
Cogeneration (steam supply for papermaking).


steam_use_other_desc:
Steam injection is admitted into the gas turbine for control of NOX emmissions.


steam_use_other_desc:
Soot blowers, feedwater heater, hydrolysis of urea to ammonia for SCR are less than 1%


elec_other_desc:
Line losses and power provided free of charge.


steam_use_other_desc:
Provide process steam to adjacent ethanol plant


steam_use_other_desc:
Sold to state correctional facility to generate heating and A/C.


EAreport_notattach_desc:
EA or EIS not readly avaliable.  See Comments


EAreport_notattach_desc:
Site specific boron study on Kaskaskia River related to ash pond discharge is available upon request.


steam_use_other_desc:
Steam sales to local customers for process steam


steam_use_other_desc:
Produce steam to supplement Moores Park Steam Utility


steam_use_other_desc:
ICLP IS A COGENERATING FACILITY, 5% OF THE STEAM IS SENT TO A CITRUS PROCESSING FACILITY


elec_other_desc:
Other is estimated losses from transformers

steam_use_other_desc:
Auxilliary steam for operation of the steam units (sootblowing and boiler feed pumps)


EAreport_notattach_desc:
EA was conducted prior to the construction of Unit 2. Results of study are insignificant with respect to water usage and effluents.


EAreport_notattach_desc:
The 30 year old EAS & Corps EIS considered all plant aspects & only provided a brief summary of wastewater treatment and the cooling water system. More detailes info is available from more recent files and from the companies 316 a and 316b demonstrations


EAreport_notattach_desc:
Environmental analysis was completed in 1975 including the ponds.  If requested, we will send hard copy.


EAreport_notattach_desc:
The EIS study for Polk Power Staion is voluminous and was submitted to EPA previously with approval by Region IV Administrator John H. Hankinson, Jr. on May 26, 1994.


steam_use_other_desc:
As a QF Facility, the plant supplies steam to the adjacent oil field for Enhanced Oil Recovery


steam_use_other_desc:
Process steam supplied to the ExxonMobil refinery, which is a partial owner of the electric steam generating facility.


steam_use_other_desc:
LM6000PC combustion turbine generator set engine (combustor) steam injection for NOx emissions control


steam_use_other_desc:
380 klbs/hr provided to steam host for their use.

EAreport_notattach_desc:
facillity became zero surface water discharge during development/ all industrial wastewater and cooling tower blowdown reclaimed for treatment and then used as cooling tower make-up.


EAreport_notattach_desc:
Final results transmitted by John Dunn with EPA Region 7 to NDEQ directly.


elec_other_desc:
EPC is under contract to place all net electricity generated on the grid and is bought by the utility.  The utility then handles the distribution and sale of the power.

steam_use_other_desc:
Station steam is sold to a nearby state hospital for heat, cooling & cooking


steam_use_other_desc:
Steam is sold to adjacent paper mill for it's processes.

EAreport_notattach_desc:
The studies are to voluminous to include.


steam_use_other_desc:
Export steam to two industrial customers based on 2010 YTD heat input allocation.  2009 Not typical due to flood recovery from June 2008 flood event.


EAreport_notattach_desc:
Study was for new barge unloader and did not address any impacts on water quality.


steam_use_other_desc:
ZLD Wastewater Treatment, Brine Concentrator Startup Steam & Drum Dryer Operation


elec_other_desc:
sold to Long island Power Authority as part of a long term power purchase agereement (PPA)

steam_use_other_desc:
steam is generated by an HRSG heat input from a CT.  Majority of steam is sent to an extraction turbine then a portion is extracted for thermal purposes (steam/HTHW/chilled water)


EAreport_notattach_desc:
The 1976 report only discussed water quality of the river in general terms.


elec_other_desc:
The owner of the unit, Southern Company dba Alabama Power, distributes the electricity for sale on the grid.


steam_use_other_desc:
Process steam and hot water for 4 customers


elec_other_desc:
Electric energy furnished without charge to Parent/City of Hamilton (i.e., city street lights, etc.)


steam_use_other_desc:
PURPA QF steam usage in distilled water plant


EAreport_notattach_desc:
1973 Environmental Assessment very minimal discussion of  water impacts as  plant is zero liquid discharge facility


steam_use_other_desc:
Auxiliary Steam for water processing & heating the power plant.


EAreport_notattach_desc:
An electronic version of the report is provided.


steam_use_other_desc:
Steam injection (IP) into the combustion gas turbine for Nox control.


steam_use_other_desc:
Steam is supplied to #9 Combustion turbine for starting and plant whistle.  Very little use.


steam_use_other_desc:
Commercial Process Steam Sold to Customer


steam_use_other_desc:
Steam is sold to a third party for process use.


steam_use_other_desc:
1.9% of process steam is used annually to heat an onsite green house.


steam_use_other_desc:
This facility is a cogen facility and steam is extracted from the turbines for steam sales and building heating.


elec_other_desc:
All power generated is sold to MEAM our joint action agency at fuel cost +10% O&M coal and +5% O&M gas. MEAM will bill us for all power purchased from them. If dispatched by Entergy then we would sell to MEAM (at fuel + O&M) and they would bill Entergy. We are a non-profit organization.

prime_purpose_desc:
Provide power to Entergy or MEAM when dispatched under current contract. Only time we would generate for our customers would be during transmission outages or potential outages. Revenue is generated by capacity sold to MEAM.


steam_use_other_desc:
Less than 1% of steam generated is used for building heat.


steam_use_other_desc:
Steam is sent to an adjacent industry for process operations


steam_use_other_desc:
Cogeneration: export 70pph to thermal hosts


EAreport_notattach_desc:
The US Army Corps conducted the original (1976) EIS for Nearman prior to construction. It is not attached because of its age but is available on request.


steam_use_other_desc:
0.01% of steam is sent to an adjoining industry. The box above does not allow me to enter anything other than 0% or 1%, so I entered 0%


elec_other_desc:
On-site use is needed for Auxillary and Ancillary Components.  The 94.4% represents the "net" electricity generated from units.

steam_use_other_desc:
Steam heat is used for plant heat (of building) only.


steam_use_other_desc:
CPI USA North Carolina - Southport Plant is a co-generation facility, that sends steam to their host, Archer Daniels Midland.


EAreport_notattach_desc:
An EIS is believed to have been produced in the 1970's, however no report could be found in company files.


EAreport_notattach_desc:
The EA did not address any water quality issues.


EAreport_notattach_desc:
Results previously submitted for permit ammendment


steam_use_other_desc:
Continous blow down-1.0 summer, 0.8 % winter. Sootblowing: 0.45 (summer) 0.65% (winter).


steam_use_other_desc:
We have two process steam customer and 113 district heating customers that we sell steam to.


EAreport_notattach_desc:
The EIS study for Big Bend Unit 4 is voluminous and was submitted to EPA previously with approval by Region IV Administrator Charles R. Jeter on January 22, 1982.


steam_use_other_desc:
Steam air injectors use steam on the condenser; and, on Unit 1 steam is used to reheat the gas going up the stack.


EAreport_notattach_desc:
EIS can be found at http://psc.wi.gov/apps35/erf_search/default.aspx - search under docket # 6690-CE-187.


elec_other_desc:
Goes to Dupont as process steam for their manufacturing operation

steam_use_other_desc:
Goes to Dupont as process steam for their manufacturing operation.


EAreport_notattach_desc:
CWA 316(a) and (b) studies are ongoing and no reports are available at this time.


# Plant_Outfalls

oufall_name:
Unit 1 Cooling Tower Emergency Overflows to Storm Drains


oufall_name:
Unit 2 Cooling Tower Emergency Overflows to Storm Drains


oufall_name:
Miscellaneous low volume wastes discharged to the ash pond


oufall_name:
Southwest stormwater retention pond discharge, including car wash wastewater


oufall_name:
Southeast stormwater retention pond discharge


oufall_name:
Northwest stormwater retention pond discharge including gypsum storage transfer runoff


oufall_name:
Boiler blow down and floor drains to cooling tower collecting basin


oufall_name:
Discharge from concrete treatment basins


oufall_name:
Outfall 001 Discharge from Main Condensor 2 Pump Operation


oufall_name:
Combined cooling tower blowdown and low volume waste


oufall_name:
Sewage Treatment Plant Emergency Overflow


oufall_name:
Drains from oil handling areas-retired Units 1-5 & Units 1,2,6, & 7.


oufall_name:
Outfall 004 RO Reject and Boiler Blowdown Wastestreams


oufall_name:
DSN008 Intake Screen Washwater Discharge


oufall_name:
DSN013 FRS Sedimentation Basin 2 Emergency Overflow


surfwater_name:
do not discharge to waters of the State. -see Comments


oufall_name:
Sample Point 107 - Heat Recovery Steam Generator #21 Blowdown


oufall_name:
Sample Point 108 - Heat Recovery Steam Generator #22 Blowdown


oufall_name:
Cooling Tower Overflows for Units 1,2,3,4 (Etowah River)


oufall_name:
401 South Pipe Unit #3 Condenser Non-Contact Cooling


oufall_name:
Stormwater from Marine Fuel Pier Unloading Area


oufall_name:
Once Thru Non Contact Condensate Cooling


oufall_name:
Outfall 001 - Condenser Cooling Water and Other Minor Flows


oufall_name:
Outfall 002 - Alternative Condenser Cooling Water Outfall for Intake Deicing


oufall_name:
Outfall 003 - Coal Pile Runoff Treatment System Effluent


oufall_name:
Sample Point 103 - Boiler Makeup Water Treatment System Wastewater


oufall_name:
Sample Point 105 - Heat Recovery Steam Generator #11 Blowdown


oufall_name:
Sample Point 106 - Heat Recovery Steam Generator #12 Blowdown


oufall_name:
501 Unit #3 Heat Exchangers Non-Contact Cooling


oufall_name:
002-Discharge from the Evaporation Pond to Sutherland Reservoir


oufall_name:
L01-Internal Outfall for Discharge of Reverse Osmosis Reject Water


oufall_name:
Sample Point 110 - Block 2 Oil/Water Separator Discharge


oufall_name:
Sample Point 111 - Block 1 Oil/Water Separator Discharge


oufall_name:
Cooling Tower Blowdowns for Units 1,2,3,4 (Etowah River)


oufall_name:
004 Industrial Wastewater Treatment Plant


oufall_name:
005 Sewage Treatment Outfall Sanitary Wastewater


oufall_name:
Non-contact condenser cooling water discharge


oufall_name:
001-Discharge from the Cooling Pond to Sutherland Reservoir


oufall_name:
DSN 006A - Unit 7 and Unit 8 Cooling Towers


oufall_name:
Outfall 001 - Industrial Wastewater and Storm Water


oufall_name:
Outfall 901 - Emergency Storm Water Overflow

surfwater_type_other:
This is the same as Outfall 001, except as a overflow of the pond.


oufall_name:
Sanitary wastewater treatment plant discharge


oufall_name:
Outfall 002  (Secondary Discharge Outfall AZPDES Permit No. AZ0024791)


oufall_name:
stormwater from electriccal control room roof drains and yard areas (inlcudes parking lot).


oufall_name:
Stormwater discharged from electrical equipment areas and Unit 5 transformer pit drains


oufall_name:
Sanitary Waste Only to Groundwater via cesspools


oufall_name:
107 - Metal Cleaning and Stormwater to Outfall 103


surfwater_name:
Greens Bayou Above Tidal Segment No. 1016


oufall_name:
Once through cooling water for the two combustion turbine generator (CTG) unit's lube oil cooling systems combined with the CTG's sandfilter backwash water.


oufall_name:
Once through condenser cooling water for Unt 3 steam turbine generator combined with Unit 3's sandfilter backwash water and the hydrogen booster pumps cooling water from April 15 to October 31 (defined as summer period).


oufall_name:
Combustion turbine compressor cooling water


oufall_name:
Condenser Cooling Water- Outfall Pumps Discharge


oufall_name:
Units 10/9 Condenser and non-contact cooling, evaporator and boiler blowdown


oufall_name:
Unit 11 Condenser and non-contact cooling, evaporator and boiler blowdown


oufall_name:
Seal Pit and Unit 3 Noncontact Cooling Water


oufall_name:
Demineralizer Rinses, roof & Road Drains


oufall_name:
Total Facility Process Discharge including Internal Outfalls 003 and 004


oufall_name:
Outfall 101 - Boiler Blowdown (Low Volume Waste)


oufall_name:
Outfall102 Oil-Water Separator (Low Volume Waste)


oufall_name:
Outfall 001 Discharge of Once Pass Through Cooling Water


oufall_name:
Condenser cooling water and house service water


oufall_name:
Storm Runoff from concrete unloading ramp


oufall_name:
Storm runoff from screen house roof and nearby paved area


oufall_name:
Flue Gas Desulfurization Sludge Disposal Area Settling Pond #3


oufall_name:
Flue Gas Desulfurization Sludge Disposal Area Settling Pond #2


oufall_name:
Cooling Tower Blowdown from Recirculated Cooling Water through Unit 5 to the Ash Pond


oufall_name:
Outfall 003 Hydrostatic Test Waters [Comment 1]


surfwater_name:
Parish Ditch Henceforth to Bayou Segnette


oufall_name:
Once-Through Cooling & Auxiliary Cooling Water, PME


oufall_name:
Low Volume Waste, Metal Cleaning Waste, & Storm Water


oufall_name:
Intakes screen trash basket overflow for Units 1,2,6 & 7


oufall_name:
Intakes Cleaning Wastewater for Units 1,2,6, & 7


oufall_name:
Intakes Heat Treatment to Normal Operations


oufall_name:
Intakes yard drain and stormwater runoff for Units 1,2,6, & 7


oufall_name:
Condensate tank overflows and building emergency dewatering pump


surfwater_name:
Strait of Georgia via ConocoPhillip's discharge outfall 001


oufall_name:
Demineralizer Regenerant Waste and Filter Backwash


oufall_name:
Boiler Blowdown (Units 1&2) & Package Boiler


surfwater_name:
40 Arpent Canal Henceforth to Lac Des Allemands


oufall_name:
Ash Transport Water and Low Volume Waste Discharge


oufall_name:
Stormwater Runoff from Coal Delivery Rail Lines and Ash Byproduct Storage Areas


oufall_name:
Units 1&2 Building Sump Emergency Discharge


oufall_name:
Incidental Waste Treatment Basin final effluent


oufall_name:
Sewage treatment facility final effluent


oufall_name:
Ash Basin No. 6 polishing pond final effluent


surfwater_name:
Intermittent Branch of Pawnee Creek (Also intermittent)


surfwater_name:
West Fork of the Big Blue River (Intermittent Stream 100% Wastewater dominated stream from Pollution Control Facilities WWTP and Chief Ethanol Fuels sewage disposal)

surfwater_type_other:
Intermittent creek that is effluent dominated by wastewater discharges as noted above.


oufall_name:
Flue Gas Desulfurization Disposal Area Settling Pond #1


oufall_name:
Cooling Water Diversion System (Units 1-2)


oufall_name:
Cooling Water Diversion System (Units 3-4)


oufall_name:
Ash pond discharge including cooling tower blowdown, sanitary wastewater, metal cleaning wastess, low volume wastes and coal pile runoff


oufall_name:
Stormwater runoff associated with industrial activity


oufall_name:
Cooling tower blowdown from towers 1, 2, and 3


oufall_name:
Industrial waste treatment (Coal pile desilting basins, roof drains, parking lot drins, water treatment plant wastes, tower drains


oufall_name:
Northeast stormwater retention pond discharge


oufall_name:
Uncontaminated stormwater runoff from plant landfill


oufall_name:
Condenser Cooling Water and House Service Water


surfwater_name:
ditch to Portage Bayou (Little River Ditches)


oufall_name:
Ash pond consisting of low volume wastes, DSN02A, DSN02B, DSN02C, ash transport wastes, car wash, and stormwater including coal pile runoff


oufall_name:
Cooling tower blowdown from the Carbon Capture process


oufall_name:
Stormwater runoff associated with electric power generation


oufall_name:
Condenser Cooling Water from Units 7 & 8


oufall_name:
Condenser Cooling Water from Units 4, 5, and 6


oufall_name:
Effluent from Metal Cleaning Waste Treatment Basin


oufall_name:
Intake Screen Backwash Discharge (Unit 7)


oufall_name:
Intake Screen Backwash Discharge (Unit 8)


oufall_name:
Intake Screen Backwash Discharge (Units 3 & 4)


oufall_name:
metal cleaning waste, FGD system wastewater, bottom ash contact water, & stormwater


surfwater_name:
40 Arpent Canal Henceforth Lac Des Allemands


oufall_name:
Condenser Cooling Water Diversion Channel Overflow


oufall_name:
Condenser Cooling Water Supplemental Cooling Pond Overflow


oufall_name:
Condenser Cooling Water Supplemental Cooling Tower Discharge


oufall_name:
Raw Water Treatment and Demineralizer Regenerant Wastes


oufall_name:
Treated Sanitary Wastewater Internal Outfall to Outfall 001


oufall_name:
Low Volume Wastewater Internal Outfall to Outfall 001


oufall_name:
DSN002 AOG/NRW Heat Exchanger Non-Contact Cooling Water


oufall_name:
DSN004 Combined Low Volume Discharge (Non-Contact Cooling Water and Stormwater Runoff)


oufall_name:
DSN007 Dilution Pump Oil-Water Separator


oufall_name:
Water and Wastewater Treatment Plant Discharges into Circ. Water System Discharge


oufall_name:
Lime Sludge Pond Discharge to Wolf Creek Cooling Impoundment (Coffey County Lake)


oufall_name:
Circulating Water System Discharge into Wolf Creek Cooling Impoundment (Coffey County Lake)


oufall_name:
Discharge of Radiation Waste and Steam Generator Blowdown into Circulating Water


oufall_name:
Floor Drain to Outfall 001 Sampling Point


oufall_name:
Unit 1&2 Once Through Condenser Cooling Water


oufall_name:
Outfall 009 - Coal Pile Runoff Basin J. P. Madgett


oufall_name:
Combined Wastewaters of the Ash Pond Overflow


oufall_name:
Coal Pile Runoff Pond Emergency Overflow


oufall_name:
102 Emergency Overflow from Grit Chamber


oufall_name:
Flue Gas Desulfurization Wastewater/Dewatering Emergency Bypass


oufall_name:
Low Volume Waste Pumping Station Overflow


oufall_name:
Stormwater Runoff south and east yard drains


oufall_name:
Ash pond discharge including sanitary wastewater, pretreated metal cleaning wastes, low volume wastes, coal pile runoff, and stormwater from fuel handling areas


oufall_name:
Stormwater from conbustion turbine fuel handling area


oufall_name:
Ash Sluice Water Recycle System Emergency Overflow


oufall_name:
CR Unit 1 Once Through Condenser Cooling Water


oufall_name:
CR Unit 2 Once Through Condenser Cooling Water


oufall_name:
Emergency Plant Waste Water Treatment Pond Overflow


oufall_name:
Unit #7 and Unit #8 Boiler Blowdown and Boiler Drain


oufall_name:
Recirculating Wastewater Treatment System Blowdown


oufall_name:
Once-Through Cooling Water (Units 5 & 6)


oufall_name:
Once-Through Cooling Water (Units 3 & 4)


oufall_name:
Once-Through Cooling Water (Units 1 & 2 (retired))


oufall_name:
Groundwater underdrain from W. Valley Equalization Pond


oufall_name:
007 screen backwash from EM Unit 5 Pumphouse No. 3


oufall_name:
008 Reject water from the Hay Road reverse osmosis water treatment units used as makeup water for the Hay Road Unit 4 cooling tower (requested this outfall be removed)


oufall_name:
SWRO from Unit #1 Yard Drains, Groundwater Infiltration, Low Volume Wastes and Fire Deluge Drainage


oufall_name:
SWRO, Acid Mine Drainage From 2 Abandoned Deep Mine Entries and Groundwater Infiltration


oufall_name:
Intake Screen Backwash Units 1&2 - Stormwater


oufall_name:
Plant Equipment Non-contact Cooling Water


oufall_name:
001b Copper Pond Effluent (Chem Cleaning)


oufall_name:
001c Iron Pond Effluent (Ammonia Deluge)


oufall_name:
002 Condenser Cooling Water Discharge Channel


oufall_name:
Intake Screen Backwash Discharge (Unit 4)


oufall_name:
Ash disposal site treatment plant effluent (Leachate collection surge pond effluent, and area stormwater runoff)


oufall_name:
Units 1 and 2 sewage treatment plant effluent


oufall_name:
Stormwater runoff from the north and south areas of the Unit 3 FGD scrubber area


oufall_name:
Coal pile desilting basin #1 overflow from 10 year-24 hour storm


oufall_name:
Coal pile desilting basin #2 overflow from 10 year-24 your storm


oufall_name:
Ash disposal area diversion ditch storm water runoff


oufall_name:
Final Settling Pond No. 3 overflow handling river intake dredging pond effluent


oufall_name:
Emergency overflow from IWT equalization pond No. 2


oufall_name:
Overflow from cooling tower clarifier wet well


oufall_name:
Sanitary Lagoon Discharge to the Missouri River


oufall_name:
Internal Dischare of Coal Pile Run-off Pond to Bottom Ash Pond


oufall_name:
Condenser Cooling Water, Auxillary Non-Contact Cooling Water and Circulating Water pump Seal Water


oufall_name:
Stormwater runoff from administrative building and parking lot


surfwater_name:
Unnamed channel owned by Campbell Estates


oufall_name:
022 Stormwater run-off from retired EM Units 1 and 2


oufall_name:
SWRO, acid mine drainage, and ground water infiltration


oufall_name:
SWRO, R&P Coal Co. Mining Ops and RO from E. Valley Ash Haul Road


oufall_name:
SWRO from vegetated area adj. to cooling towers 2A & 2B


oufall_name:
SWRO and sources prev. monitored at IMP 107


oufall_name:
Ash recycle clearwell overflow handling ash transport water, sludges from various clarifiers, west side yard drainage and ash silo wash water


oufall_name:
Outfall 003 - Unit 5 OCPP Condenser Cooling Water


oufall_name:
Outfall 004 - Unit 6 OCPP Condenser Cooling Water


oufall_name:
Outfall 005 - Unit 7 OCPP Condenser Cooling Water


surfwater_name:
City warm water ditch or storm sewer ditch

surfwater_unnamed_desc:
The receiving surface water is a city warm water/storm sewer ditch, which feeds 10-12 miles down to the Rawhide creek. The Rawhide creek is a part of the Elkhorn River Basin.


oufall_name:
Roof Drains, Floor Drains & Drinking water


oufall_name:
Stormwater Run-off & Coal Conveyer Fire Protection System Drains


oufall_name:
Outfall 006 - Unit 8 OCPP Condenser Cooling Water


oufall_name:
CCP Stackout Pad contact storm runoff pond


oufall_name:
FGD Landfill Interim Leachate Collection Pond


oufall_name:
Temporary Coal Combustion Products Storage Area noncontact stormwater runoff treatment pond


oufall_name:
Outfall 007 - OCPP Treatment System Effluent


oufall_name:
Sample Point 103 - Unit 5 OCPP Flyash Hydrovactor


oufall_name:
Outfall 002A - Units 1-4 Non-Contact Cooling Water


oufall_name:
Low Volume Waste Sump Emergency Overflow - Stormwater


oufall_name:
Intake Screen Backwash and River Pump Strainer Discharge (Units 6 and 7)


oufall_name:
01E-Combined Waste Treatment Pond Discharge


oufall_name:
Once-through condenser cooling water, Units 6 & &, discharge to Bakers Creek.


oufall_name:
Ash pond discharge including sanitary wastewater, pretreated metal cleaning wastes, and coal pile runoff


oufall_name:
Emergency cooling water overflow. Unit 1 cooling tower.


oufall_name:
Emergency cooling water overflow. Unit 2 cooling tower.


oufall_name:
Emergency overflow from coal processing holding pond.


oufall_name:
Limestone Pile Runoff Basin - Treated Discharge


oufall_name:
Coal Pile Runoff Basin - Treated Discharge


oufall_name:
Intake Structuure Traveling Screen Backwash


oufall_name:
Two Cell Domestic Wasterwater Stabilization Pond Discharge to the Slough


oufall_name:
Oil Water Separator Discharge Over Weir into Culvert


surfwater_name:
No receiving surface water near the area

surfwater_unnamed_desc:
No receiving water near the surrounding area. The nearby receiving water is 10 miles away.


oufall_name:
001- Combined wastewater discharge cooling tower blowdown, boiler blowdown, demineralizer backwash and stormwater runoff


oufall_name:
001 Wastes from 101-701 Main Station Discharge


oufall_name:
Intake Screen Backwash, Fire Pump Bypass, and Circulatinf Water Pump Bearing Wash Water


oufall_name:
Water Treatment Plant Waste Water Basin for Units 10 and 11


oufall_name:
Construction Runoff Settling Pond Discharge


oufall_name:
Intake Screen Backwash Discharge (Unit 5)


oufall_name:
Intake Screen Backwash Discharge (Unit 6)


oufall_name:
Temporary Coal Combustion Products Storage Area Treatment Pond


oufall_name:
Service and Essential Service Water System Discharge through Essential Service Water Piping into the Ultimate Heat Sink Area of WCCI


oufall_name:
Cooling Impoundment Discharge to Wolf Creek


oufall_name:
003 Storm Water Runoff from Access Road combined with Sewage Treatment Plant Effluent


surfwater_name:
Johnson Creek, thence to Lake O' the Pines in Segment


oufall_name:
Once through cooling water condenser cooling


oufall_name:
Outfall 001 - Unit 1 Condenser Cooling Water Discharge

surfwater_name:
South Menomonee Canal of the Menomonee River


oufall_name:
Outfall 002 - Unit 2 Condenser Cooling Water Discharge


oufall_name:
Sample Point 101 - Wastewater Treatment System Effluent


oufall_name:
Sample Point 104 - Unit 6 OCPP Flyash Hydrovactor


oufall_name:
Storm water runoff  east and central yard drains


oufall_name:
Stormwater Runoff north side of material storage area & roof drains


oufall_name:
Stormwater Runoff  south side of material storage area


oufall_name:
Outfall 007 (Storm Water Runoff Discharged into Balck creek from Solid Waste Landfill)


oufall_name:
storm water run off rec.area and haul road


oufall_name:
Storm water run off main plant area and parking lots


oufall_name:
Storm water run off from southwest yard between switchyard and plant


oufall_name:
Storm water run off from the area between the tributary to Clifty Creek and the recreation area


oufall_name:
storm water run off from the switchyard area


oufall_name:
Emergency Overflow of Bottom Ash Transport Water & Bottom Ash Hopper and Seal Trough Overflow


oufall_name:
Low Volume Wastewater Treatment System, Non-chemical Metal Cleaning Wastes


oufall_name:
Bottom Ash Transport Water and Bottom Ash Hopper and Seal Trough Overflow


oufall_name:
Old Ash Disposal Site Wetlands Discharge


oufall_name:
Intake Screen Backwash from Crooked Creek


oufall_name:
Outfall 002B - Treatment System Effluent


oufall_name:
Outfall 001 - Neal 1 & 2 Once through non-contact cooling water


oufall_name:
Cooling Tower Blowdown, FGD Waste Water Treatment, and Lake Water combined


oufall_name:
005 screen backwash from retired EM Units 1& 2 and strainer backwash Pumphouse No. 1


oufall_name:
On-site drainage ditch conveyance structure


oufall_name:
Stormwater runoff associated with industrial activity including landfill runoff and gypsum storage runoff


oufall_name:
Stormwater runoff associated with industrial activity and cooling tower A coldwater basin blowdown overflow


oufall_name:
Once-through cooling water to the Great Miami River


oufall_name:
Ash pond pressure filter discharge to the Great Miami River


oufall_name:
Storm water discharge to Great Miami River


oufall_name:
Sanitary treatment plant discharge to the Great Miami River


oufall_name:
Emergency Overflow South Coal Pile Collection Basin


oufall_name:
Ash Disposal Site Sedimetation Pond Discharge


oufall_name:
Ash Diposal Site Subdrain - Groundwater Intercept


surfwater_name:
Clinch River (via Condenser Cooling Water Channel)


oufall_name:
003 - Low volume waste discharge and storm water runoff


oufall_name:
004 - Low volume waste discharge from pump house


surfwater_type_other:
Cooling Water Pond operated by Jackson County Port Authority


surfwater_type_other:
Cooling Water Pond Operated by Jackson County Port Authority


oufall_name:
Treated Coal Pile Runoff to Stormwater Detention Basin B


oufall_name:
Sewerage from Extended Aeration Package Plants


oufall_name:
Uncontaminated Storm Water Runoff from CCB Landfill Site


oufall_name:
Final Plant Discharge: Combined discharge of outfalls 01A,01B,01C,01D,and 01E to the Ocmulgee River


oufall_name:
Cooling Tower Blowdown for Units 1,2,3, and 4


oufall_name:
Ash Transport Bleedoff (includes 03E Wastewater Basins Units 1,2,3 and 4, Low Volume Waste


oufall_name:
Unit 3 Cooling Tower Overflows/Basin Drains


oufall_name:
Condenser Colling Water (Units 1, 2, and 3)


oufall_name:
Ash Transport Water & Metal Cleaning Waste


oufall_name:
Storm Water Runoff, Low Volume Waste, & PME


oufall_name:
Outfall 008 Air Heater Wash Pond Discharge


oufall_name:
Outfall 009 Air Heater Internal Discharge


surfwater_type_other:
Small polluted creek with previously exisiting acid mine drainage


oufall_name:
W3&4 Sample Point 112 -Treated Coal Pile Runoff


oufall_name:
W3&4 Sample Point 103 -Bottom Ash Sluice Water


oufall_name:
W3&4 Sample Point 102-Metal Treatment Wastewater


oufall_name:
W3&4 Sample Point 104-Cooling Tower Blowdown 3


oufall_name:
001and 001A - Condenser Cooling Water and Service Water Systems


oufall_name:
01E - Liquid Waste Treatment System Effluent


oufall_name:
Stormwater Runoff from South Area of FGD Landfill


oufall_name:
Stromwater Runoff from the East and North Areas of the FGD Landfill


oufall_name:
Drain and Overflow of Unit 2 Cooling Tower Basin


oufall_name:
Storm Water Runoff & Emergency Overflow South Coal Pile Detention Basin


oufall_name:
Storm Water Runoff - Station Drainage Area D


oufall_name:
Closed Ash Disposal Site South & North Sed. Pond Combined Discharge


oufall_name:
Cooling Tower Basin Overflows and Drains to Storm Drains, Unit 1


oufall_name:
Ash Pond C Emergency Overflow - Stormwater


oufall_name:
Ash Pond E Emergency Overflow - Stormwater


oufall_name:
Ash Pond B Emergency Overflow - Stormwater


oufall_name:
Low Volume Collection Sumps Emergency Overflow - Stormwater


oufall_name:
Unit 2 Intake pump pit Lake water storage tanks


surfwater_name:
Middle Fork of the Little Chariton River


oufall_name:
Low volume wastes and general service water


oufall_name:
Settling Basins, Filtration, and Backwash


oufall_name:
001-PA0063606 Stormwater Ash Leachate Pond


oufall_name:
Outfall 002-Process Water to Wisconsin River


oufall_name:
W3&4 Outfall 005- Noncontact Cooling Water to Wisconsin River


oufall_name:
W1&2 Sample Point 110- Unit 1 Condenser Cooling Water


oufall_name:
W1&2 Sample Point 111- Unit 2 Condenser Cooling Water


oufall_name:
W1&2 Outfall 001- Cooling Water to Wisconsin River


oufall_name:
Intake Deicing Water (Untreated Cooling Tower Blowdown)


oufall_name:
Untreated Cold Side Cooling Tower Blowdown


oufall_name:
Emergency Overflow - Condenser Pit Drains


oufall_name:
Demineralizer Regeneration Batch Neutralization Effluent


oufall_name:
Emergency Overflow - Final Settling Yard Pond


oufall_name:
Emergency Overflow Bottom Ash Filter Beds


oufall_name:
Discharge from Ash Disposal Site Sedimentation Pond


oufall_name:
Emergency Overflow from Ash Disposal Site


oufall_name:
Building Sump Emergency Bypass - Units 1&2


oufall_name:
Ash Pond 1 Emergency Overflow - Stormwater


oufall_name:
Unit 3 Once Through Noncontact Service Water Strainer Backwash


oufall_name:
Unit 3 Main Turbine Lube Oil Once Through Noncontact Cooling Water


oufall_name:
Unit 3 I.D. Fan Bearing Once Through Noncontact Cooling Water - Stormwater


oufall_name:
Ash Pond No. 2 Emergency Overflow - Stormwater


oufall_name:
Once-through condenser cooling water, Units 1 & 2


oufall_name:
Once-through condenser cooling water, Units 3 & 4


oufall_name:
Cooling tower blowdown (Unit 5) discharged to ash pond


oufall_name:
Ash pond discharge including cooling tower blowdown, sanitary wastewater, pretreated metal cleaning wastes, low volume wastewater, coal pile runoff and stormwater


oufall_name:
Intake screen backwash, backwash bypass, and storm water runoff


oufall_name:
Stormwater runoff associated with industrial activity including car rinse water


oufall_name:
Chemical Cleaning Wastes from Units G-1 & G-2


oufall_name:
Deep mine dewatering treatment plant (002)


oufall_name:
Treated bottom ash transport water (203&303)


oufall_name:
Drain and Overflow of Unit 1 Cooling Tower Basin


oufall_name:
Main sanitary wastewater treatment plant


oufall_name:
Sample Point 105 - Metal Cleaning Wastewater


oufall_name:
Outfall 003 - Coal Pile Runoff Basin Overflow


oufall_name:
McDonough Intake Building Sump Emergency Discharge


oufall_name:
001A Units 1, 2, 3, & 4 Circ. Cond. Cool


oufall_name:
Storm Water From Rail Car Unloading and Ash Pond Berm.


oufall_name:
Leachate Drainage, Truck Wash & Road Runoff Sumps, Sealed Spring, Storm Water - 001

surfwater_unnamed_desc:
Receiving H2O #1: Unnamed Tributary (River/Stream)
Receiving H2O #2: Monongahela River


oufall_name:
Emergency Overflow from Combined Drain Sump


oufall_name:
005 Aux. Coal Pile Sump Emergency Overflow


oufall_name:
101 Metal Cleaning Waste (Boiler Chemical Clean Waste)


oufall_name:
103 Coal Pile Runoff Sump Emergency Overflow


oufall_name:
Treated  Coal Pile Runoff, Maintenance Cleaning Wastewater, and Boiler Chemical Cleaning Waste


oufall_name:
Unit 1A & 1B Cooling Tower Blowdown/Overflow


oufall_name:
Unit 2A & 2B Cooling Tower Blowdown/Overflow


oufall_name:
Ash Haul Rd Sed Removal Facility 1 Emergency Overflow


oufall_name:
Ash Haul Rd Sed Removal Facility 2 Emergency Overflow


oufall_name:
Phase 3 CCB Landfill LSI + Ash Haul Road Sed. Removal Facilities


oufall_name:
Stormwater- not associated with a regulated industrial activity (northwest contractor parking area & road ditch)


oufall_name:
Stormwater- area containing a section of the ash haul road (intersection of Hornsbyville and Waterview Roads)


oufall_name:
Ash Disposal Site - Combined Outfall Pipe to Allegheny River


oufall_name:
Emergency Spillway - Ash Sedimentation Pond


oufall_name:
Storm Water Runoff - Station Drainage Area C


oufall_name:
Emergency Overflow North Coal Pile Collection Basin


oufall_name:
Combined wastewaters of the old ash pond overflow


oufall_name:
Once-through cooling waters, pump seal drains, Ford area runoff, and boiler blowdown


oufall_name:
Combined wastewaters of the new ash pond overflow


oufall_name:
Storm water runoff from parking lot and roof drains at manhole N-13


oufall_name:
Ash site surge pond 10 year-24 hour storm water emergency overflow


oufall_name:
Make-up clarifier areas stormwater runoff to Cherry Run


oufall_name:
Storm water runoff by Power Plant Road at the bottom of King's Hill


oufall_name:
Storm water runoff from coal truck gate entrance area and dust control water runoff


oufall_name:
Storm water runoff at Power Plant Road by ash recycle overflow


oufall_name:
Storm water runoff from industrial waste treatment area


oufall_name:
Storm water runoff from Units #1 and #2 cooling tower area and internal outfalls 126 and 226


oufall_name:
Flue gas desulfurization wastewater treatment plant


oufall_name:
015 Intake screen backwash from the pumphouse for Hay Rd.'s cooling tower make-up water


oufall_name:
Ash Pond Emergency Overflow - Stormwater


oufall_name:
Cooling Tower Blowdowns/Overflows for Units 6


oufall_name:
Cooling Tower Blowdowns/Overflows for Unit 7


oufall_name:
Units 1 through 5 Cooling Tower Emergency Overflow


oufall_name:
Dewatering Discharge from Around the Bottom Ash Pond


oufall_name:
Intake Screen Backwash Water and Circulating Water Pump Bearing Wash Water


oufall_name:
Outfall 009 Neal 3 Once through non-contact cooling water


oufall_name:
Helper Cooling Tower Intake Screen Wash Water


oufall_name:
Storm Water Runoff Station Drainage Area B & Emergency Overflow North Coal Pile Collection Basin


oufall_name:
Industrial Wastewater Treatment Plant Discharge


oufall_name:
L02-Internal Outfall for Discharge of Zeolite Softner Reject Water


oufall_name:
003-Discharge from Coal Pile Settling Pond


oufall_name:
Coal handling sanitary wastewater treatment plant


oufall_name:
Stormwater runoff from fan yard and area south of fan yard


oufall_name:
Stormwater runoff from crusher house area


oufall_name:
Transformer yard and roof drains, plus intake screen backwash


oufall_name:
Stormwater from central coal handling area


oufall_name:
111 South Pipe #1 Condenser Non-Contact Cooling


oufall_name:
121 North Pipe #1 Condenser Non-Contact Cooling


oufall_name:
801 South Pipe #2 Condenser Non-Contact Cooling


oufall_name:
901 North Pipe #2 Condenser Non-Contact Cooling


oufall_name:
301 North Pipe Unit #3 Condenser Non-Contact Cooling


oufall_name:
Service Rd. Drain Basin Emergency Overflow


oufall_name:
Ash Pond 3 Emergency Overflow (Smith Cabin Creek)


oufall_name:
Gypsum & Limestone Handling Area Sump Emergency Overflow


oufall_name:
Treated Low Volume Wastewater to Tributary of Fritz Creek


oufall_name:
Construction desilting basin and storm water runoff from south side unit #3


oufall_name:
Outfall 003A - Units 5 & 6 Non-Contact Cooling Water


oufall_name:
Outfall 004A - Units 7-9 Non-Contact Cooling Water


oufall_name:
Sample Point 105 - Unit 5 OCPP Bottom Ash Hydrovactor


oufall_name:
Sample Point 106 - Unit 6 OCPP Bottom Ash Hydrovactor


oufall_name:
CR Unit 3 Once-through condenser cooling water


oufall_name:
CR Unit 3 Nuclear Services & Decay Heat Non-contact cooling water


oufall_name:
CR Unit 3 Laundry Sump & Shower Tank (LSST)


surfwater_name:
BIG BLUE RIVER / SOUTH OF CRETE, NEBRASKA


oufall_name:
Outfall C01 Unit 1 Cooling Tower Blow Down


oufall_name:
Outfall C02 Unit 2 Cooling Tower Blow Down


oufall_name:
Outfall 001 (Units 1 & 2 Cooling & Units 3 & 4 Bearing Cooling Water)


oufall_name:
Outfall 004 (Cooling Tower Blowdown to ash pond)


oufall_name:
Condensate/Filtered Water/Potable Water Tank Overflows


oufall_name:
Emergency Overflow to Lake Juliette (Low Volume Wastes) from Units 1 and 2 Wastewater Basin


oufall_name:
Emergency Overflow to Lake Juliette (Low Volume Waste) fro Units 3 and 4 Wastewater Basin


oufall_name:
Cooling Tower Blowdowns/Cooling Tower Overflows


oufall_name:
Service Water Pump Building - Stormwater


oufall_name:
Bottom Ash Pond Discharge to the Missouri River


oufall_name:
Internal Discharge of Coal Pile Run-off Pond to Bottom Ash Pond


surfwater_name:
Unnamed tributary to little campaign creek


oufall_name:
Outfall 006 (Intermittent Waste Water from the Scrubber Suuply Pond)


oufall_name:
Stormwater runoff from emergency reclaim conveyor area


oufall_name:
Stormwater runoff from south coal handling area


oufall_name:
Recycle Wastewater Treatment System Blowdown


oufall_name:
Stormwater- not associated with a regulated industrial activity (refinery/YPS fenceline)


oufall_name:
Service Water Final Discharge to Lake Juliette


oufall_name:
Unit 1 Cooling Tower Overflow/Basin Drain to Lake Juliette


oufall_name:
Unit 2 Cooling Tower Overflow/Basin Drain to Lake Juliette


oufall_name:
Settling Pond Emergency Overflow to Lake Juliette (Ash Transport Water)


oufall_name:
Unit 6 Turbine Oil Cooler Cooling Water Outfall


oufall_name:
20% of Unit 6 Once-Through Cooling Water Outfall


oufall_name:
Landfill Discharge into Cooling Tower Basin


oufall_name:
Fuel Pile Runoff Sump Emergency Overflow - Stormwater


surfwater_name:
Unnamed Wet-Weather Tributary of Monongahela River


surfwater_name:
Unnamed wet-weather tributary to Monongahela River


oufall_name:
Emergency Overflow - Ash Valley Surge Pond


oufall_name:
Storm Water Run Off (SWRO) East Parking Lot


oufall_name:
Wabash River Combined Cycle Plant to Wabash River


oufall_name:
Metal Cleaning Treatment System Effluent


surfwater_name:
Mackinaw Creek (cut-off) to Illinois River


oufall_name:
Coal Pile Runoff Treatment System Effluent


oufall_name:
Stormwater- not associated with a regulated industrial activity (dredge spoils area)


oufall_name:
Stormwater from Service Road for Intake Cooling Water Pump


oufall_name:
Low Volume Wastewater and Any Discharges from Outfall 002 - Internal Outfall


oufall_name:
Sample Point 102 - FGD Blowdown (treated)


oufall_name:
Sample Point 103 - Low Volume Wastewater


oufall_name:
Pretreated metal cleaning wastes from combustion turbines


oufall_name:
Unit 4 Cooling Tower Overflow/Basin Drain


oufall_name:
Internal Discharge of Storm Water Pond to Bottom Ash Pond


oufall_name:
Units 3&4 Once Through Condenser Cooling Water


oufall_name:
Units 3&4 Building Sump Emergency Discharge


oufall_name:
Intake Screen Backwash Units 3&4 Stormwater


oufall_name:
Chemical Metal Cleaning Waste Treatment Effluent


oufall_name:
Chemical Metal Cleaning Waste Treatment System Effluent


oufall_name:
East Yard Runoff Collection Basin Overflow/Discharge


oufall_name:
Demineralizer Water (Off Specification Bypass)


oufall_name:
Unit 7 Demineralized Water Storage Tank Drain


oufall_name:
Old Ash Disposal Site Storm Water Runoff


oufall_name:
Storm water runoff/emergency overflows from limestone storage area


oufall_name:
042 Storm water runoff from Hay Road Units 5-8 Area


oufall_name:
Outfall 010 - Overflow from Coal Pile Runoff


oufall_name:
Water Treatment Plant Emergency Overflow


oufall_name:
Coal Pile Runoff Emergency Overflow - Stormwater


oufall_name:
Ash Transport Water, outfalls 606, 611, 612


surfwater_name:
Hamilton Hydraulic Canal to Great Miami River


oufall_name:
West Yard Runoff Treatment System Effluent


oufall_name:
East Yard Runoff Treatment System Emergency Overflow


oufall_name:
Condensate Storage Tank Emergency Overflow


oufall_name:
Combined wastewaters of ash pond, cooling tower waters, and metal cleaning wastes


oufall_name:
Batch chemical precipitation of metal cleaning wastes


oufall_name:
Stormwater runoff from substation and other plant areas


oufall_name:
Unit 1&2 Area Stormwater (head of discharge canal)


oufall_name:
Stormwater- Unit 3 area (head of discharge canal)


oufall_name:
Stormwater- Reboiler Building Parking Lot


oufall_name:
Stormwater discharge north of bottom ash pond


oufall_name:
cooling tower perimeter stormwater runoff


oufall_name:
Emergency Overflow - Coal Yard Truck Wash Sump


oufall_name:
FGD system wastewater, bottom ash contact water, and stormwater


oufall_name:
011 - Solid Waste Disposal Area (Lake Ontario Basin)


oufall_name:
Discharge from the wastewater treatment plant consisting of low volume wastewater, ash transport wastewater, coal pile runoff, and treated sanitary wastewater prior to commingling with the wastestreams from IMP 101 and 103. This is an internal monitoring point.


oufall_name:
Emergency Overflow - CPR Pond & Coal Yard STP


oufall_name:
SWRO -  Contractor parking, Limestone Conveyor Area & Rail Loop


oufall_name:
SWRO - Gyspum Haul Road, Embankment of Ash Ponds & Rail Loop


oufall_name:
SWRO - Vegetated Area SW of Coal Pile & Access Road


oufall_name:
Bottom Ash Sluice Water, Floor, Equipment, and Yard Drains


oufall_name:
Waste Treatment Facility Equalization Basin Emergency Bypass


oufall_name:
SWRO - FGD Bldg & Gypsum Storage Dome Areas


oufall_name:
SWRO - W. Substation Area & Access Roads


oufall_name:
SWRO - E. Substation Area and Access Roads


oufall_name:
SWRO - NE Wooded Areas, Access Roads & Railroad Areas


oufall_name:
SWRO - Intake Area (East) Access Road & Railroad Areas


oufall_name:
SWRO - Intake Area (Central) Access Road & Intake and WWT Buildings


oufall_name:
SWRO - Intake Area (S) Vegetated/Railroad Area


oufall_name:
SWRO - East Gypsum Railcar Staging Area & Equip Storage


oufall_name:
SWRO - South Gypsum Railcar Staging & Access Road Areas


oufall_name:
SWRO - Central Haul Road and Sediment Trap 1 Area


oufall_name:
Main Sewage Treatment Plant (Sanitary) Effluent


oufall_name:
Breaker House Sewage Treatment Plant (Sanitary) Effluent


surfwater_unnamed_desc:
Boggy Creek to Bever Creek to Wichita River to Red River (Segment 0214)


oufall_name:
Coal Pile Emergency Overflow - Stormwater


oufall_name:
Refuse Site Raw Water Basin Emergency Overflow Outfall 009


surfwater_unnamed_desc:
unnamed reclaimed lake, thence to an unnamed ditch, thence to Little Payne Creek


surfwater_unnamed_desc:
unnamed old mine cut to an unnamed reclaimed lake, thence to Little Payne Creek


oufall_name:
Once Through Cooling Water from Units 1-4 to Big Lake (Back Bay of Biloxi)


oufall_name:
Ash Pond Treatment for Ash Transport Wastewater from Units 4 and 5


oufall_name:
Screen Wash and Service Water Tank Overflow 005


oufall_name:
Storm Water Long term Fuel Storage North West


oufall_name:
Stormwater- not associated with a regulated industrial activity (Old Craft Parking Lot & Road ditch NW of 001)


oufall_name:
Outfall 008 - Coal Pile Runoff Basin Alma 1-5


oufall_name:
Boiler Blowdown Internal Monitoring Point -102


oufall_name:
Boiler Blowdown Internal Monitoring Point-104


oufall_name:
Landfill Runoff and Vacuum Pump Compressant Water


oufall_name:
Landfill Stormwater Runoff and Groundwater


oufall_name:
Stormwater runoff and water tower blowdown


oufall_name:
Unit 1 and 2 cooling tower blowdown prior to commingling with the wastestreams from IMP 102 and 103. This is an internal monitoring point.


oufall_name:
Plant Drains, Coal Pile and West Area Basin Emergency Overflow-Stormwater


oufall_name:
W3&4 Sample Point 105-Cooling Tower Blowdown 4


oufall_name:
W3&4 Sample Point 106- Tower Blowdown Total


oufall_name:
012A - Solid Waste Disposal Area I and II - Somerset Basin


oufall_name:
Stormwater Runoff from H-1 H-2 Plant Area, Cooling Tower, and Scrubber


oufall_name:
Chemical Cleaning Wastes from Units R-1, H-1 & H-2


oufall_name:
Adair Run Landfill Access Road Stormwater Runoff Outfall


oufall_name:
Landfill Lateral Expansion Cap Storamwater Runoff Outfall


oufall_name:
Combined Thermal Discharge from Outfalls 001, 002, and 003 Outfall


oufall_name:
Cooling tower blowdown from Units 3 and 4 prior to commingling with the wastestreams from IMP 102 and 101. This is an internal monitoring point.


oufall_name:
Wastewater from the bottom ash pond, withdrawn on an emergency basis for cooling water makeup to Units 3 and 4 cooling towers. This is an internal monitoring point.


oufall_name:
Discharge from the lake pump strainer backwash to the Verdigris River. This is an external outfall.


oufall_name:
Combined discharges of IMP 101, 102, 103, and 104. This is an external outfall.


oufall_name:
Cooling Tower Basin Overflows and Drains to Storm Drains, Unit 2


oufall_name:
Low Volume Wastes (Liquid Radwaste System), Unit 1


oufall_name:
Low Volume Wastes (Liquid Radwaste System), Unit 2


oufall_name:
Low Volume Wastes (Pressure Filter Backwash)


oufall_name:
Blowdown and Draining of Water from Chiller Systems to Storm Drains


oufall_name:
012 - Solid Waste Disposal Area I and II - Somerset Basin


oufall_name:
Unit 5 Once-Through Cooling Water Outfall


oufall_name:
80% of Unit 6 Once-Through Cooling Water Outfall


oufall_name:
Outfall 002 - Green Bay Intake Deice Water


oufall_name:
Outfall 003 - Fox River Intake Deice Water


oufall_name:
SWRO - Southern Haul Road and Sediment Trap 2 Area


oufall_name:
SWRO - Eastern Borrow and Access Road Areas


oufall_name:
SWRO - Western Borrow and Access Road Areas


oufall_name:
Emergency overflow of N. Ash Disp. Site surge/settling pond


oufall_name:
Emergency overflow of leachate/seepage collection area at toe of N. Ash disp. Site.


oufall_name:
Emergency overflow leachage pump station


oufall_name:
High storm water flow from substation yard


oufall_name:
Combined sewage treatment and industrial treated effluents


oufall_name:
Emergency overflow from Neutralization Tank A


oufall_name:
Excess storm water flow from East yard runoff


oufall_name:
Emergency bypass subdrain pump system for ground water beneath ash filter ponds


# Plant_Permits

permit_type:
Resource Conservation and Recovery Act (RCRA)


permit_type:
National Pollutant Discharge Elimination System (NPDES)


permit_ID:
NJDEP Stormwater General Permit #NJ 0088315


permit_ID:
1065009-003-00100 Allegheny Health Dept APC


permit_ID:
Agreement between Harbor Cogeneration Company and The City of Long Beach, 10/27/04


# Pond_General

pd_desc:
Metal Cleaning Wastewater Treatment Pond North


pd_desc:
Metal Cleaning Wastewater Treatment Pond South


pd_desc:
CCP Stackout Pad contact storm runoff pond (028)


pd_desc:
(034)FGD landfill west sedimentation basin


pd_desc:
(027) Temporary Coal Combustion Products Storage Area noncontact stormwater runoff treatment pond


pd_desc:
(030) FGD Landfill Interim Leachate Collection pond


pd_desc:
(031) FGD Landfill Interim Leachate Collection pond


pd_desc:
FGD landfill south sedimentation basin (035)


pd_desc:
(032) FGD Landfill East Sedimentation Basin


pd_desc:
(033) FGD Landfill North Sedimentation Basin


pd_desc:
Ash Disposal Site Runoff Sedimentation Pond


pd_desc:
Coal pile runoff and waste water basin No. 4


pd_desc:
Active FGD Disposal Site Sedimentation Pond


pd_desc:
Closed Coal Combustion Byproduct Disposal Site Sedimentation Pond (Mingo)


pd_desc:
Bottom Ash Storage Area (Units 1-5)/Clearwater Pond


pd_desc:
Coal Ash Disposal Facility Stormwater Pond


pd_desc:
East Plant Stormwater Runoff Collection Pond


pd_desc:
Combustion By-products landfill pond (CBL)


pd_desc:
Ashfill Leachate and Storm Water Collection Pond


pd_desc:
SE Units 1,2, and 4 Fly Ash and Scrubber Slurry Pond


pd_desc:
Old SE Units 1, 2, And 3 Bottom Ash Pond


pd_desc:
Surge Pond (stormwater detention system)


pd_desc:
West Valley Ash Site Contact Stormwater / Leachate Pond


pd_desc:
East Valley Ash Site Storm Water Pond (A)


pd_desc:
East Valley Ash Site Storm Water Pond (B)


pd_desc:
East Valley Ash Site Energy Dissipator Pond


pd_desc:
Deep Mine Discharge Treatment Vertical Flow Pond SPD-15


pd_desc:
Deep Mine Discharge Treatment Wetlands Pond SPD16


pd_desc:
Original Ash Site Discharge Treatment Wetlands SPD-17


pd_desc:
Landfill Collection Runoff Collection Pond


pd_desc:
Limestone Area Drainage Collection Pond #1


pd_desc:
Limestone Area Drainage Collection Pond #2


pd_desc:
Combustion Turbine Diesel Tank Containment


pd_desc:
East End Coal Pile Runoff Collection Pond


pd_desc:
West End Coal Pile Runoff Collection Pond


pd_desc:
Storm Water Runoff Haul Road Sediment Trap 1


pd_desc:
Storm Water Runoff Haul Road Sediment Trap 2


pd_desc:
West Collection Basin (GPP Sumps/Runoff)


pd_desc:
Industrial Surface Impoundment North Ash Pond


pd_desc:
Industrial Surface Impoundment North Basin


pd_desc:
Industrial Surface Impoundment East Ash System (Cells 1, 2, and 3)


pd_desc:
Industrial Surface Impoundment South Basin


pd_desc:
Industrial Surface Impoundment Unit 5 Excess Slurry Basin


pd_desc:
Industrial Surface Impoundment East Ash Basin


pd_desc:
Industrial Surface Impoundment Unit 1, 2, and 3 Stackout Basin


pd_desc:
Industrial Surface Impoundment Cooling Pond


pd_desc:
Front Range Blowdown Basin (previously Nixon Northeast Former Ash Pond)


pd_desc:
Solar Evaporation Pond #1 (northeast pond)


pd_desc:
Solar Evaporation Pond #2 (southeast pond)


pd_desc:
Solar Evaporation Pond #3 (northwest pond)


pd_desc:
Solar Evaporation Pond #4 (southwest pond)


pd_desc:
Nixon Stormwater Pond and Coal Pile Runoff


pd_desc:
Reid/HMPL Ash Pond Dredge Spoil Transfer Decant Pond


pd_desc:
Stormwater run off from H-1, H-2 plant area, cooling tower, and scrubber (015)


pd_desc:
Reid/HMPL Ash Pond Dredge Spoil Transfer Pond


pd_desc:
Stormwater Runoff from South Area of FGD Landfill (012)


pd_desc:
Stormwater Runoff from the East and North Areas of the FGD Landfill (014)


# Pond_Leachate_Coll_Sys

Pond_Leach_Sys_Other_desc:
Interanal draiange layers with toe drains


Pond_Leach_Sys_Other_desc:
Underdrain System, Supplemental Draingae Layers, Lateral Drains, and Toe Drains


Pond_Leach_Sys_Other_desc:
drainage ditch around perimeter of ash pond


Pond_Leach_Sys_Other_desc:
seeps flow under road to constructed wetlands


Pond_Leach_Sys_Other_desc:
Seep flows to Ash Pond discharge channel.


Pond_Leach_Sys_Other_desc:
Seepage collection system from a toe drain


# Pond_Mntor_Inspct

Pond_YrInsp:
Water level and condition of ancillary equipment


Pond_YrInsp:
Plant conducts visual inspection of levees, water levels, vegetation


Pond_YrInsp:
interstitial space between primary and secondary liners monitored by leachate generation rate


# Pond_Storage

pd_stor_ww_other1:
Condenser Cooling Water, House Service Water, Essential Service Water, Demineralizer Regerant Waste, Wastewater treatment Plant Effluent, House service Water and Essential Service Water Strainer Backwashes, Cooling Pond Intake Screen Backwash, Water Pretreatment System Filter Backwash.


pd_stor_other1:
Suspended Solids in Floor Drains and Sumps

pd_stor_other2:
Oil and Grease from Floor Drains and Sumps

pd_stor_ww_other1:
Turbine building floor drain tank consisting of turbine building floor drains sumps, essential service water drain sumps, condensate pit sumps, Turbine Building Equipment Drain Tank, Unit 1&2 Tendon Tunnel Sumps, Aux. Boiler Blowdown, Unit 1&2 Diesel Fuel Storage Tank Sumps, Oil Water Separator No. 1 Effluent, Secondary Side Drain Water, Water Pretreatment Area Floor and Equipment Drain Sumps, Water Treatment Lime Softening Clarator Blowdown.


pd_stor_procWW2:
Combustion turbine evaporative coolers blowdown

pd_stor_ww_other1:
AIR COMPRESSOR COOLING WATER (SERVICE WATER)


pd_stor_procWW3:
Combustion turbine cleaning (compressor portion of the turbine) water


pd_stor_procWW1:
Combustion turbine evaporative coolers blowdown


pd_stor_ww_other1:
Discharge from Gypsum Runoff Sedimentation Pond


pd_stor_ww_other1:
Treated Effluent from HDS Wastewater Treatment System


pd_stor_ww_other1:
Previously treated Low Volume Waste Water [ion exchange]


pd_stor_other2:
low volume wastes as defined in 40CFR423.11

pd_stor_ww_other1:
low volume wastes as defined in 40CFR423.11


pd_stor_ww_other1:
Building and Precipitator Pad Sumps and Low Volume Wastes


pd_stor_ww_other1:
Ash Pond 3 Discharge and Low volume Wastes

pd_stor_ww_other2:
Sediment basin for dry ash stack operation


pd_stor_ww_other1:
All internal plant drains with the exception of sanitary sewer


pd_stor_ww_other2:
demineralizer wastewater, cooling basin cleaning, washdown


pd_stor_ww_other1:
Treated domestic wastewater; BCTW; CTB; YARDW; RORW;


pd_stor_ww_other1:
Including inlet oil skimmer, used to retain oil spills


pd_stor_ww_other1:
Previously treasted Low Volume Waste Water [ion exhange]


pd_stor_ww_other1:
Previously treated Low Volume Waste Water from RET-SPD-1 [ion exchange]


pd_stor_ww_other1:
Condenser Cooling Water; House Service Water


pd_stor_procWW2:
Combustion turbine cleaning (compressor portion of the turbine) water

pd_stor_ww_other1:
Stormwater runoff from fuel oil tank farm area


pd_stor_ww_other1:
Rinse water following boiler tube cleaning


pd_stor_ww_other1:
Various nuclear related streams - see Part H


pd_stor_ww_other1:
Steam Generator Blowdown - Alternate Pathway


pd_stor_ww_other1:
Effluent from SPD-2 (Yard Drainage Pond)

pd_stor_ww_other2:
Effluent from SPD-7 (Coal Pile Runoff Pond)


pd_stor_other1:
FGD calcium sulfate residuals from haul roads

pd_stor_ww_other1:
Storm water runoff containing FGD calcium sulfate residuals from haul roads and gypsum dome area


pd_stor_ww_other1:
Storm water runoff containing landfill haul road residuals


pd_stor_ww_other1:
Oily Waste Water from oily waste sumps & area drains


pd_stor_ww_other1:
Effluent from SPD-3, 4, 5, 6 (BAS Recycle Pond - A and BAS Pond B, C & D)


pd_stor_ww_other1:
Filter backwash; clarifier and bottom ash sluice decant


pd_stor_ww_other3:
SPD-1 discharge to control pond operating level


pd_stor_other2:
coal fines from SPD-2 dredging operations


pd_stor_ww_other1:
Internal outfalls contributory to Outfall 021.


pd_stor_ww_other1:
Groundwater from closed mixed ash pond (RET-SPD-1)


pd_stor_ww_other1:
misc. metal cleaning waste (chemical & non-chemical)


pd_stor_ww_other1:
Boiler washdown  and tube cleaning water, will only go to ponds after analyzed, if analyses are non-hazardous.

pd_stor_ww_other2:
Air heater cleaning water will go to pond,

pd_stor_ww_other3:
Combustion turbine Cleaning water, will go to the ponds after analyzed and analyses prove it is non hazardous.


pd_stor_ww_other1:
wastewater from washing down ash loading area


pd_stor_ww_other1:
Storm water,  residue from fugitive dust from coal pile and ash unloading


pd_stor_ww_other1:
Ash pit and cooling tower overflow and cooling tower drains


pd_stor_ww_other1:
Stormwater runoff from soil covered landfill slopes


pd_stor_ww_other2:
Boiler Room Sump Wastewater (Low volume waste) as defined under stream electric guidelines at 40 CFR 123.


pd_stor_ww_other1:
Pond 4 - Construction parking lot rainwater runoff.


pd_stor_ww_other1:
Floor drain wastewater, once-through cooling water, yard drain wastewater, RO reject water, leachate


pd_stor_ww_other4:
ash pile runoff, RO reject water, cooling tower blowdown


pd_stor_ww_other1:
Water from SPD-1, SPD-4, SPD-3, SPD-7, and Landfill -1


pd_stor_ww_other4:
Rinse water from fly ash tanker loading area.


pd_stor_ww_other1:
Rinse water from fly ash tanker loading area.


pd_stor_ww_other1:
Pond was cleaned out and backfilled, no wastes are stored or treated.


pd_stor_other1:
incidental settleable solids from process wastewater streams


pd_stor_other1:
incidential settleable solids from process wastewater streams


pd_stor_procWW2:
Combustion turbine cleaning (combustion gas portion of turbine) water

pd_stor_procWW4:
Combustion turbine evaporative coolers blowdown


pd_stor_ww_other4:
Condensate Polisher Regeneration ; Mist Eliminator Wash Water; Service Water; Pump Seal Water


pd_stor_ww_other1:
Treated brine plant discharge for use in cooling towers


pd_stor_ww_other1:
The basin is permitted to receive Boiler Tube Cleaning Wastewater, but this water is not normally sent there.


pd_stor_ww_other2:
Reverse Osmosis Cleaning Spent Solutions/Rinsates


pd_stor_ww_other2:
previously monitored effluents (low volume wastewater)


pd_stor_ww_other1:
sanitary wastewater discharge from an activated sludge treatment plant


pd_stor_ww_other1:
Oil process activites - recycle waste oil


pd_stor_procWW3:
Combustion turbine cleaning (combustion gas portion of turbine) water


pd_stor_other1:
possible metal cleaning wastes from 001b

pd_stor_ww_other1:
FLTBW, FDW, FAS, GR, FGDB, IXW, LRUC, LEACH, MRS, RORW, YARDW, LPR, CW

pd_stor_ww_other2:
Effluent from SPD-4, SPD-5, SPD-6, and SPD-9


pd_stor_ww_other1:
SPD-8 Effluent, SPD-3 Effluent, and SPD-6 Effluent

pd_stor_ww_other4:
Equipment Maintenance Pad Sump and Floor Drain Wastewater


pd_stor_ww_other3:
Supernatant from Fixation Area Decant Tank


pd_stor_ww_other1:
Brine discharges from Brine Concentrator when Crystalizer off-line

pd_stor_ww_other2:
Discharges from oil/water separator when brine concentrator is off-line


pd_stor_ww_other2:
Brine from Crystalizer during upset conditions


pd_stor_ww_other1:
Rinses from Boiler tube cleaning (not cleaning solution)


pd_stor_other1:
Possible metal cleaning and other waste residues


pd_stor_ww_other1:
Mississippi River water silt, sand from raw water filter backwash.


pd_stor_ww_other1:
Raw Surface Water from Bayou Bartholomew


pd_stor_other2:
Oil and Grease from Floor Drains and Sumps.


pd_stor_ww_other1:
02S Sewage Lagoons--from potable water system.


pd_stor_ww_other1:
SPD-1, SPD-2, and SPD-3 all discharge here.


pd_stor_ww_other1:
SPD-1, SPD-2, SPD-3, and SPD-4 all discharge here.


pd_stor_ww_other1:
Pond no longer receives liquid - borne material


pd_stor_other1:
Possible metal cleaning wastes and miscellaneous waste residues


pd_stor_ww_other1:
Emergency tank drains from scrubber process


pd_stor_ww_other4:
intake water treatment wastewater & sludge


pd_stor_procWW5:
Combustion turbine cleaning (combustion gas portion of turbine) water

pd_stor_procWW6:
Combustion turbine cleaning (compressor portion of the turbine) water


pd_stor_procWW3:
Combustion turbine evaporative coolers blowdown


pd_stor_ww_other1:
Rain water from Combustion Byproduct stack area


pd_stor_ww_other1:
Water from Lake Limestone, not a waste water pond.


pd_stor_procWW1:
Combustion turbine cleaning (compressor portion of the turbine) water


pd_stor_ww_other3:
Effluent from evaporation/percolation pressure relief system


pd_stor_other1:
moisture conditioned Fly ash is used as construction material for Up-stream Raise

pd_stor_other2:
moisture conditioned Bottom ash used as construction material for raise


pd_stor_procWW1:
Combustion turbine cleaning (combustion gas portion of turbine) water


pd_stor_ww_other1:
Ash Transport Water Blowdown from outfall 02C and Service water sump overflow 01G

pd_stor_ww_other2:
Sewage treatment plant effluent and drainage canal discharge 01F


pd_stor_ww_other1:
In the past received Bottom Ash Cooling water


pd_stor_ww_other1:
Boiler Blowdown, Coal Pile Runoff, Floor drain wastewater


pd_stor_ww_other1:
Any equipment wash/rinse water (no chemicals added) not collected elsewhere.

pd_stor_ww_other2:
FGD wastewater from equipment rinses, slurry preparation, slurry tank overflow, and other incidental FGD wastewater. Reused in system when possible.


pd_stor_ww_other1:
Not a waste. Well Water for Cooling tower


pd_stor_ww_other1:
Not a waste. Well water for cooling and boiler water


pd_stor_ww_other1:
metal cleaning waste after treatment in tank and testing


pd_stor_ww_other1:
Drain from F01 emergency total retention (same as SPD-1)


pd_stor_ww_other3:
Treated Metal Cleaning Waste Pond effluent


pd_stor_ww_other1:
Floor drain wastewater, yard drain wastewater, reverse osmosis reject water, general runoff, once-through cooling water


pd_stor_ww_other1:
Fly ash sluice, Reverse osmosis reject water

pd_stor_ww_other2:
Once through cooling water, ion exchange wastewater

pd_stor_ww_other3:
Clarifier sludge, Railroad track hopper sump water


pd_stor_ww_other1:
Coal pile runoff; boiler fireside cleaning water


pd_stor_ww_other4:
Ion Exchange Wastewaters, Reverse Osmosis Reject Water, Scrubber Blowdown, Cooling Tower Blowdown, General Runoff FGD Area


pd_stor_procWW4:
Combustion turbine cleaning (combustion gas portion of turbine) water

pd_stor_procWW5:
Combustion turbine evaporative coolers blowdown


pd_stor_ww_other2:
Condensed Evaporation from Coal Drying - pure water stream


pd_stor_ww_other1:
Collects any spilled chemical spilled during unloading operations  - and precipitation


pd_stor_ww_other2:
Rinse water following boiler tube cleaning


pd_stor_ww_other1:
YARDW, effluents from SPD-2 and SPD-3, Off-Spec Wallboard Gypsum


pd_stor_ww_other1:
Intermittent nonchemical metal cleaning wastewaters


pd_stor_ww_other1:
Effluent from Ponds SPD-4, SPD-5, and SPD-6


pd_stor_ww_other1:
General runoff, floor drain wastewater, yard drain wastewater, gypsum pile runoff, ion exchange wastewater, boiler blowdown, limestone pile runoff


pd_stor_ww_other1:
Inactive - currently no wastewater in pond (some water from direct precipitation)


pd_stor_ww_other2:
Ion Exchange waste water & Stack Washes & Fly Ash Truck Wash Water

pd_stor_ww_other4:
Floor Drains & Steam Combustion Air Steam Coil Washes


pd_stor_other2:
Low Volume Wastes as defined in 40CFR 423.11

pd_stor_ww_other2:
Pond currently serves as the coal pile run-off pond


pd_stor_ww_other3:
Effluent from SPD-1, SPD-3, SPD-4, SPD-5, SPD-6


pd_stor_ww_other2:
Overboard water of SPD-5, SPD-6, SPD-7, and SPD-8


pd_stor_other1:
This is a future proposed pond and sunnyide's does not have the information yet.


pd_stor_ww_other4:
ash pile runoff, RO reject water, cooling tower blowndown


pd_stor_procWW6:
Combustion turbine evaporative coolers blowdown

pd_stor_ww_other1:
Filter Backwash, Ion Exchange wastewater, RO reject

pd_stor_ww_other2:
Floor drain wastewater, General Runoff, Yard drain wastewater


pd_stor_ww_other3:
Unit 3 scrubber lime reagent preparation discharge

pd_stor_ww_other4:
Unit 4 scrubber lime reagent preparation discharge


pd_stor_ww_other2:
FGD Pozzolanic Material and Lime Slaking Runoff


pd_stor_ww_other2:
low volume waste (combined with the cooling tower blowdown)


pd_stor_ww_other1:
Low volume waste consisting of misc. cooling water, instrument water filter water, l'eau claire flush wastewater, boiler condensate and non-chemical metal cleaning waste.


pd_stor_ww_other1:
L'eau claire flush water, stormwater runoff from roof drains and plant area


pd_stor_ww_other1:
pH adjusted water from the Sed Pond, Unit ID SPD-1


pd_stor_ww_other1:
Water overflow from Pond A, Unit ID SPD-2


pd_stor_ww_other1:
miscelaneous floor drains and yard drains that may contain oil


pd_stor_ww_other1:
Treated effluent from sanitary sewage treatment plant


pd_stor_ww_other1:
Inactive - currently no wastewater in pond


pd_stor_ww_other1:
Blowdown from the waste water concentrators


pd_stor_other1:
Calcium Sulfate from waste water concentrators


pd_stor_ww_other1:
Pyrite sluicewater, plants sumps, seal water, rainfall runoff, metal cleaning wastewater,

pd_stor_ww_other2:
ion exchange water treatment system discharges, lab & sampling waste streams,

pd_stor_ww_other3:
service water system discharge, air heater cleaning water, boiler blowdown, boiler

pd_stor_ww_other4:
cleaning water (tube & fireside), reverse osmosis wastewater


pd_stor_ww_other1:
Discharge from bottom ash ponds (SPD-1, SPD-2)


pd_stor_other3:
chloride purge stream WWTP effluent, residual

pd_stor_ww_other2:
Discharge from FGD chloride purge stream WWTP

pd_stor_ww_other3:
Discharge from FGD landfill leachate pond SPD-15

pd_stor_ww_other4:
Discharge from Dewatering Island Pond SPD-16


pd_stor_ww_other1:
Treated Domestic Waste Water, BFCW,BTCW,GR ,IXW,YARDW,Neutralization Tank Waste Water


pd_stor_ww_other1:
Previously treated metal cleaning and chemical cleaning waste water.

pd_stor_ww_other2:
Previously treated fireside wash water, and air preheater wash water.


pd_stor_ww_other1:
Overflows from active fly ash cells (SPD-1, SPD-2) and bottom ash cell (SPD-3)


pd_stor_ww_other3:
Note: Bottom Ash System (BAS) Wastewater (emergency only)


pd_stor_ww_other3:
May receive water from SPD-6 for level control of SPD-6

pd_stor_ww_other4:
Cooling Tower Blowdown for level control


pd_stor_other1:
possible residues from metal cleaning wastes


pd_stor_ww_other2:
Bottom Ash system blowdown (after decant and dewatering)


pd_stor_ww_other1:
Treated bottom ash sluice recycle water overflow


pd_stor_ww_other1:
Brine concentrator supernatant from SPD-5


pd_stor_other2:
sodium bicarbonate (FGD dry sorbent injection)

pd_stor_ww_other1:
service water (river water) as boiler blowdown quench

pd_stor_ww_other2:
once through cooling water as needed to maintain level)


pd_stor_ww_other2:
Potable & Cooling Tower Clarifier & IWT sludges


pd_stor_ww_other1:
runoff from fly ash and bottom ash disposal area


pd_stor_ww_other3:
metals cleaning waste  (air heater cleaning water (AHCW))


pd_stor_ww_other2:
Stormwater from landfill construction site.


pd_stor_ww_other1:
Pond B received dredged ash from Pond A.  It is being capped by a landfill.


pd_stor_ww_other3:
Treated municipal wstewater, City of Gentry, AR


pd_stor_other1:
Incidental carryover from SPD-4 supernatant


pd_stor_procWW5:
Combustion turbine cleaning (compressor portion of the turbine) water


pd_stor_ww_other1:
Waste Water Pond Dredging Solids and Wastewater


pd_stor_other1:
Residues from metal cleaning wastes (possible)


pd_stor_ww_other3:
Cooling Tower Effluent Not Classified as Cooling Tower Blowdown


pd_stor_ww_other1:
Dry CCB wastes are placed in the upper pond (fly ash, bottom ash, gypsum, etc.)


pd_stor_ww_other1:
decanted bottom ash sluice water (SPD-4)

pd_stor_ww_other2:
decanted FGD slurry blowdown sluice water (spd_5 & SPD-6)


pd_stor_ww_other1:
Overboard water from SPD-2, SPD-3, and SPD-6


pd_stor_ww_other1:
FGD WasteWater (Thickener Overflow & Underflow)

pd_stor_ww_other2:
Sedimenation Pond WasteWater and Leachate


pd_stor_ww_other3:
Exciter & Control Room HVAC  Cooling Tower blow down


pd_stor_ww_other1:
Wastewater From Firefighter Training Activities


pd_stor_ww_other1:
low volume wastewater (neutralization pit effluent, regeneration wastewater, area washdown water)


pd_stor_ww_other1:
low volume wastewater (process condensate from carbon dioxide recovery plant, area washdown water)


pd_stor_ww_other1:
low volume wastewater (boiler blowdown, area washdown water)


pd_stor_ww_other1:
Lake Blowdown (including previous monitored effluent)


pd_stor_ww_other1:
During Cleaning of SPD-2, SPD-3 used as back-up, thus SPD-2 wastewater possible


pd_stor_ww_other2:
washdown water from solids handling area


pd_stor_other1:
Washdown water from bottom ash dewatering bins and fly ash silo area


pd_stor_other1:
Incidental solids from process wastewater streams

pd_stor_ww_other1:
excess bottom ash dewatering system water


pd_stor_ww_other2:
Intermittent Cooling Tower Basin Overflow


pd_stor_ww_other1:
Motive water for fly ash hydroconveyor system.


pd_stor_other1:
incidental solids from process wastewater streams


pd_stor_ww_other4:
Yard Drain Wastewater, Ash Site Runoff-capped & uncapped


pd_stor_ww_other1:
Once-through cooling water, reverse osmosis reject water, yard drain wastewater, general runoff

pd_stor_ww_other2:
Effluent from SPD-2, leachate, floor drain wastewater, ion exchange wastewater, mill reject transport water


pd_stor_ww_other1:
periodic stromwater run-off from temporary ash storage


pd_stor_ww_other2:
Well water for coal pile dust suppression


pd_stor_ww_other1:
Pond drained, sediments removed, and then backfiled with soil.  No water, or ash sediments remain.


pd_stor_ww_other1:
Leak Detection and Groundwater Suppression


pd_stor_ww_other1:
Storm water runoff from coal conveyor and ash handling areas

pd_stor_ww_other3:
Air pre heat drains (cooling tower water) during maintenance


pd_stor_ww_other1:
Yard Equipment Wash Water (Power washer used to remove coal accumulation)


pd_stor_ww_other1:
Solids Contact Unit Treatment of Des Moines River Water


pd_stor_procWW4:
Combustion turbine cleaning (compressor portion of the turbine) water


pd_stor_ww_other1:
Effluent from WWT plant that treats FGD purge water


pd_stor_ww_other1:
pH adjusted wastewater from Demineralizers


pd_stor_ww_other1:
All raw water pretreatment system wastes


pd_stor_ww_other1:
Secondary Treated Effluent from a municipal WWTP, used to extinction no discharge


pd_stor_ww_other1:
Stormwater runoff from undeveloped landfill area.


pd_stor_ww_other1:
FGD overflow - final FGD material mixed with water from belt washings


pd_stor_ww_other2:
continuous deionization system softener waste


pd_stor_ww_other1:
continuous deionization system softener waste


pd_stor_other1:
incidental solids from process wastewater systems


pd_stor_other1:
Incidental carryover from SPD-1 and SPD-2 supernatant


pd_stor_ww_other1:
Stormwater runoff from the site and upgradient farm ground.


pd_stor_ww_other1:
FGDB, FLTBW, FDW, FAS, GR, GPR, IXW, MRS, YARDW, low volume wastes


pd_stor_ww_other1:
Overflows from intermediate cell (SPD-5)


pd_stor_ww_other1:
n/a - intake water only, although capable of recycling flow from SPD-9


pd_stor_ww_other1:
Water Treatment Plant Sludge (lime softening)


pd_stor_ww_other1:
Clarified water from SPD-5,  Pond used for secondary settling and retention for pH adjustment prior to discharge


pd_stor_other3:
storm water with associated coal fines from coal pile sump

pd_stor_ww_other3:
sand filter and zeolite system regeneration stream


pd_stor_ww_other2:
floor & laboratory drains & drains from equipment cleaning


pd_stor_ww_other1:
Water used by Reed Minerals for intitial washing/sizing of slag


pd_stor_other4:
River Intake Sediment, Captive Generated C&D Municipal Wastes

pd_stor_ww_other1:
Air Heater, Precipitator Washes, Pyrite Pile Leachate/Runoff


pd_stor_other1:
Coal fines (no coal currently stored in area)

pd_stor_ww_other1:
Pond just collects stormwater runoff since coal is no longer stored in this area


pd_stor_other1:
Incidental solids from process wastewater process ponds


pd_stor_ww_other1:
floor drains,  flyash sluice,  general runoff,  ion exchange wastewater,

pd_stor_ww_other2:
landfill runoff-uncapped landfill,  reverse osmosis reject,  sootblowing wash water


pd_stor_ww_other1:
floor drains,  general runoff,  ion exchange wastewater,  sootblowing wash water


pd_stor_ww_other1:
floor drains,  general runoff,  reverse osmosis reject,  sootblowing wash water


pd_stor_ww_other2:
this pond is cross-tied to SPD-6, wastewaters combined


pd_stor_other2:
low volume wastes as defined in 40CFR 423.11

pd_stor_ww_other1:
APR, CTB, GR, GPR, GYPWW, FDW, FAS, IXW, LRUC, MRS, YARDW

pd_stor_ww_other2:
LPR, CW, Low volume waste as defined under 40 CFR 423.11


pd_stor_ww_other1:
Ash Pond 3 no longer receives liquid borne material from the plant.

pd_stor_ww_other2:
It serves as a sediment pond for the "B" Prime North 1 and 2 dewatering cells


pd_stor_ww_other3:
Dredgings from Central Wastewater Treatment Ponds and Coal Pile Sump


pd_stor_other1:
Bottom ash residues from dewatering bins

pd_stor_ww_other1:
Air heater water and boiler fireside cleaning water


pd_stor_other2:
Low Volume Wastes as defined under 40 CFR 423.11

pd_stor_ww_other1:
No longer receives liquid borne material


pd_stor_other1:
possible residues from  metal cleaning wastes


pd_stor_other1:
mill rejects, and Low Volume Wastes as defined under 40 CFR 423.11


pd_stor_ww_other1:
Discharge from SPD-1, seal water, ion exchange water treatment system discharges,

pd_stor_ww_other2:
plant sumps, wash-water, lab & sampling waste streams, service water system,

pd_stor_ww_other3:
roof drains, oil/water separator discharges, reverse osmosis water treatment discharge,


pd_stor_ww_other1:
Non-contact stormwater and wash water around fly ash silo


pd_stor_other2:
Low Volume Wastes as defined under 40 Cfr 423.11


pd_stor_ww_other2:
Low Volume Wastes as defined by 40 CFR 423.11


pd_stor_ww_other1:
ion exchange wastewater, mill reject sluice, reverse osmosis reject water, steam turbine cleaning water

pd_stor_ww_other4:
reverse osmosis reject water, steam turbine cleaning water


pd_stor_ww_other4:
All the above enter from the neutralization basin - a large concrete sump in station


pd_stor_ww_other1:
Ion exchange water, Reverse Osmosis Reject Water


pd_stor_ww_other4:
general runoff, ion exchange wastewater, mill reject sluice


pd_stor_ww_other1:
emergency overflow from SPD-1, not needed (used) since 2000


pd_stor_other2:
incidental solids from process wastewater systems


pd_stor_ww_other4:
General runoff, Ion exchange wastewater, Mill reject sluice


pd_stor_other1:
Small amounts of ash fines from bottom ash sluice and yard ditch


pd_stor_ww_other2:
area drainage, vehicle wash station, abnormal plant overflows

pd_stor_ww_other3:
secondary sewage treatment plant outflow


pd_stor_ww_other1:
whatever water is included with solids dredged from SPD-1


pd_stor_other1:
whatever solids are eroded from coal pile during rain and ice/snow melt


pd_stor_ww_other1:
water from french drain network, final collection point for process water,discharge to POTW


pd_stor_ww_other1:
CPR water, mixes with process water downstream


pd_stor_ww_other1:
Brine Concentrator Blowdown holding pond


pd_stor_ww_other2:
Ash Hopper Seal Waters, Filter Backwash, Other Low Volume Wastes and General Runoff

pd_stor_ww_other3:
Ion Exchange Wastewater, Reverse Osmosis Reject Water, Boiler Chemical Cleans, Combustion Turbine Evaporative Coolers Blowdown

pd_stor_ww_other4:
CT Site Floor Drain Wastewater, Fuel Oil Unloading Area Runoff Wastewaters


pd_stor_ww_other1:
Receives discharge from an Internal NPDES outfalls


pd_stor_ww_other1:
Coal handling equipment runoff, Limestone storage area runoff


pd_stor_ww_other3:
Bottom ash sluice water inflow is intermittent


pd_stor_ww_other1:
Temporary Bottom Ash and Fly Ash storage storm water runoff


pd_stor_other3:
low volume waste as defined in 40 CFR 423.11

pd_stor_ww_other1:
Dewatering cell for ash dredged from Ash Pond 2 (SPD-2)


pd_stor_ww_other1:
Water may be transferred into the surge pond from the ash pond and/or the metal cleaning pond for treatment and disposal.


pd_stor_ww_other1:
Low Volume Wastes as defined under 40 CFR 423.11

pd_stor_ww_other2:
General Runoff, Ion Exchange Wastewater, Mill Reject Sluice

pd_stor_ww_other3:
Reverse Osmosis Reject Water, Soot Blowing Wash Water


pd_stor_ww_other1:
Stormwater runoff from wastewater treatment plant dedicated land disposal units.


pd_stor_ww_other2:
all components of wastewaters found in SPD-2, SPD-3, SPD-4, SPD-5, and SPD-6


pd_stor_ww_other2:
Low Volume Waste as defined under 40 CFR 423.11


pd_stor_other1:
mill rejects and low volume wastes as defined under 40 CFR 423.11

pd_stor_ww_other1:
Pond is inactive and currently does not receive any ash and does not contain free water


pd_stor_ww_other1:
Process wastewater that comes from SPD-2


pd_stor_ww_other1:
Brackish wastewater from Zero Discharge Plant evaporator brine.


pd_stor_ww_other1:
this pond is cross-tied to SPD-5, wastewaters combined


pd_stor_ww_other1:
miscellaneous plant related wastewater from sumps


pd_stor_other1:
incidental solids from stormwater runoff


pd_stor_ww_other1:
Limestone pile runoff, gypsum pile runoff, general runoff


pd_stor_ww_other1:
No longer receives liquid-borne material


pd_stor_ww_other1:
mill reject sluice which is part of bottom ash sluice

pd_stor_ww_other3:
boiler tube cleaning water from other Luminant facilities (Industrial Solid Waste Permit)


pd_stor_ww_other1:
Product water from lime soda softening (clarifers )


pd_stor_ww_other1:
Slip stream of the effluent from SPD-2 used for pilot scale treatment technology demo


pd_stor_ww_other2:
Low Volume Wastes as defined under 40CFR 423.11


pd_stor_ww_other1:
Inactive and no longer receives liquid borne material


pd_stor_ww_other2:
SPD-2 water for water balance and liner protection

pd_stor_ww_other3:
Water from SPD-4 for maintainence of SPD-4 or for water balance


pd_stor_ww_other1:
Elevated Well Water Storage Tower Blowdown


pd_stor_ww_other1:
Emergency Storage of FGD Slurry Blowdown


pd_stor_ww_other1:
Chemical cleaning wastewater for all units


pd_stor_ww_other1:
Air Heater Cleaning Water; Boiler Fireside Cleaning Water; Filter Backwash; Floor Drain Wastewater; General Runoff; Iopn Exchange Wastewater; Leachate; Mill Reject Sluice;


pd_stor_ww_other1:
Filter Backwash, Floor Drain Wastewater, Gypsum Pile Runoff, Ion Exchange Wastewater, Mill Reject Sluice, Reverse Osmosis Reject Water, Yard Drain Wastewater, Once-through Cooling Water


pd_stor_ww_other1:
Stormwater from Coal Pile Storage Area discharged to Ash Pond


pd_stor_ww_other1:
Combined effluent pond water(SPD-19 & 20) emergency only


pd_stor_other1:
Water treatment lime soda softening wastes,

pd_stor_ww_other2:
Combined effluent pond water(SPD-19 & 20) emergency only


pd_stor_ww_other1:
Storm water from the lignite pond may be transferred into this pond for treatment and disposal.


pd_stor_other1:
Lime soda softening sludges from water treatment


pd_stor_ww_other1:
Lube oil storage tank containment drains

pd_stor_ww_other2:
Fuel oil storage tank containment drains


pd_stor_other2:
low volume wastes as defined under 40CFR 423.11

pd_stor_ww_other2:
Low Volume Wastes as defined under 40 CFR 423.11


pd_stor_ww_other1:
NPDES collection basin emergency overflow, fire training runoff


pd_stor_ww_other1:
Storm water runoff containing ash handling area residuals


pd_stor_ww_other1:
Storm water runoff containing coal and ash handling area residuals


pd_stor_ww_other1:
Leachate/ Runoff from Area 3, Demineralizer Regeneration Waste

pd_stor_ww_other2:
Ash Trench Drain, Raw Water Strainer Blowdown, Pyrite Transfer Tank Overflow


pd_stor_ww_other1:
Treated process waste water from spd 7 & 8


pd_stor_other1:
temporary storage until loadout for offsite recycling


pd_stor_ww_other1:
Consolidation Coal Company's acid mine drainage treatment plant effluent

pd_stor_ww_other2:
Consolidation Coal Company's coal preparation plant effluent


pd_stor_ww_other1:
FGD chloride purge WWTP discharge, wash waters, plant sumps, drainage from

pd_stor_ww_other2:
ammonia on demand system, metal cleaning wastewater tank discharge, cooling water

pd_stor_ww_other3:
used for bottom ash sluice, reverse osmosis & ion exchange water treatment system discharges, water

pd_stor_ww_other4:
treatment evaporation blowdown, sampling waste streams, service water system, boiler fireside cleaning water


pd_stor_ww_other1:
Brine Concentrator / Chrystallizer Effluent


pd_stor_ww_other2:
Condensor hydro water (condensate water)


pd_stor_ww_other2:
storm water from fly ash truck load out area


pd_stor_ww_other1:
Ion exchange waste water and filter backwash


pd_stor_other1:
Incidental solids from process wastewater systems


pd_stor_ww_other1:
Stormwater from direct rainfall into the chemical waste basin


pd_stor_ww_other1:
Temporarily stores SDA pond water during SDA pond cleaning.


pd_stor_ww_other1:
Water from SPD-1 and SPD-2 for evaporation


pd_stor_ww_other3:
Unit 2 Ash Tank and Boiler seal overflow.


pd_stor_other1:
Solids from treating wastewater from SPD-4

pd_stor_ww_other1:
Brine concentrator supernatant from treating wastewater from SPD-4


pd_stor_ww_other1:
Fly ash sluice water; final polishing pond


pd_stor_other2:
Misc. coal and ash contaminated materials


pd_stor_other1:
Misc. coal and ash contaminated materials

pd_stor_ww_other1:
SPD-1 water for freeze protection and level control of SPD-1


pd_stor_ww_other1:
Sludge from Coal Pile Runoff Treatment.  See Comments.


pd_stor_other1:
Residues from runoff from gypsum pile area


pd_stor_other1:
Sediments, residual solids from 1) road washing, 2) containment overflows, 3) drains

pd_stor_ww_other1:
Low volume intermittent flows from sump & containment overflows, road washing, drains, emergency condensate overflow, conveyor washwater, fire water system overflow


pd_stor_ww_other1:
Other, specify: Low volume intermittent flows from sump & containment overflows, road washing, drains, deaerator & reclaim tank vents


pd_stor_ww_other1:
Brine  from Zero Discharge Plant evaporator.


pd_stor_ww_other1:
Sedimentation pond discharge from drinking water plant.


pd_stor_ww_other1:
Slurry blowdown during emergency situations


pd_stor_ww_other1:
Washdown water from ash and coal handling areas.


pd_stor_ww_other1:
Once-through cooling water, yard drain wastewater, floor drain wastewater, reverse osmosis reject water general runoff


pd_stor_ww_other1:
EFFLUENT FROM SPD-5 AND possible effluent from SPD-3 & SPD-4


pd_stor_ww_other3:
Reverse osmosis reject water, Ultrafiltration reject water, EDI reject water


# Pond_WWT_Capital_Info

Pond_WWT_Components_Incl_desc:
general and administrative overhead costs of $25,623.96 was not included.


Pond_WWT_Components_Incl_desc:
Two pH meters, one control valve, 2 metering pumps, piping, control panel.  All other parts of waste water system not included (waste water pumps, clarifier, valves, other piping, flow meter)


Pond_WWT_Components_Incl_desc:
Project was integral with larger landfill development project.  Some costs for impoundment, such as building, site preparation, etc were not specifically identified in project records.


Pond_WWT_Components_Incl_desc:
Pond 5 has not been active since 2008.  Pond-5 is one of the three station flyash settling ponds onsite.


Pond_WWT_Components_Incl_desc:
The cost only includes the WWT Plant construction (WWT-1).  It does not include the cost(s) associated with the ponds (Pond-1 through Pond-4).


Pond_WWT_Components_Incl_desc:
not applicable, no costs were reported in Table D-15, see comments


Pond_WWT_Components_Incl_desc:
Indirect costs are not included in the above.  See comments for cost breakdown.


Pond_WWT_Components_Incl_desc:
Site preparation is not included for 1 of the 3 ponds to which this section applies.  Land purchase costs are not included for all 3 ponds.  Indirect costs are not included for 2 of the ponds.


Pond_WWT_Components_Incl_desc:
The following WWT-1 system scope items are not included in the capital costs reported in Table D-15: Influent piping from FGD, effluent piping to the plant clear water pond, all of the concrete work inside the main building, Sargent & Lundy Engineering and Design costs, the filter press cloth wash system equipment & installation and the WWT-1 system start-up & commissioning costs.


Pond_WWT_Components_Incl_desc:
Storage tanks, pumps, piping, clarifier systems, lime storage and injection, sludge handling and effluent filtration equipment, electrical switchgear and controls.


Pond_WWT_Components_Incl_desc:
South ash pond construction, dredge and booster pump


# Pond_WWT_OandM

OM_Other1:
Contractor Costs -Maintain and Operate Pomd System


OM_Other1:
Maintenance costs by offsite contractors


OM_Other1:
General repairs, mowing, rodent control, rock


OM_Other1:
Bi-annual grubbing of ponds (2010- $16,000)


# Retired_Pond_Systems

Plant_Desig:
Reid/HMPL Ash Pond Dredge Spoil Transfer Pond


Plant_Desig:
Reid/HMPL Ash Pond Dredge Spoil Transfer Decant Pond


Plant_Desig:
Coal pile runoff pond, ash pond (3 cells),ash landfill runoff pond


# Treatment_Diagram

System_ID:
POND-1, POND-2, POND-A, WWT-1, WWT-2, RET-POND-1


System_ID:
POND-1, POND-2, POND-3, POND-4, POND-5, POND-6, POND-7, WWT-3


# Treatment_Effluents

Effluent_Dest:
Hauled off site for reuse (marketed and sold)


Effluent_Dest_Other:
Used for ash sluice, FGD absorber makeup


Effluent_Dest_Other:
Embankment construction and hauled to landfill


Effluent_Dest_Other:
reused for dust suppression, coal washdown system, and/or in the scrubber system


Effluent_Dest_Other:
Intermediate outfall 003 to final outfall 001


Effluent_Dest_Other:
Reuse as economizer ash and air heater ash sluice


Effluent_Dest_Other:
Bottom ash sluice and dry fly ash system hydroveyor water


Effluent_Dest_Other:
Recirculated water to submerged flight conveyor


Effluent_Dest_Other:
Reuse for ash sluicing and other applications


Effluent_Dest_Other:
Reuse in numerous plant operations including sluicing, cooling, freeze protection


WWTU_ID:
Chemical Precipitation Reaction Tank 1 - 1


Effluent_Dest_Other:
recycled for use in the bottom ash sluice system, FGD makeup water, mill reject sluice water


Effluent_Dest_Other:
Commingled with CTB prior to discharge to SW


Effluent_Dest_Other:
Roads and Onsite Dry Fly Ash Landfill Cap.


Effluent_Dest_Other:
On-site landfill or Sold on the market as resuse.


Effluent_Dest_Other:
Recycled as FAS, FGDAB, FGDP for Unit 2 FGD scrubber


Effluent_Dest_Other:
Recycled as FAS, FGDB, and FGDAB Unit 1 & 2 FGD scrubber


Effluent_Dest_Other:
Reuse as boiler water and cooling tower water


Effluent_Dest_Other:
Dust suppression at landfill, haul roads, coal pile


# Treatment_Influents

Influent_Other:
Combination of stormwater and reverse osmosis reject and filter backwash accummulated from 9/22/2008 to 3/6/2009


WWTU_ID:
Chemical Precipitation Reaction Tank 1 - 1


Influent_Other:
Low Vol Waste (from units owned by others)


Influent:
Combustion turbine evaporative coolers blowdown


Influent_Other:
FGD overflow: Final FGD material mixed with water from belt washings


Influent:
Combustion turbine cleaning (compressor portion of the turbine) water


Influent_Other:
Units 1-4 Bottom Ash Sluice (& MRS) (*See Comment)


Influent_Other:
Ash Seal Water, Slag Tank Overflow, Hydrobin, and other processes


WWTU_ID:
Chemical Precipitation Reaction Tank 1 - 2


Influent_Other:
From potable water treatment system and demineralization system wastes


Influent_Other:
continuous deionization system softener waste


Influent_Other:
Boiler blowdown, bottom ash overflow, wash waters


Influent_Other:
Low Vol Waste - Mill Reject Sluice Flush Waters


Influent_Other:
Tractor shed oil/water separator effluent


Influent_Other:
Boiler Ash System BD (After decant and dewatering)


Influent:
Combustion turbine cleaning (combustion gas portion of turbine) water


Influent_Other:
Economizer ash and Air heater ash sluice


Influent_Other:
Cooling water reservoir water makeup from Illinois River


Influent_Other:
Sewage Tmt Plant & yard drain wastewater


Influent_Other:
Chem lab & battery room sink & floor drains


Influent_Other:
Hydrobin overflow and dry fly ash system hydroveyor water


Influent_Other:
Yard drain waste water (flow is unknown)


Influent_Other:
Ash Pile Runoff from landfill (flow is unknown


Influent_Other:
FGD wastewater from equipment rinses, slurry preparation, slurry tank overflow, and other incidental FGD wastewater. Reused in system when possible.


Influent_Other:
Miscellaneous wastewater from equipment washes/rinses (no chemicals added) not collected elsewhere.


Influent_Other:
Equipment Cooling Water, Seal Water, Dust Vacuum Water, In Plant Drains


Influent_Other:
Limestone slurry prep equip cooling water


Influent_Other:
Previously Monit. Effluent during storm events


Influent_Other:
Recirculated water from submerged flight conveyor


Influent_Other:
Raw Water Treatment Filter Backwash and FDW


Influent_Other:
Ash Handling Area Washdown, Dust Control and YARDW


Influent_Other:
Non chem Economizer Wash and Heat Ex. Wash


Influent_Other:
Issue - no diagram and no pond system identified


Influent_Other:
Bottom and Economizer Ash, and Mill Reject Sluice Water


Influent_Other:
Demineralizer and Laboratory Waste Drains, and Sand/Carbon Filter Backwash


Influent_Other:
Coal Pile Reclaim Hopper and Rail Car Dumper Sumps Wastewater


Influent_Other:
Coal Pile Runoff and Landfill Runoff (Uncapped)


Influent_Other:
CALCIUM SULFATE & FLYASH SLURRY (FGD-3 & FGD-4) (emergency only)


Influent_Other:
Units 1 and 2 Coal Handling Equipment Washdown


Influent_Other:
T2 Area Coal Handling Equipment Washdown


Influent_Other:
includes: Coal pile, Gypsum pile, Limestone pile, and Stormwater


Influent_Other:
No. 1 & 2 Economizer Ash (Emergency Only)


Influent_Other:
Unit 1 & 2 pyrites transfer tank overflow


Influent_Other:
Unit 1 and 2 raw water strainer blowdown


Influent_Other:
Unit 1 and 2 pyrites transfer tank overflow


Influent_Other:
Solids Contact Unit Treatment of Des Moines River water


Influent_Other:
Low Level Waste Water Collection Pit from Station Discharges and Area Rainwater


Influent_Other:
Treats fly ash silo area washdown water, CPR, AHCW


Influent_Other:
Ammonia-on-Demand (AOD) System Recycle Tank


Influent_Other:
Fuel oil storage tanks containment berm collected precipitation


Influent_Other:
boiler room sumps containing: YARDW, FDW, BFCW, slag tank overflow


WWTU_ID:
Chemical Precipitation Reaction Tank 2 - 1


Influent_Other:
Raw water treatment including RO and demineralizer wastewater.


Influent_Other:
Combined FGD Slurry Blowdown and FGD Scrubber Purge as sludge goes into SPD-17


Influent_Other:
Combined Wastewater Treatment Plant Discharge


Influent_Other:
MRS is also included in the gpm listed for BAS


Influent_Other:
Pneumatically conveyed Fly ash from SE Unit-6


Influent_Other:
SE Unit-6 Condensate Polisher Wastewater


Influent_Other:
Air cleaning & boiler fireside cleaning water


Influent_Other:
Stormwater, service water, filter backwash, gypsum washwater, plant sludge dewatering, ash leachate,


Influent_Other:
Demineralizer and mixed bed regeneration


Influent_Other:
Unit 5&6 FGD WW: conveyor belt wash water, floor drain wastewater, and storm water


Influent_Other:
Demineralizer wastewater pH neutralization effluent


Influent_Other:
Plant Sumps (clinker grinder, ESP, ash pits, ash house, turbine room)


Influent_Other:
Consol acid mine drainage treatment plant discharge


Influent_Other:
U3 Wastewater: AHCW, FLTBW, FDW, RORW, IXW


Influent_Other:
Wastewater collection sumps (includes overflow & pit sumps and reverse osmosis discharge and ion exchange discharge)


# WWT_Pollutants

Fut_Lim_Chng_Desc:
selenium limit of 29 ug/l at Outfall 002, effective July 2012


Fut_Lim_Chng_Desc:
No improvements are under construction or planned.


WWTS_Trgtd_Metals_Specify:
Aluminum Cadmium, Chromium II, Cobalt, Copper, Iron, Lead, Manganese


WWTS_Trgtd_Metals_Specify:
cadmium, copper, lead, mercury, nickel, silver, tin, zinc


WWTS_Trgtd_Metals_Specify:
Iron, nickel, lead, aluminium, cadmuim, chromium, copper, mercury, vanadium, zinc


Fut_Lim_Chng_Desc:
Mercury monthly average and maximum limits of 1.8 and 3.2 ng/L, respectively


Fut_Lim_Chng_Desc:
mercury monthly and maximum limits of 1.8 and 3.2 nanograms/Liter, respectively


WWTS_Trgtd_Metals_Specify:
Iron, magnesium, aluminium, and other heavy metals


WWTS_Trgtd_Metals_Specify:
Aluminum, Arsenic, Barium, Boron, Cadmium, Mercury, Selenium,


WWTS_Trgtd_Metals_Specify:
Al, Sb, As, Be, Cd, Cu, Pb, Hg, Ni, Ag, Se, Tl, Zi


WWTS_Trgtd_Metals_Specify:
copper, iron, silver, selnium,  and mercury


WWTS_Trgtd_Metals_Specify:
Iron, Copper, Lead, Mercury, Selenium, Beryllium


WWTS_Trgtd_Metals_Specify:
Lead, manganese, mercury, nickel, selenium, silver, zinc, iron, aluminum, arsenic, beryllium, boron, cadmium, chromium III, copper


WWTS_Trgtd_Metals_Specify:
Iron, Manganese, copper, zinc, chromium, hex chromium, aluminum, nickel, lead, mercury, cadmium, arsenic, selenium


WWTS_Trgtd_Metals_Specify:
Iron, arsenic, barium, copper, cadmium, chromium, lead, nickel, selenium, vanadium, zinc


# WWT_Study

OtherStudies:
No wastewater treatment technologies have been studied by the plant.


SummaryStudiesDesc:
Golder Associates conducted an impoundment dike stability study for the bottom ash pond and the south dike of the final ash pond.  Recommendations were made for the repair of the impoundment dikes.                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                         Professional Engineering Consultants conducted an analysis to determine how to prevent rainfall induced overflows of the cinder pit from being discharged to Tecumseh Creek.


OtherStudies:
No studies have been conducted on any ash or FGD wastewater treatment technologies.


SummaryStudiesDesc:
Treatment monitoring of in-process ash pond water (and FGD wastewater, if applicable) using ICP-MS measurements for total and dissolved (<0.45um) metals and using EPA 245.7 measurements for total and dissolved mercury.


SummaryStudiesDesc:
Study #1 - Treatment monitoring of in-process ash pond water (and FGD wastewater, if applicable) using ICP-MS measurements for total and dissolved (<0.45um) metals and using EPA 245.7 measurements for total and dissolved mercury. Study #2 - Pilot and full scale compost wetland treatment of FGD wastewater for the removal of metals (including selenium and mercury).  Total and dissolved (<0.45um) metals measured using ICP-MS. Total and dissolved (<0.45um) mercury measured using EPA 245.7.  Study #3 - Full scale ferric chloride treatment for mercury removal in ash pond treatment system with FGD gypsum slurry directly routed to ash pond.  Total and dissolved (<0.45um) mercury measurements using EPA 245.7 performed on in-process ash pond waters.  Study #4 - Pilot scale compost wetland treatment of FGD wastewater for removal of selenium and mercury. Total and dissolved (<0.45um) metals measured using ICP-MS. Total and dissolved (<0.45um) mercury measured using EPA 245.7.


SummaryStudiesDesc:
McMeekin Station conducted a pH control pilot study using caustic soda feed at the ash landfill runoff pond (SPD-3) during 2004-2005.  This study was intended to evaluate need and effectiveness for pH adjustment at NPDES Outfall 002.  The only parameter measured was pH.

OtherStudies:
On going pilot study for an aluminum based coagulant.


SummaryStudiesDesc:
A mercury treatability study is being conducted to determine a possible solution to reduce the mercury concentration in the effluent discharge to a monthly average and maximum mercury permit limit of 1.8 and 3.2 ng/L, respectively.  

Minnesota Power pursued a two-part approach to evaluate potential mercury-reducing technologies.  This approach included optimization studies using the Lamella Clarifier and alternative technologies used in conjunction with or in place of the existing Lamella Clarifier.  The optimization studies included pH, flocculent, coagulant and polymer variation. The alternative technologies described in the Plan included ion precipitation/co-precipitation, adsorption, and fine particulate removal via microfiltration/ultra-filatrion.   Primary measured parameters included total and dissolved mercury and TSS.  Ancillary data collected included sulfates, chlorides, TOC/DOC, Aluminum, Copper, Iron, Selenium, Calcium, Silicon, Phosphates, Antimony, Arsenic, Barium, Beryllium, Boron, Cadmium, Chromium, Cobalt Magnesium, Manganese, Molybdenum, Nickel, Silica, Thallium, Zinc, Alkalinity, BOD/CBOD, Nitrogen, and Phosphorous.

OtherStudies:
American Peat Study, April 2005; Lamella Efficiency and Metal Reduction Study, May 2006; Mercury Evaluation Study, May 2006; Ferrometrics MircuryFilter Pilot, August 2006; Nalco Innovation Center Coagulant/Flocculent Study, June 2009


SummaryStudiesDesc:
Bench scale test of Forced-Air to convert sulfite to sulfate for odor control


SummaryStudiesDesc:
Study #1 - Full scale ferric chloride treatment was studied for arsenic removal in ash pond system.  Total and dissolved (<0.45um) arsenic in-process measurements performed.  Study #2 - Treatment monitoring of in-process ash pond water (and FGD wastewater, if applicable) using ICP-MS measurements for total and dissolved (<0.45um) metals and using EPA 245.7 measurements for total and dissolved mercury.


OtherStudies:
GE Water  performed a bench scale treatability testing in 2009 on samples of seep leachate from the Flint Creek dry ash landfill.  The treatability testing was done to determine the effectiveness of the ABMet selenium removal technology in removing selenium from the landfill seep leachate.  Laboratory, bench scale testing was done with ABMet bioreactors run in series.


SummaryStudiesDesc:
Boron Removal Study, see attached report


OtherStudies:
There have been no ash of FGD waste water treatment technologies studied at SJRPP


SummaryStudiesDesc:
A pilot study to test efficacy of an enhanced constructed wetlands to remove metals and ammonia.  Sytem includes tricking filter, Zero Valent Iron stage, settling/oxidation basin.  Arsenic, selenium and mercury were measured in the influent and effluent, as were nitrogenous compounds, phosphorous, TSS, TDS, etc.  Report is enclosed.


SummaryStudiesDesc:
Full scale study, retiring unlined basins and commencing operation of above-ground settling tanks (see study)


SummaryStudiesDesc:
The I-43 landfill is in the beginning phases of research and pilot testing of wastewater technologies for the treatment of storm water generated from the active portion of the landfill and other areas of storm water generation. No data or other information is available since we are only in the preliminary stages of this project


SummaryStudiesDesc:
Evaluation of FGD blowdown treatment technologies including bioreactor and constructed wetland treatment following chemical wastewater treatment.


SummaryStudiesDesc:
A study evaluating the potential effects of the operation of a newly installed SNCR system on Unit 1 and 2, on Nitrogen concentrations in ash is currently underway.  Smith Plant is collecting data on relevant source and wastewater streams at the Plant.  No wastewater treatment systems are currently planned or presently being investigated as a part of this study.


OtherStudies:
Not Applicable.  No treatment technologies studied by the plant


SummaryStudiesDesc:
See attachments of copy of CDM preliminary arsenic pilot study report and final arsenic pilot study report with attachments and polymer final engineering report (pilot results within)

OtherStudies:
Jar tests with calcium polysulfide & ferric sulfate


OtherStudies:
Other than the current gypsum stacking operation, no FGD wastewater treatment technologies have been studied.


SummaryStudiesDesc:
In order to better characterize the blowdown that might be discharged from the new Plant Crist FGD, Gulf Power installed an operated a pilot scale (5 megawatts) FGD at the Crist Mercury Research Center.  During pilot testing, we were able to obtain and analyze pilot blowdown samples designed to provide useful real life test results of the potential chemical characteristics of the blowdown from the full-sized Plant Crist FGD.  The table attached to Part D of the ICR illustrates the rang of values and maximum values measured from the pilot durin this test period.  Specific wastewater treatment technologies were not evaluated by this pilot.


OtherStudies:
Bench-scale treatablity study conducted by Zenon Environmental Corporation in 2006 for ABMet biological water treatment technology for selenium removal in the FGD scrubber blowdown.


SummaryStudiesDesc:
An observation and slope assessment study was conducted in 2010: see attached document.   An ash pond closure plan was developed in 2010: see attached document.  A partial Affected Property Assessment Report (APAR ) was submitted to TCEQ on September 17, 2010.  A copy of the APAR is provided.  LCRA expects to supplement this partial APAR with additional monitoring data and analyses as it is developed.


OtherStudies:
A bench study was completed using Electrocoagulation as a treatment for FGD waste water.


SummaryStudiesDesc:
The Jeffrey Energy Center rebuilt and placed into service flue gas desulfurization scrubbers during the time period 2008-2010.  As a condition of this change, Westar Energy agreed to complete a Kansas Antidegradation Study to address the control of the resulting water discharge.  The study evaluated the feasibility of several water control technologies and discharges.  The options evaluated included deep well injection, zero discharge through the use of reverse osmosis,  evaporation, and/or crystallization systems, biological treatment through constructed wetlands, and alternative discharge locations.

OtherStudies:
Vacuum filtration and wastewater treatment through settling and clarification were studied and implemented  on the scrubber discharge at Jeffrey Energy Center.


OtherStudies:
Electrocoagulation treatment for FGD wastewater.


OtherStudies:
There hasn't been any studies since 2000.


SummaryStudiesDesc:
A study was conducted by Washington Group International for our Hatfield's Ferry Power Station and used for Fort Martin since the FGD system are the same except for flows.  We are in the process of another study to reduce TDS, Sulfates and heavy metals with Black & Veatch with the study approximately 50% complete.


OtherStudies:
No treatment technologies have been studied.


SummaryStudiesDesc:
The study was to determine if the residence time of the ash pond has decreased to the point in which our NPDES permit for Total Suspended Solids could be exceeded.  Then, determine what alternatives are available to increase the residence time of the pond, possible redesign of the pond, to improve solids removal and water reuse.  Only studies/past routine NPDES permit TSS samples, and bench scale settling tests of the ash were evaluated/conducted.


SummaryStudiesDesc:
A pilot study is presently being conducted at Wateree Station to investigate the addition of Calcium Polysulfide, Ferric Sulfate/Polymer, and Ferric Sulfate.


OtherStudies:
No ash or FGD wastewater treatment technologies have been studied by the plant.


SummaryStudiesDesc:
We contracted with a research group from the University of Florida to look at comparative effectiveness of treating FGD blowdown using electrocoagulation, ion exchange, and zero liquid discharge.  Studies involved the use of benchtop, laboratory-scale experiments.  An array of analytes were measured including selenium, boron, and other constituents of both influent and treated water looking at removal efficiencies associated with each treatment process.


SummaryStudiesDesc:
Various resins were used to evaluate the removal of chromium, selenium, and copper.

OtherStudies:
See attachment "Arapahoe 00583 D2-4.pdf" for details regarding discharge treatment technologies (which included ash) studied at Arapahoe.


OtherStudies:
Nalco chemical to consolidate chemicals.  This bench study was not successful.


SummaryStudiesDesc:
FGD treatment studies just beginning. No description available.


OtherStudies:
We have had no ash or FGD studies done at this facility.


SummaryStudiesDesc:
On-going study of addition of Klaraid PC-1195 (polymer) to bind to FGD blowdown solids to aid in flocculation and settling prior to discharge into other ponds.  Indicators are based on visual clarity and settability.


OtherStudies:
No ash or FGD wastewater treatment technologies have been studied.


SummaryStudiesDesc:
Jar tests were performed to determine if the addition of ferric chloride would be an effective way to increase the removal capability of nickel and vanadium in the Chemical Waste Treatment System (CWTS).  Additionally, the study evaluated additional technologies for the removal of those chemicals.  The alternative treatment technologies evaluated were ion exchange, reverse osmosis, biological treatment, and polymer addition.


OtherStudies:
The plant has not studied alternative wastewater treatment technologies.


OtherStudies:
WPC Study evaluated methods for optimizing existing purgewater treatment system.  2008 GE AbMet report evaluated effectiveness of a biological treatment system on the purgewater.  The 2009 GE AbMet study evaluated treatment methods for cyanide removal in the purgewater treatment system.


OtherStudies:
Studies were conducted in the early 1990's to design the Advanced Waste Water Treatment Plant (WWT-2).


# WWT_System_Information

Climate:
All reaction vessels indoors or underground


Climate:
Eguipment in heated building due to freezing temperatures

Space_Avail:
Dependant on space requirements of any new addition system


No_Bid_Explanation:
No bid proposals, or engineering reports prepared since January 1, 1995 for the wastewater treatment system.


Climate:
Equipment is housed inside due to cold winters.

Space_Avail:
Space availability had no impact on the design of the treatment system.


Climate:
Arctic climate requires all equipment to be indoors

No_Bid_Explanation:
Whatever bids were prepared and analyzed for construction of HCCP (SE Unit 2) wastewater system are not available at this time.  Although plant was built after 1995, what was built is what is available, not all of the engineering analysis to decide what that would be built.


Climate:
Piping and control systems are housed indoors due to being in a cold climate

Space_Avail:
Dependent on location of any wastewater treatment systems there could be space constraints, and location of anything new in an existing plant always require additional changes.


No_Bid_Explanation:
No bid proposals or engineering reports prepared since 1995


No_Bid_Explanation:
There have been no bid proposals or engineering reports prepared since 1/1/1995 for this system.


Climate:
For SBR, chillers needed in summer and heaters in winter


Climate:
Due to cold winter climate, equipment containing water will need to be protected from freezing.

Space_Avail:
Due to limited space, the existing WWF pond was constructed to the maximum size per surrounding obstacles (P7&P8 discharge canals, coal conveyor, & plant discharge).  Significant costs expected if pond or WWF required expansion.


Climate:
All piping is heat traced and insulated.

Space_Avail:
Space for any future additions is limited.


No_Bid_Explanation:
This treatment system consists of gypsum thickeners and ponds that are used for process water storage.  The thickeners have not been upgraded since 1995.  The ponds were lined with HDPE and covered with pozzolinic material in the late 1990's but were not improved for wastewater treatment.


Climate:
Filter presses, filter press feed pumps, clarifier sludge pumps, lime feeder and chemical metering pumps (polymer, sulfuric acid, ferric chloride) were installed inside a building or an enclosure to protect the equipment in winter.

Space_Avail:
Using smaller, separate enclosure buildings for the clarifer sludge pumps reduced the size of the main building for WWT system and thus, reduced costs. Sufficient space was available to locate all of the equipment in the area as needed, but any future addition of other equipment will become a challenge since the size of the main building is fixed.


Space_Avail:
Using smaller, separate enclosure buildings for the sludge and effluent pumps reduced the size of the main building for WWT system and thus, reduced costs. Sufficient space was available to locate all of the equipment in the area as needed, but any future additions of other equipment will become a challenge since the size of the main building is fixed.


Climate:
Some equipment had to be housed indoors, other components had to be heat traced and insulated


Climate:
Some equipment presently is housed indoors due to being in a cold climate.

Space_Avail:
Sammis Plant has virtually no remaining space for any wastewater treatment systems.  Space was constrained from the beginning due to location of the plant, and the recent addition of air quality control systems took almost all remaining space.


No_Bid_Explanation:
There have not been any bid proposals or engineering reports submitted since 1995.


Climate:
Wastewater units were constructed within a wastewater treatment facility building.  Outdoor piping from sedimentation basins to the wastewater treatment building is either insulated or heat-traced due to cold weather conditions during winter months.

No_Bid_Explanation:
System was designed and installed circa 1987.


Climate:
Piping heat traced, chemical addition tank indoors, continuous low flow during coldest weather


No_Bid_Explanation:
No proposals or reports were submitted to the plant since January 1, 1995.


Climate:
Heat tracing on some of the chemical feed lines and chemical tanks enclosed in heated builidng.


Climate:
All equipment installed in a heated building.

No_Bid_Explanation:
This information was not readily available.


Climate:
Extreme cold weather necessitates wastewater treatment equipment and chemical storage occurs inside, and external pipe runs need constant flow to prevent freezing

No_Bid_Explanation:
No bid proposals or engineering reports for WWT-1 since January 1, 1995.


No_Bid_Explanation:
Answer is "I have attached the engineering report"  Spreadsheet will not allow de-selection of  "I did not attach…."


Climate:
There is no WWT system and none planned. Not applicable.

Space_Avail:
There is no WWT system and none planned. Not applicable.

No_Bid_Explanation:
System was installed in 1992.  No bid proposals were prepared since January 1, 1995.


Climate:
Treatment system installed indoors due to cold winters.

No_Bid_Explanation:
No relevant bid proposals or engineering reports have been prepared since 1995.


Climate:
Biological treatment components are housed inside a building.  PLC equipment reqired to be housed inside.

Space_Avail:
System had to be located approximately one mile from source of wastewater to have sufficient area for settlig ponds, etc.


Climate:
Piping heat traced.  Chemical feed equipment is indoors.  Continuous low flow in winter.


No_Bid_Explanation:
No engineering reports or proposals were prepared for the wastewater system since January 1, 1995.


Climate:
Entire waste water system from equalization tank forwarding pumps to discharge pumps had to be installed inside a building to prevent freezing in addition to adding freeze protection to all the services supplying the waste water treatment building.

Space_Avail:
The waste water treatment building had to be placed in a location that required the relocation of the gypsum handling system and due to the weight of the equipment the subsurface had to be stabilized and the entire facility erected on caissons.


Climate:
Some equipment iseither housed inside or heat traced due to winter freezing.

No_Bid_Explanation:
System has not been changed nor proposals or reports generated.


Climate:
Some equipment had to be housed inside due to cold winters.


Climate:
Entire wastewater plant is located outside.  System is heat traced and insulated as needed.  Water must continually flow for freeze prevention.


No_Bid_Explanation:
No bid proposals solicited -majority of work done in-house


Climate:
Wastewater Treatment System located indoors due to cold winters.


Climate:
Wastewater Treatment Systems installed indoors due to cold winters.

No_Bid_Explanation:
The wastewater treatment system clarifiers were replaced in 2003; however, a formal engineering report was not prepared for that work.


Climate:
Equipment is housed inside due to cold winter climate.


Climate:
All equipment is housed outdoors. Outdoor caustic tank includes a heater to maintain temperature above 65 deg F in cold weather.


Climate:
Non self draining pipes under 8" diameter are insultated and heat traced.


Climate:
Heat tracing and insulation on pumps and piping at the mixing basin due to winter weather.

Space_Avail:
Crane head space needed for pumps at mixing basin for maintenance.


Climate:
Most equipment housed indoors.  Outdoor equipment has been insulated.

No_Bid_Explanation:
Preliminary analyses and design prepared specifically for the Asheville FGD blowdown composition.


No_Bid_Explanation:
System installed prior to January 1, 1995


Climate:
Dewatering bins are located indoors to prevent freezing

No_Bid_Explanation:
The facility is unaware of  proposals/engineering reports generated since 1995 for WWT-1.


No_Bid_Explanation:
The facility is unaware of  proposals/engineering reports generated since 1995 for WWT-2.


No_Bid_Explanation:
The facility is unaware of  proposals/engineering reports generated since 1995 for WWT-3.


No_Bid_Explanation:
The facility is unaware of  proposals/engineering reports generated since 1995 for WWT-4.


Climate:
Heated regulator required to regulate CO2 pressure form storage tank.


Climate:
Wastewater Treatment System is located indoors due to cold winters.

Space_Avail:
Edge of coal storage area had to be reconfigured and warehouses had to be removed and replaced to accommodate the treatment building.


Climate:
System located indoors due to hot and cold weather extremes and precipitation.

Space_Avail:
Space availability was not an issue for this facility.


Climate:
Waste water treatment equipment has to be kept indoors during cold weather temperatures.

No_Bid_Explanation:
No bid proposals and/or engineering reports prepared since January 1, 1995 for the wastewater treatment system.


Climate:
The ferrous sulfate solution used for hexavalent chromium reduction crystallizes at temperatures less than 40 Farenheit.  Ferrous sulfate is fed during warm months outside of the pH building; moved inside during the cooler months.

No_Bid_Explanation:
No bid proposals and/or engineering reports have been prepared since January 1, 1995 for the wastewater treatment system.


No_Bid_Explanation:
Systems has been operational since 1986.


Climate:
some algae growth around weirs during summer in SPD-1 and SPD-2


Climate:
The system is heat traced and insulated to protect equipment to 10 degrees F.

No_Bid_Explanation:
This system was installed in 1985.  No engineering reports are available.


No_Bid_Explanation:
This is not bid proposal or engineering report avaialbe.


Climate:
Filter presses, filter press feed pumps, clarifier sludge pumps, lime feeder, lime slurry pumps, secondary clarifiers, clarifer feed pumps, sumps, sump pumps and chemical metering pumps (polymer, sulfuric acid, ferric chloride) were installed inside a building or an enclosure to protect the equipment in winter.

Space_Avail:
Sufficient space was available to locate all of the original equipment in the area as needed, but any future addition of other equipment will become a challenge since the size of the main building is fixed and there is little to no spare area inside the existing building. In addition, there is limited space available outside the existing WWT system building to accomodate any future equipment.


Climate:
All equipment was housed inside due to cold winters except equilization tanks, sludge holding tanks, and upper portion of hydrated lime powder storage silo.


Climate:
Heat tracing and insulation was used to prevent freezing.


Climate:
Some of the equipment is indoors due to being in a cold climate

Space_Avail:
This would be dependent on size and location of additional equipment


Climate:
Small diameter non self draining lines require insulation and heat tracing.


Climate:
Process equipment located indoors due to harsh winter climate


Climate:
Equipment located indoors to protect from weather.


Climate:
Some Equiptment is housed inside due to cold winters


Climate:
Installed steam sparging in tanks, heat trace and insulation on outdoor piping, and pumps/controls are located in an insulated/heated building.

Space_Avail:
No space constraints at time of construction.

No_Bid_Explanation:
Treatment system was constructed prior to 1995.


Climate:
Pipe is insulated for freeze protection.  Equipment stored indoors till time for installation. Tank installed during appropiate weather conditions.


Climate:
Small diameter non self draining pipes require insulation and heat tracing.


No_Bid_Explanation:
System was installed with the original plant design. This information is contained in the COC and other permit applications.


Climate:
Heat trace and insulation necessary to protect equipment in winter.


Space_Avail:
Designed and chose equipment for smaller footprint

No_Bid_Explanation:
The WWTP was built prior to 1995.  A dry polymer system was added to th WWT System post 1995.  The system equipment costs totaled $32,000 and the installation costs totaled $44,000.


Climate:
For the physical-chemical units, small diameter non self draining piping had to be heat traced and insulated.

Space_Avail:
For the physical-chemical units, limited space availability restricted the location of the facility and restricted truck access for sludge off loading. Space availability limited the number of wetlands cells/hydraulic resistance time that could be installed.


Climate:
For SBRs chillers needed in summer and heaters in winter.


No_Bid_Explanation:
cost unknown, we could not locate the bid and or engineering reports for the systems


Climate:
Warm climate allowed all wastewater treatment to be located outdoors.

Space_Avail:
Current system utilizes all available space


Climate:
A significant investment was made to house the filter presses, gravity filters,  and associated pumps.  Insulation and heat tracing was also installed on miscellaneous lines to protect from freezing.


Space_Avail:
There is a space limitation in the area of the exisiting WWTF.  Additional WWTF equipment, if necessary, would have to be installed elsewhere.

No_Bid_Explanation:
No Engineering or bid proposals or engineering reports have been requested or received.


Climate:
Some wastewater treatment system components were installed indoors due to cold winters.


Climate:
Equipment installed indoors due to cold winters.

Space_Avail:
Limited space available due to location between bluff and lakeshore.  New treatment building and equipment was installed as part of Elm Road Generating Station project.


Climate:
Most equipment is located indoors due to winter climate, building is heated and insulated. Large tanks are outdoors


Climate:
Equipment located inside heated building for protection from weather.

Space_Avail:
Additions/modifications to the filter building will involve significant engineering due to space limitations.

No_Bid_Explanation:
No bid proposals/engineering reports since 1995


Climate:
piping and control system are presently housed indoors due to being in a cold climate


Climate:
Bioreactor housed inside building to help keep bacteria alive and thriving during winter months.

No_Bid_Explanation:
No engineering repoerts for this site, needs for waste water treatment were based off enginnering reports for Progress Energy's Roxboro Steam Electric Plant.


Climate:
All equipment located inside building to protect against cold weather.

No_Bid_Explanation:
Bid proposals other than those included in the enclosed engineering reports are not available.


Climate:
A significant investment was made to house the filter presses, gravity filters,  and associated pumps.  Insulation and heat tracing was also installed on miscellenious lines to protect from freezing.


No_Bid_Explanation:
With the expansion of JKS2, the clarifier was replaced with a larger capacity unit and was part of the scope of work for JKS2 expansion.


No_Bid_Explanation:
There have been none prepared since January 1, 1995.


Climate:
Chemical feed equipment is inside a building.  Heat tracing and insulation is on outdoor piping.


Climate:
Treatment units were placed below ground and controls are housed inside due to cold winters.

No_Bid_Explanation:
The system was last updated in 1987.  No bid proposals or engineering reports were prepared since January 1, 1995.


Climate:
Equipment will be either inclosed or heat traced and insulated

Space_Avail:
Distance from FGD makes transport problematic


Climate:
Piping had to be heat traced to protect against freezing in the winter.

Space_Avail:
System had to be designed to include previous equipment already installed that was being used as part of this system.


Climate:
Portion of system contained within building


Climate:
Most equipment located inside for freeze protection. Piping is heat-treated or flushed.

Space_Avail:
Space is limited to add any additional large wastewater equipment.


Climate:
Most equipment located indoors except for settling basins (Pond-2), Lime slurry tanks are heated and insulated.


Climate:
All equipment /tanks inside building w/exception of the EQ Tank


Climate:
Minimal impacts expected.  However, it is an indoor facility with heat traced and insulated lines.

Space_Avail:
Space for facility was very limited.  WWT plant was designed to fit into a very compact area.

No_Bid_Explanation:
Neither the bids nor the engineering report for the FGD wastewater treatment facility, WWT-1, are available. The bid process occurred several years ago and construction was completed in 2008. The person in charge of this project is no longer with the company and we have been unable to locate bids in his historical files.


Climate:
Portion of the system is enclosed.  Other winterization considerations were heat tracing & line insulation.

No_Bid_Explanation:
Costs associated with the FGD wastewater treatment system are included in Section 6.1.  The report is attached and entitled, "Pilot Study Report WWT Bio-Plant 3-28-07.pdf" .


Climate:
Cold weather may impact efficacy of metals removal.

Space_Avail:
Land availability may hinder utilization of this technology.


Climate:
No protection - Clarifier outdoors, remaining process unit equipment housed inside heated building

Space_Avail:
Facility had ample space available for equipment

No_Bid_Explanation:
Table D-15 WWT-1 includes detailed capital cost for the waste water treatment system.


No_Bid_Explanation:
No bid proposals have been prepared since January 1, 1995 for the wastewater treatment system.


Climate:
Clarifier and mixing tank are located inside a building for winter protection. During cold weather, the geobag may freeze up and require extra measures to restore flow. During hot weather, the geobag can become slimed up and require mechanical agitation to restore flow. Wether changes can cause the water in the coal runoff pond to invert and cause large pH changes.


Climate:
Warm climate allowed most of the treatment system to be located outdoors.

Space_Avail:
Space was a available for Process Wastewater Treatment system (PWTS) close to the Process Water ponds on the plant site site.  No Space restrictions.

No_Bid_Explanation:
Process Wastewater Treatment System (PWTS) was started up in 1989


Climate:
All outside piping associated with the WWT system is heavily insulated as well as heat treated to protect the lines from freezing. Generally, the dewatering process is discontinued durning the months of December, January and February due to cold weather.

Space_Avail:
The installation of the present Waste Water Treatment System  (steel containment Clarifiers) abandoning the 002 Lagoon (unlined Pond) was as a result of a cost comarison between the present system compared to new pond/lagoon with a liner.


Space_Avail:
All the Process Water Reclamation Facility Equipment is tightly housed in a partially enclosed location.  No room for expansion.

No_Bid_Explanation:
No bid proposals on the treatment system.


Space_Avail:
All FGD Wasterwater Treatment Equipment is tightly housed in am enclosed building.  Limited room for expansion.


Climate:
Wastewater treatment equipment is housed indoors to protect from weather (freezing) and to provide shelter for operators.

Space_Avail:
If additional wastewater treatment is required, an additional building will be required (no room for expansion in current building)


Climate:
The water discharging into the thickener is warm enough to allow the thickener to be outside without any insulation.

Space_Avail:
It was installed with original construction of the plant, so space was not an issue.

No_Bid_Explanation:
There have been no bid proposals or engineering report on the thickeners since Jan 1, 1995.


Space_Avail:
Must have enough space available for plant footprint.


Space_Avail:
Space availability was not an issue when this treatment system was designed.  Space availability would preclude installation of some types of treatment equipment.

No_Bid_Explanation:
Attached as responses to EPA Questionnaire D5-10 are bid documents for the construction of this system.  Some bids included work on this wastewater treatment system and upgrades to the FGD process and are not separated by type of work being done.  Examples include piping and electrical.


Space_Avail:
Space availability was not an issue when this treatment system was designed.  Space limitations are not an issue at this location.

No_Bid_Explanation:
An engineering report by Puckorius & Associates is supplied and designated as EPA Questionnaire D5-10 WWT-3


No_Bid_Explanation:
Not applicable; units are original to the facility and began operation in 1992


Climate:
The wastewater treatment plant at IMP 102 (SPD-1) was enclosed to protect the tanks and equipment from implement weather.


Space_Avail:
Using smaller, separate enclosure buildings for the sludge and effluent pumps reduced the size of the main building for WWT system and thus, reduced costs. Sufficient space was available to locate all of the equipment in the area as needed. However, any future additions of other equipment will become a challenge since the size of the main building is fixed and there is limited open space available in the vicinity of the WWT-1 system.


Climate:
Equipment had to be located indoors due to cold weather climate.

Space_Avail:
Costs increases due to fitting the wastewater treatment system units into tight spaces.

No_Bid_Explanation:
No proposals and/or engineering reports since January 1, 1995.


# WWT_Systems

Plant_Desig:
Central Wastewater Treatment Facility (CWWTF)


Plant_Desig:
Chemical Metal Cleaning Wastewater Treatment System (BTCW)


Plant_Desig:
Underground Injection Control (UIC) System


Plant_Desig:
Runoff Pond-Wet Well- Neutralization-OW Separator


# WWT_Units

WWTU_ID:
Chemical Precipitation Reaction Tank 1 - 1


WWTU_ID:
Chemical Precipitation Reaction Tank 2 - 1


WWTU_ID:
Chemical Precipitation Reaction Tank 2 - 2


WWTU_ID:
Chemical Precipitation Reaction Tank 3 - 1


WWTU_ID:
Chemical Precipitation Reaction Tank 3 - 2


WWTU_ID:
Chemical Precipitation Reaction Tank 1 - 2


WWTU_MOC_Other Desc:
SA515-gr.70 w/ Plasite no. 7155HHB coating, 304 s.s.


WWTU_Plant_Desig:
Constructed wetlands--dual train, 4 cells each


WWTU_Plant_Desig:
Chemical Metal Cleaning Wastewater Treatment Basin


WWTU_Plant_Desig:
CONTINUOUS BACKWASH GRAVITY FILTERS FLT-S


WWTU_Plant_Desig:
Oil Water Separator (part of the equalization basin (SPD-3))


WWTU_ID_Other:
Chemical Precipitation Reaction Tank 4-1


WWTU_MOC_Other Desc:
steel frame, polypropylene plates with filter fabric


WWTU_MOC_Carbon_Liner:
Multipart system of glass mat and Ceilcote


WWTU_MOC_Other Desc:
compacted mixed soils & partial liner on eastern upstream side


WWTU_MOC_Other Desc:
Earthen with Poz-O-Pac liner and hypolon sides


WWTU_MOC_Carbon_Liner:
A-36 carbon steel, no information regarding a liner, painted with 1 coat Amercoat 64 and 2 coats Amercoat 66


WWTU_MOC_Carbon_Liner:
painted with 1 coat Amercoat 64 and 2 coats Amercoat 66


# WWTS_Ancillary_Equip

WWT_Anc_Equip:
lime slurry pump(adds hydrated lime slurry to system for pH adjustment


WWT_Anc_Equip:
Chemical Storage Tanks (HCl, Urea, Phosphate, Ferric Chloride)


WWT_Anc_Equip:
WWT Feedwater Tank with Pumps (2) and Agitator


WWT_Anc_Equip:
Clarifiers with Rakes and Turbine Drives


WWT_Anc_Equip:
Vacuum Filters with Vacuum, Filtrate, and Feed Pumps


WWT_Anc_Equip:
Pump, wastewater (forwarding water from the equalization tank to Reaction Tank 1)


WWT_Anc_Equip:
Pump, sludge (serving underflow from the clarifiers)


WWT_Anc_Equip:
Pump, sludge (filter press fast fill pumps)


WWT_Anc_Equip:
Pump, wastewater (forwarding water from the filtrate sump to the equalization tank)


WWT_Anc_Equip:
Pump, wastewater (forwarding water from the physical-chemical system to the bioreactor system)


WWT_Anc_Equip:
Pump, wastewater (First stage effluent transfer pumps)


WWT_Anc_Equip:
Pump, wastewater (Second stage recycle/recirculation pumps)


WWT_Anc_Equip:
Pump, wastewater (Bio reactor backwash pumps - pump the water from the first and second transfer tanks back through the bioreactors)


WWT_Anc_Equip:
Pump, wastewater (Send wastewater from the backwash holding compartments to the equalization tank)


WWT_Anc_Equip:
Chemical Feed System (sulfide, ferric chloride, polymer, hydrochloric acid, nutrient)


WWT_Anc_Equip:
Pump, wastewater (forwarding water from the effluent tank to the ash basin)


WWT_Anc_Equip:
Pump, wastewater (secondary containment sump pump, forwards wastewater from secondary containment to the filtrate sump)


WWT_Anc_Equip:
Pump, forward feed (water from EQ tank to coagulation tank)


WWT_Anc_Equip:
Pump, sludge (filter press feed pumps - feeds sludge to filter press operations)


WWT_Anc_Equip:
No ancillary Equipment associated with POND-3, WWTF


WWT_Anc_Equip:
Pump, wastewater (filtrate sump pump, pumps the wastewater from the filtrate sump back to the equalization tank)


WWT_Anc_Equip:
Pump, wastewater (wastewater forwarding pump, transfers wastewater from the equalization tank to the reaction tank)


WWT_Anc_Equip:
Pump, wastewater (forwarding water from the wetlands supply tank to the ash basin)


WWT_Anc_Equip:
Service Water System (tank, pumps, filters)


WWT_Anc_Equip:
Pump, wastewater (pumps water from the effluent tank to the ash basin)


WWT_Anc_Equip:
pump, wastewater, stormwater runoff to water tanker


WWT_Anc_Equip:
pump, wastewater, stormwater runoff to POND-2


WWT_Anc_Equip:
sludge pumps(recircing clarifier underflow and transferring sludge to holding tank prior to solids separation


WWT_Anc_Equip:
Sump Pumps (WWT-1, lime building pumping treated water to settling basins (pond-2)


WWT_Anc_Equip:
Piping (relocating piping to settling basins, transport)


WWT_Anc_Equip:
Secondary Clarifier Sludge Blowdown Pumps


WWT_Anc_Equip:
Chemical Feed System ( Sulfuric acid and Sodium hydroxide)


WWT_Anc_Equip:
Pump, wastewater (transfer from pH 1 tank to pH 2 tank)


WWT_Anc_Equip:
Pumps, WWT clarified water (from clarifier to multimedia filters)


WWT_Anc_Equip:
Chemical mix skid, Polymer mixing and injection (feed at entrance to clarifier)


WWT_Anc_Equip:
Pump (To transport coal pile runoff water to contact basin and chemical addition equipment)


WWT_Anc_Equip:
Sludge Pump (Transfer coal solids to truck load out)


WWT_Anc_Equip:
2,325 ft of 10 in. diameter HDPE force main


WWT_Anc_Equip:
Pumps, sludge (sludge tank to belt press)


WWT_Anc_Equip:
Wastewater transfer pumps (SPD-3 to SPD-2)


WWT_Anc_Equip:
Chemical feed system (ferric chloride, polymer)


WWT_Anc_Equip:
Pump, sludge (serving underflow from clarifiers)


WWT_Anc_Equip:
Pump, sludge (filter press fast fill pumps - transfers sludge from the sludge holding tank)


WWT_Anc_Equip:
Pump, wastewater (forwarding water from the equalization tank to the primary clarifier)


WWT_Anc_Equip:
Pump, wetlands (wetlands supply tank to wetlands equilization basin)


WWT_Anc_Equip:
Pump, wastewater (forwards water from the wetlands supply tank to the constructed wetlands treatment system)


WWT_Anc_Equip:
Pump, wastewater forwarding (from equilization)


WWT_Anc_Equip:
pump, waste water and recirc pump (at pond)


WWT_Anc_Equip:
Slurry pumps (recycling flush water back into the FGD reagent prep system)


WWT_Anc_Equip:
Ventilation Fans (for controlling fugitive dust)


WWT_Anc_Equip:
Pump,wastewater (south lagoon effluent to WWT influent)


# WWTS_Pld_Improvements

Pld_WWTS_Desc:
Install impoundment/wetland on discharge of WWT-1 to treat partial discharge of WWT-1.


Pld_WWTS_Desc:
First train of CWTS cells will be converted to vertical flow cells.


Pld_WWTS_Desc:
Clean and reuse 5,050 gallon indoor chemical tank for ferrous sulfate addition


Pld_WWTS_Desc:
addition of sand filtration to remove effluent mercury


# WWTU_Chem_Addn

WWTU_ID:
Chemical Precipitation Reaction Tank 1 - 1


WWTU_ID:
Chemical Precipitation Reaction Tank 2 - 1


WWTU_ID:
Chemical Precipitation Reaction Tank 3 - 1


WWTU_ID:
Chemical Precipitation Reaction Tank 1 - 2


WWTU_Chem_Purpose:
Coagulation of suspended solids in the IWT and sedimentation basins.


WWTU_Chem_Purpose:
pH adjustment, desaturate CaSO4, precipitate heavy metals


WWTU_ID:
Chemical Precipitation Reaction Tank 2 - 2


WWTU_Chem_Purpose:
pH neutralization when sodium hydroxide is not available or unable to maintain system pH


WWTU_Chem_Purpose:
ph adjustment, desaturization, and precipitation


WWTU_ID_Other:
Flue Gast Desulphurization (FGD) Scrubber Sludge Pond (Outfall 109)


WWTU_ID:
Chemical Precipitation Reaction Tank 3 - 2


WWTU_Chem_Purpose:
promote flocculation of suspended solids


WWTU_Chem_Type:
Flocculation agent for filter press when operational


WWTU_Chem_Purpose:
pH adjustment to ensure proper solids ratio.


