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emissions   Hog Farms photos, Pulp mill photos, Rendering Plants,50% Honeybee Disease photos, US EPA Coal Combuster photos


Live Animal Producers (hog/cattle/poultry)
1500-3500ppb of ammonia/hydrogen sulfide/PM10 odor TO 13-14 ppb,
Pulp Mills - hydrogen sulfide/methyl mercaptan odor etc premeasured at 400-2500ppb TO 6ppb,
Rendering Plants -ammonia/methyl mercaptan odor measured at 600-1500ppb,
Mysterious Honeybee 50% Losses in Fall Dwindle Disease

We calculate control units needed to reduce each CO, CO2, SO2, Nox, VOC, PM10/2.5 and Mercury Air
Emissions at following levels: 4, 40, 400, 4,000, 40,000 and 400,000 TONS PER YEAR.

From 1996 to 2003, we tested our control equipment by visually observing the air emission reductions at
power plants, forest fire smoke plumes, pulp mill and live animal sites.

March 25 & 26, 2004 Hog farm test-Ohio


Ohio Pork Association Executive Director Dick Isler (614-882-5887) arranged an Ohio Hog producer Bill Ringler
to have us install our control equipment at two 5000 and 7000 hog farm sites about five miles apart for 17 hour test.
Hog SMELL adds Hydrogen Sulfide 1500-3500 ppb. PulpSmell is Methyl Mercaptan, Dimethyl Sulfide,
Phenols & Dimethyl Disulfide at 1-300ppb. We eliminated these SMELLs and lowered ppb odor in 17 hours at each site.

On March 25 at 4pm, Air emission at 5000 hog farm (two10MM gallon) lagoons measured 2711 ppb ammonia
& 3155 ppb hydrogen sulfide. At 7000 hog farm (two15MM gallon) lagoons, air was 3101ppb ammonia
& 3210 ppb hydrogen sulfide.
On March 26 at 8:30 am, Air emission measured at 5000 hog was down to126 ppb ammonia and 132 ppb
hydrogen sulfide but NO SMELL/NO ODOR and at 7000 hog farm at 9:30am measured 220 ppb ammonia
and 192 ppb hydrogen sulfide.

Our 92-95% reduction in 17 hrs was excellent but we improved by adding secondary outside unit on next confirmed tests.

We can do tests using Ultra Violet measurement when available to confirm hydrogen sulfide measurements
and/or FTIR for ammonia measurements to compare to our proprietary measurements. A before measurements
of ammonia & hydrogen sulfide are typically 500 to 3000 ppb per USDA & US EPA.This smell desensitizes
nasal passages & these compounds rust metal.

Power plants air emissions include Sulfur Dioxide(SO2) {800-2500ppm},  Nitrogen Oxide (NOX){100-500ppm}, 
Carbon Monoxide (CO){2.25ppm},  Particulate Matter-10 micron (PM10){1.5-2.0ppm}, Particulate 
Matter 2.5 micron (PM2.5) {1-2.0ppm},  Volatile Organic Compound (VOC){NA},  Ammonia{NA} and
Hydrogen Sulfide{NA}.

We did test observations at western US power plants in 2001-03, western state forest fires, North Carolina
pulp mill in 2003 and test labs. We saw cleaner air in one to three days, NO ROTTEN EGG SMELL
(hydrogen sulfide) & better environment.

To confirm our visual tests, we developed a proprietary measurement capability & worked with US EPA
 who implemented use of Open Path FTIR (fournier transformer infrared) spectrograph photos in two or
three dimensional illustration to verify SO2, NOX, CO, PM2.5, PM10, VOC and Ammonia and Hydrogen
Sulfide with UltraViolet combination. We do work with associations, private companies & consumers.
We ID/PREmeasure air emissions & determine control units needed per site.

We did tests to observe and video tape FTIR test measurments at hog farms, pulp mills, power plants
and tested pilot plants for fossil fuels when equipment was available or used our proprietary measurement
method with still photos attached here.

NC HOG FARM-June 13/14,2004-99.4% reduction ammonia & hydrogen sulfide


On June 13-18, 2004 week, we tested air emissions at Asheboro, NC Hog Farm. Farm has 770 hogs in
each of 11 houses & three large lagoons.  The tests show 2221 ppb of ammonia & 2242 ppb of  hydrogen
ulfide on June 13, 2004 at 3pm. 
We installed one primary control inside unit in office area and one secondary unit outside office.  At 9 am
on June 14, 2004, the measurements were 13 ppb of ammonia and 14 ppb of hydrogen sulfide but
no detectable smell or odor to tester.
We appreciate and thank Mr Roy & JoAnn Chriscoe owners for their cooperation to offer their facilities for testing.

NC PULP MILL-June 14/15,2004-98.6% reduction hydrogen sulfide


On June 14, 2004 in Roanoke Rapids, NC at 5 pm, we tested hydrogen sulfide air emission of pulp mill
at two offsite locations.  The first location was 500 yards south of pulp mill stack at local Faith Tabernacle
Church on Washington Street Extension and measured 422 ppb of hydrogen sulfide.  The church deacon
Eugene Parks advised us his car had rusted out from hydrogen sulfide in air but car motor functioned very well. 
We installed one primary unit in church meeting room facing pulp mill. The second location was one mile north
of pulp mill stack at Mr Mead residence on Ray Street in Gaston, NC & measured 1323 ppb of hydrogen sulfide.
 Mr Mead advised us this was not the worst bad-smell day. We installed one primary unit in his home facing pulp mill.
 An outside unit was placed behind his home for secondary clearing.  We PREmeasured control units needed.

At 9 am on June 15, 2004, the results at both church 500 yards south of pulp mill stack and residence one mile
north were six (6) ppb of hydrogen sulfide and a .75" rainfall per City Planner.  Hydrogen sulfide was reduced
by 98.6% to 99.3%.
We appreciate Pastor Charles Arnold and Deacon Eugene Parks of Faith Tabernacle Church in Roanoke Rapids, NC
nd Mr Mead of Gaston, NC for their cooperation and confidence in providing their facilities to ID/measure air emissions
nd install our equipment to reduce air emissions of Pulp Mill in Roanoke Rapids, NC.
We thank pulp mill owner environmental staff at International Paper for reviewing data results of our reducing air
emissions below the 120 ppb hydrogen sulfide air emission as a proposed requirement by NC regulations.



On June 16, 2004 at US EPA test site in Research Triangle Park, NC at 8 am, we observed US EPA
contractor testing new coal combustor using natural gas to heat to 2000 F for two hours.  At 10 am,
contractor switched to pulverized bituminous coal with 18% ash and 1.5% sulfur for shake out tests.
The combustor was rated at 4 million BTU/hour using either 333 pounds per hour of 12,000 BTU coal
or 28.8 gallons of fuel oil or 3,840 standard cubic feet per hour of 1020 BTU natural gas.  They operated
 at 50% of capacity but still had 4000+ cubic feet per minute of air through combustor and 1000 cubic feet
per minute flue gas flows thru stack.  The combustor system had surge bin hopper with four hours of coal,
screw and gravity conveyor and air flow delivery back to top of 40+ foot combustor.  The flue gas flow was
to three heat exchangers, one bag house and one wet scrubber with  limit of 150F exit emission stack gases.
 Most plants are 270F+ without wet scrubber.  EPA Contractor confirmed .16"+ rain in 17 hrs as with lower emissions.

The US EPA had no continuous monitors attached to any portals of combustor yet.  They used a FTIR-open path
with passive mode to measure stack's heated exit emissions.  It was to provide a clear resolution of infrared
measurements if temperature exit stack gases are at least 270F but assured us they could give us measurement
f at 150F per EPA staff person.

Our objective was to confirm our proprietary test measurements compared with EPA's FTIR and reduce air
emissions level of flue gases. We did measurements for Sulfur Dioxide, Carbon Monoxide, Carbon Dioxide,
Nitrogen Oxide, Particulate Matter 10 micron, Mercury, Hydrogen Sulfide to check US EPA.  We await results
of coal emissions by US EPA FTIR collected.

We conclude the Hog Farms and Pulp Mill air emissions reduced an average 5-6% an hour during first 17 hours
with one or two primary units & secondary unit as PREmeasured.  EPA combustor plugged with ash/clinker
after 3.5 hours & operated 45-50 minutes after we activated our primary units. It was long enough to see same
consistent hourly reduced air emissions.

ICT control units do not emit any measurable radiation signal & are safe per David Proffitt and
Ed Brown of Arcadis-US EPA prime contractors & operators who stated "your control equipment can not interfere
with combustor operation". Large plants CO2 reductions are 47.1% in + 50.1% outside stack at 42 ft where backround level starts.

After 45 minutes, we had percentage reductions based on actual measurements and projected reductions after17 hours as follows:                                                   
                                                      after 45 minutes reduction %         after 17 hrs projected
SO2    sulfur dioxide                                         -14%                                  -97.5%
CO      carbon monoxide                                  -26%                                   -97.6%
CO2    carbon dioxide                                      -46%                                   -97.6%
PM10   particulate matter 10 micron                 -20%                                   -60%  BAG house has low emissions.
Nox      Nitrogen Oxide                                   -19.6%                                -96%
Mercury                                                           -13.7%                               -90%
Hydrogen Sulfide                                              -10.9%                                -98.3%
Each coal, oil, natural gas or other process will require one or more primary units and secondary units based on
cubic feet per minute of their air emission flows.  The flue gas flows range may be 100 to 2,000,000 cubic feet per minute.

We are doing test using flue gases in static cell to confirm our test measurements. 

We thank US EPA at Research Triangle Park, NC for their cooperation in helping us review, monitor and pretest
heir combustor before and after use of our control equipment and compare their state of art FTIR measurement
equipment to our proprietary measurement method.  A special thanks to Mr. Robert Hall, Mr. Shannon Senne,
Mr. Bruce Harris, Mr.Harris's assistant, combustor contractor employees Mr. Ed Brown and Mr. David Proffitt. 

We can reduce air emissions of power plants using coal, gas or oil as performed at US EPA coal, gas & oil plant.
See details.

HYDRO POWER PLANTS watersheds are 360 to 1800 square miles MUST lower charged air particle
density/lower fugitive air emissions to obtain normal rainfall of .20" to.75"+ a day to improve and maintain a
onstant CFS flow rate with head pressure to drive hydro turbines and generate electricity.  Most hydro has
100% water flow in spring March/April/May & in fall Nov with snow melt & rainfall but UNreasonable rainfall
June/July/Aug/Sept/Oct and Dec/Jan/Feb from higher air pollution/ charged particle density to obtain only
 38% annual operating rate unless water storage available.


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