1146-1

(Adopted September 9, 1988)(Amended January 6, 1989)

(Amended May 13, 1994)(Amended June 16, 2000)

(Amended November 17, 2000)

RULE 1146. EMISSIONS OF OXIDES OF NITROGEN FROM

INDUSTRIAL, INSTITUTIONAL, AND COMMERCIAL

BOILERS, STEAM GENERATORS, AND PROCESS

HEATERS

(a) Definitions

(1) ANNUAL CAPACITY FACTOR means the ratio of the amount of fuel

burned by a unit in a calendar year to the amount of fuel it could have

burned if it had operated at the rated heat input capacity for 100 percent of

the time during the calendar year.

(2) ANNUAL HEAT INPUT means the actual amount of heat released by

fuels burned in a unit during a calendar year.

(3) BOILER or STEAM GENERATOR means any combustion equipment

fired with liquid and/or gaseous and/or solid fossil fuel and used to produce

steam or to heat water and that is not used exclusively to produce

electricity for sale. Boiler or Steam Generator does not include any waste

heat recovery boiler that is used to recover sensible heat from the exhaust

of a combustion turbine or any unfired waste heat recovery boiler that is

used to recover sensible heat from the exhaust of any combustion

equipment.

(4) BTU means British thermal unit.

(5) HEAT INPUT means the chemical heat released due to fuel combustion in

a unit, using the higher heating value of the fuel. This does not include the

sensible heat of incoming combustion air.

(6) NOx EMISSIONS means the sum of nitric oxide and nitrogen dioxide in

the flue gas, collectively expressed as nitrogen dioxide.

(7) PROCESS HEATER means any combustion equipment fired with liquid

and/or gaseous and/or solid fossil fuel and which transfers heat from

combustion gases to water or process streams. Process Heater does not

include any kiln or oven used for drying, curing, baking, cooking, calcining,

or vitrifying; or any unfired waste heat recovery heater that is used to

recover sensible heat from the exhaust of any combustion equipment.

(8) RATED HEAT INPUT CAPACITY means the heat input capacity

specified on the nameplate of the combustion unit. If the combustion unit
Rule 1146 (Cont.) (November 17, 2000)

1146-2

has been altered or modified such that its maximum heat input is different

than the heat input capacity specified on the nameplate, the new maximum

heat input shall be considered as the rated heat input capacity.

(9) STANDBY BOILER is a boiler which operates as a temporary

replacement for primary steam or hot water while the primary steam or hot

water supply unit is out-of-service.

(10) THERM means 100,000 Btu.

(11) UNIT means any boiler, steam generator, or process heater as defined in

paragraph (a)(3) or (a)(7) of this subdivision.

(b) Applicability

This rule applies to boilers, steam generators, and process heaters of equal to or

greater than 5 million Btu per hour rated heat input capacity used in all industrial,

institutional, and commercial operations with the exception of:

(1) boilers used by electric utilities to generate electricity; and

(2) boilers and process heaters with a rated heat input capacity greater than 40

million Btu per hour that are used in petroleum refineries; and

(3) sulfur plant reaction boilers.

(c) Requirements

(1) The owner or operator of any unit(s) with a rated heat input capacity

greater than 40 million Btu per hour and with greater than 25% annual

capacity factor burning gaseous and/or non-gaseous fuels, shall not

discharge into the atmosphere NOx emissions, in excess of 30 ppm or

0.036 pound per 106 Btu of heat input.

(2) The owner or operator shall not discharge into the atmosphere NOx

emissions in excess of 40 ppm or 0.052 pound per 106 Btu of heat input for

any unit(s) with a rated heat input capacity:

(A) greater than or equal to 5 million Btu per hour burning non-gaseous

fuels, excluding units subject to (c)(1); or

(B) greater than or equal to 5 million Btu per hour and less than 40

million Btu per hour burning gaseous or a combination of gaseous

and non-gaseous fuels; or

(C) greater than or equal to 40 million Btu per hour with a rated heat

input less than or equal to 25 percent burning a gaseous or a

combination of gaseous and non gaseous fuels.
Rule 1146 (Cont.) (November 17, 2000)

1146-3

(3) On and after January 1, 2002, the owner or operator of any unit(s) with a

rated heat input capacity greater than or equal to 10 million Btu per hour

shall not discharge into the atmosphere NOx emissions in excess of:

(A) 30 ppm or 0.036 pound per 106 Btu of heat input for units burning

gaseous fuels; and

(B) 30 ppm or 0.036 pound per 106 Btu of heat input, or a weighted

average limit calculated using Equation 1, provided a totalizing fuel

flow meter is installed pursuant to paragraph (c)(10), for units

burning a combination of gaseous and non-gaseous fuels.

 (30 ppmv * x) + (40 ppmv * y)

Weighted Limit = __________________________ (Equation 1)

x + y

Where: x = annual heat input from gaseous fuel

y = annual heat input from non-gaseous fuel

(4) On and after July 1, 2002, the owner or operator of any unit(s) with a rated

heat input capacity greater than or equal to 5 million Btu per hour and less

than 10 million Btu per hour, shall not discharge into the atmosphere NOx

emissions in excess of the emission limits specified in subparagraphs

(c)(3)(A) and (c)(3)(B) as applicable.

(5) The owner or operator of any unit(s) with an input capacity greater than or

equal to 5 million Btu per hour and subject to (c)(1), (c)(2), (c)(3), or

(c)(4) shall not discharge into the atmosphere carbon monoxide (CO)

emissions in excess of 400 ppm.

(6) The owner operator of any unit(s) with a rated heat input capacity greater

than or equal to 5 million Btu per hour and an annual heat input less than

or equal to 9.0 x 109 Btu (90,000 therms) per year, shall:

(A) operate the unit(s) in a manner that maintains stack gas oxygen

concentrations at less than or equal to 3 percent on a dry basis for

any 15-consecutive-minute averaging period; or

(B) tune the unit(s) at least twice per year, (at intervals from 4 to 8

months apart) in accordance with the procedure described in

Attachment 1 or the unit manufacturer's specified tuneup

procedure. If a different tuneup procedure from that described in

Attachment 1 is used then a copy of this procedure shall be kept on
Rule 1146 (Cont.) (November 17, 2000)

1146-4

site. If the unit does not operate throughout a continuous sixmonth period within a calendar year, only one tuneup is required

for that calendar year. The operator of any unit(s) who specifies the

tuneup option shall maintain a record for a period of two years

verifying that the tuneup has been performed. No tune-up is

required during a calendar year for any unit that is not operated

during that calendar year; this unit may be test fired to verify

availability of the unit for its intended use but once the test firing is

completed the unit shall be shutdown. Records of test firings shall

be maintained for a period of two years, and shall be made

accessible to an authorized District representative upon request; or

meet the applicable NOx and CO emission limits in paragraphs

(c)(1), (c)(2), (c)(3), and (c)(4), and (c)(5).

(7) The owner or operator of any unit(s) subject to paragraph (c)(6) shall

submit for the approval of the Executive Officer a compliance plan that

demonstrates compliance with paragraph (c)(6). Such plan shall contain:

(A) A list of permits of all units with the rated heat input capacity and

anticipated annual heat input.

(B) For each unit listed, a selection of one of the three options specified

in paragraph (c)(6) to achieve compliance with this rule.

(C) Nonresettable fuel totalizing meter specifications for each fuel used,

date of meter installation, records of fuel use for each unit during

the last two years starting from March 1, 1991.

The plan shall be disapproved if for any continuous 12-month period, the

annual fuel usage exceeds 90,000 therms. In this case the unit shall have to

comply with the applicable emission limits specified in paragraphs (c)(1),

(c)(2), (c)(3), or (c)(4).

(8) Any unit(s) with a rated heat input capacity greater than or equal to 40

million Btu per hour and an annual heat input greater than 200 x 109 Btu

per year shall have a continuous in-stack nitrogen oxides monitor or

equivalent verification system in compliance with 40 CFR part 60

Appendix B Specification 2. Maintenance and emission records shall be

maintained and made accessible for a period of two years as to the

Executive Officer.
Rule 1146 (Cont.) (November 17, 2000)

1146-5

(9) For owners or operators that are subject to the requirements specified in

paragraph (c)(6), the provisions of paragraphs (c)(1), (c)(2), (c)(3), (c)(4),

(c)(5), or (c)(8), as applicable, shall become effective for the life of the unit

on March 1 of any calendar year if that unit operated for the previous

calendar year at an annual heat input greater than:

(A) 90,000 therms for units greater than or equal to 5 million Btu per

hour; or

(B) 200 x 109 Btu per year for units greater than or equal to 40 million

Btu per hour.

(10) Any owner or operator who chooses the pound per million Btu compliance

option specified in paragraph(s) (c)(1), (c)(2), (c)(3), or (c)(4) or chooses

the weighted average emission limit using Equation 1 under subparagraph

(c)(3)(B) shall install a non-resettable totalizing fuel meter to measure the

total of each fuel used by each individual unit, as approved by the

Executive Officer.

 (11) Any owner or operator of a unit not covered under the provisions of

paragraphs (c)(1), (c)(2), (c)(3), (c)(4), or (c)(8) based on annual heat

input, shall:

(A) have installed by February 1, 1989 for units with a rated heat input

capacity equal to or greater than 5 but less than 40 million Btu per

hour, or by May 1, 1989 for units with a rated heat input capacity

equal to or greater than 40 million Btu per hour, or at the time the

unit is constructed, a totalizing meter for each fuel that

demonstrates that the unit(s) operated at or below the applicable

heat input levels; and

(B) have available for inspection by the Executive Officer by March 1

of each year, records listing cumulative annual usage of each fuel

for the preceding calendar year. Records shall be maintained and

made accessible to the Executive Officer for a period of two years;

and

(C) demonstrate that the annual heat input is less than or equal to the

applicable amount listed in the applicable paragraphs (c)(1), (c)(2),

(c)(3), (c)(4), and/or (c)(8).

(12) Except as provided in subdivision (e), if any unit subject to a compliance

plan submitted pursuant to paragraph (c)(7) exceeds 90,000 therms of
Rule 1146 (Cont.) (November 17, 2000)

1146-6

annual heat input from all fuels used in any calendar year after 1991, the

operators shall:

(A) Within 4 months after the end of the calendar year during which the

unit exceeded 90,000 therms of annual heat input, submit required

applications for permits to construct and operate; and

(B) Within 18 months after the end of the calendar year during which

the unit exceeded 90,000 therms of annual heat input, demonstrate

and maintain compliance with paragraphs (c)(1), (c)(2), (c)(3),

(c)(4), and if applicable, (c)(8) for the life of the unit; and

(C) Maintain compliance with requirements of paragraph (c)(7) until

compliance with paragraphs (c)(1), (c)(2), (c)(3) and (c)(4) and, if

applicable, (c)(8) is achieved.

(d) Compliance Determination

(1) An owner or operator of any unit(s) shall have the option of complying

with either the pound per million Btu or parts per million emission limits

specified in paragraphs (c)(1), (c)(2) (c)(3), and (c)(4).

(2) All emission determinations shall be made in the as-found operating

condition, except no compliance determination shall be established during

start-up, shutdown, or under breakdown conditions.

(3) All parts per million emission limits specified in paragraph (c) are

referenced at 3 percent volume stack gas oxygen on a dry basis averaged

over a period of 15 consecutive minutes.

(4) Compliance with the NOx and CO emission requirements of paragraphs

(c)(1), (c)(2), (c)(3), (c)(4), and (c)(5) and the stack-gas oxygen

concentration requirement of paragraph (c)(6)(A) shall be determined

according to procedures in District Source Test Method 100.1 -

Instrumental Analyzer Procedures for Continuous Gaseous Emission

Sampling (March 1989), or Method 7.1 - Determination of Nitrogen Oxide

Emissions from Stationary Sources (March 1989) and Method 10.1 -

Carbon Monoxide and Carbon Dioxide by Gas Chromatograph/NonDispersive Infrared Detector (GC/NDIR) - Oxygen by Gas

Chromatograph-Thermal Conductivity (GC/TCD) (March 1989), or any

other test method, such as methods that allow the use of hand-held

portable monitors, determined to be equivalent and approved before the

test in writing by the Executive Officers of the District and the California
Rule 1146 (Cont.) (November 17, 2000)

1146-7

Air Resources Board and the Regional Administrator of the United States

Environmental Protection Agency, Region IX. Records of all source tests

shall be maintained for a period of two years and shall be made available to

District personnel upon request. Emissions determined to exceed any limits

established by this rule through the use of any of the above-referenced test

methods shall constitute a violation of this rule.

(5) For any operator who chooses the pound per million Btu of heat input

compliance option of paragraph (c)(1), (c)(2), (c)(3), or (c)(4), NOx

emissions in pounds per million Btu of heat input shall be calculated using

procedures in 40 CFR Part 60, Appendix A, Method 19, Sections 2 and 3.

(6) Compliance determination with the NOx and CO emission requirements in

paragraph (d)(4) shall be conducted on or before January 1, 2002 and

every year thereafter for units with a rated heat input capacity equal to or

greater than 10 million Btu per hour and on or before July 1, 2002 and

every year thereafter for units with a rated heat input capacity less than 10

million Btu per hour. Notwithstanding the requirements of paragraph

(d)(2), for the purposes of demonstrating compliance with the annual

compliance determination, an owner or operator may tune a unit prior to

conducting emissions testing. Any screening analysis while tuning the unit

shall not be considered an emissions test for the annual compliance

determination.

(7) Provided the emissions test is conducted within the same calendar year as

the test required in (d)(6), an owner or operator may use the following

emissions tests to comply with paragraph (d)(6):

(A) Periodic monitoring or testing of a unit as required in a Title V

permit pursuant to Regulation XXX, or

(B) Relative accuracy testing for continuous emissions monitoring

verification pursuant to Rule 218.1.

(e) Exemption

A one-time exemption from the requirements of paragraphs (c)(1), (c)(2), (c)(3),

(c)(4), (c)(8) and (c)(12) is allowed for any owner or operator of a standby boiler

whose fuel usage from all fuels exceeded 90,000 therms but was not greater than

110,000 therms of annual heat input during the calendar year 1996. As a condition

of this exemption, an owner or operator shall submit an application for a permit

modification by July 31, 2000 and accept additional permit conditions that provide

for a daily emission increase, above what is allowed under paragraph (c)(1), (c)(2),
Rule 1146 (Cont.) (November 17, 2000)

1146-8

(c)(3), and (c)(4) of less than 55 pounds per day of NOx for all standby boilers

subject to this subdivision, an annual heat input of less than 90,000 therms for each

standby boiler, and a daily recordkeeping condition.
Rule 1146 (Cont.) (November 17, 2000)

1146-9

ATTACHMENT 1

A. Equipment Tuning Procedure1 for Forced-Draft Boilers, Steam Generators,

and Process Heaters

Nothing in this Equipment Tuning Procedure shall be construed to require any act or

omission that would result in unsafe conditions or would be in violation of any regulation

or requirement established by Factory Mutual, Industrial Risk Insurors, National Fire

Prevention Association, the California Department of Industrial Relations (Occupational

Safety and Health Division), the Federal Occupational Safety and Health Administration,

or other relevant regulations and requirements.

Should a different tuning procedure be used, a copy of this procedure should be kept with

the unit records for two years and made available to the District personnel on request.

1. Operate the unit at the firing rate most typical of normal operation. If the unit

experiences significant load variations during normal operation, operate it at its

average firing rate.

2. At this firing rate, record stack gas temperature, oxygen concentration, and CO

concentration (for gaseous fuels) or smoke-spot number2 (for liquid fuels), and

observe flame conditions after unit operation stabilizes at the firing rate selected.

If the excess oxygen in the stack gas is at the lower end of the range of typical

minimum values3, and if CO emissions are low and there is not smoke, the unit is

probably operating at near optimum efficiency - at this particular firing rate.

However, complete the remaining portion of this procedure to determine whether

still lower oxygen levels are practical.

3. Increase combustion air flow to the furnace until stack gas oxygen levels increase

by one to two percent over the level measured in Step 2. As in Step 2, record the

 

1 This tuning procedure is based on a tune-up procedure developed by KVB, Inc. for the

United States EPA.

2 The smoke-spot number can be determined with ASTM Test Method D-2156 or with the

Bacharach method. ASTM Test Method D-2156 is included in a tuneup kit that can be

purchased from the Bacharach Company.

3 Typical minimum oxygen levels for boilers at high firing rates are:

1. For natural gas: 0.5% - 3%

2. For liquid fuels: 2% - 4%
Rule 1146, Attachment 1 (Cont.) (November 17, 2000)

1146-10

stack gas temperature, CO concentration (for gaseous fuels) or smoke-spot

number (for liquid fuels), and observe flame conditions for these higher oxygen

levels after boiler operation stabilizes.

4. Decrease combustion air flow until the stack gas oxygen concentration is at the

level measured in Step 2. From this level gradually reduce the combustion air

flow, in small increments. After each increment, record the stack gas temperature,

oxygen concentration, CO concentration (for gaseous fuels) and smoke-spot

number (for liquid fuels). Also observe the flame and record any changes in its

condition.

5. Continue to reduce combustion air flow stepwise, until one of these limits is

reached:

a. Unacceptable flame conditions - such as flame impingement on furnace

walls or burner parts, excessive flame carryover, or flame instability.

b. Stack gas CO concentrations greater than 400 ppm.

c. Smoking at the stack.

d. Equipment-related limitations - such as low windbox/furnace pressure

differential, built in air-flow limits, etc.

6. Develop an O2/CO curve (for gaseous fuels) or O2/smoke curve (for liquid fuels)

similar to those shown in Figures 1 and 2 using the excess oxygen and CO or

smoke-spot number data obtained at each combustion air flow setting.

7. From the curves prepared in Step 6, find the stack gas oxygen levels where the CO

emissions or smoke-spot number equal the following values:

Fuel Measurement Value

Gaseous CO Emissions 400 ppm

#1 and #2 oils smoke-spot number number 1

#4 oil smoke-spot number number 2

#5 oil smoke-spot number number 3

Other oils smoke-spot number number 4

The above conditions are referred to as the CO or smoke thresholds, or as the

minimum excess oxygen level.

Compare this minimum value of excess oxygen to the expected value provided by

the combustion unit manufacturer. If the minimum level found is substantially

higher than the value provided by the combustion unit manufacturer, burner

adjustments can probably be made to improve fuel and air mixing, thereby allowing

operation with less air.
Rule 1146, Attachment 1 (Cont.) (November 17, 2000)

1146-11

8. Add 0.5 to 2.0 percent of the minimum excess oxygen level found in Step 7 and

reset burner controls to operate automatically at this higher stack gas oxygen level.

This margin above the minimum oxygen level accounts for fuel variations,

variations in atmospheric conditions, load changes, and nonrepeatability or play in

automatic controls.

9. If the load of the combustion unit varies significantly during normal operation,

repeat Steps 1-8 for firing rates that represent the upper and lower limits of the

range of the load. Because control adjustments at one firing rate may affect

conditions at other firing rates, it may not be possible to establish the optimum

excess oxygen level at all firing rates. If this is the case, choose the burner control

settings that give best performance over the range of firing rates. If one firing rate

predominates, settings should optimize conditions at that rate.

10. Verify that the new settings can accommodate the sudden load changes that may

occur in daily operation without adverse effects. Do this by increasing and

decreasing load rapidly while observing the flame and stack. If any of the

conditions in Step 5 result, reset the combustion controls to provide a slightly

higher level of excess oxygen at the affected firing rates. Next, verify these new

settings in a similar fashion. Then make sure that the final control settings are

recorded at steady-state operating conditions for future reference.

11. When the above checks and adjustments have been made, record data and attach

combustion analysis data to boiler, steam generator, or heater records indicating

name and signature of person, title, and date the tuneup was performed.

B. Equipment Tuning Procedure for Natural Draft-Fired Boilers, Steam

Generators, and Process Heaters.

Nothing in this Equipment Tuning Procedure shall be construed to require any act or

omission that would result in unsafe conditions or would be in violation of any regulation

or requirement established by Factory Mutual, Industrial Risk Insurers, National Fire

Prevention Association, the California Department of Industrial Relations (Occupational

Safety and Health Division), the Federal Occupational Safety and Health Administration,

or other relevant codes, regulations, and equipment manufacturers specifications and

operating manuals.

Should a different tuning procedure be used, a copy of this procedure should be kept with

the unit records for two years and made available to the District personnel on request.
Rule 1146, Attachment 1 (Cont.) (November 17, 2000)

1146-12

1. PRELIMINARY ANALYSIS

a. CHECK THE OPERATING PRESSURE OR TEMPERATURE.

Operate the boiler, steam generator, or heater at the lowest acceptable

pressure or temperature that will satisfy the load demand. This will

minimize heat and radiation losses. Determine the pressure or temperature

that will be used as a basis for comparative combustion analysis before and

after tuneup.

b. CHECK OPERATING HOURS.

Plan the workload so that the boiler, steam generator, or process heater

operates only the minimum hours and days necessary to perform the work

required. Fewer operating hours will reduce fuel use and emissions. For

units requiring a tuneup to comply with the rule, a totalizing non-resettable

fuel meter will be required for each fuel used and for each boiler, steam

generator, and heater to prove fuel consumption is less than the heat input

limit in therms per year specified in the rule.

c. CHECK AIR SUPPLY.

Sufficient fresh air supply is essential to ensure optimum combustion and

the area of air supply openings must be in compliance with applicable codes

and regulations. Air openings must be kept wide open when the burner is

firing and clear from restriction to flow.

d. CHECK VENT.

Proper venting is essential to assure efficient combustion. Insufficient draft

or overdraft promotes hazards and inefficient burning. Check to be sure

that vent is in good condition, sized properly and with no obstructions.

e. COMBUSTION ANALYSIS.

Perform an "as is" combustion analysis (CO, O2, etc.) with a warmed up

unit at high and low fire, if possible. In addition to data obtained from

combustion analysis, also record the following:

i. Inlet fuel pressure at burner (at high & low fire)

ii. Draft above draft hood or barometric damper

1) Draft hood: high, medium, and low

2) Barometric Damper: high, medium, and low

iii. Steam pressure, water temperature, or process fluid pressure or

temperature entering and leaving the boiler, steam generator, or

process heater.

iv. Unit rate if meter is available.
Rule 1146, Attachment 1 (Cont.) (November 17, 2000)

1146-13

With above conditions recorded, make the following checks and corrective actions

as necessary:

2. CHECKS & CORRECTIONS

a. CHECK BURNER CONDITION.

Dirty burners or burner orifices will cause boiler, steam generator, or

process heater output rate and thermal efficiency to decrease. Clean

burners and burner orifices thoroughly. Also, ensure that fuel filters and

moisture traps are in place, clean, and operating properly, to prevent

plugging of gas orifices. Confirm proper location and orientation of burner

diffuser spuds, gas canes, etc. Look for any burned-off or missing burner

parts, and replace as needed.

b. CHECK FOR CLEAN BOILER, STEAM GENERATOR, OR PROCESS

HEATER TUBES & HEAT TRANSFER SURFACES.

External and internal build-up of sediment and scale on the heating surfaces

creates an insulating effect that quickly reduces unit efficiency. Excessive

fuel cost will result if the unit is not kept clean. Clean tube surfaces,

remove scale and soot, assure proper process fluid flow and flue gas flow.

c. CHECK WATER TREATMENT & BLOWDOWN PROGRAM.

Soft water and the proper water or process fluid treatment must be

uniformly used to minimize scale and corrosion. Timely flushing and

periodic blowdown must be employed to eliminate sediment and scale

build-up on a boiler, steam generator or process heater.

d. CHECK FOR STEAM, HOT WATER OR PROCESS FLUID LEAKS.

Repair all leaks immediately since even small high-pressure leaks quickly

lead to considerable fuel, water and steam losses. Be sure there are no

leaks through the blow-off, drains, safety valve, by-pass lines or at the feed

pump, if used.
Rule 1146, Attachment 1 (Cont.) (November 17, 2000)

1146-14

3. SAFETY CHECKS

a. Test primary and secondary low water level controls.

b. Check operating and limit pressure and temperature controls.

c. Check pilot safety shut off operation.

d. Check safety valve pressure and capacity to meet boiler, steam generator or

process heater requirements.

e. Check limit safety control and spill switch.

4. ADJUSTMENTS

While taking combustion readings with a warmed up boiler, steam generator, or

process heater at high fire perform checks and adjustments as follows:

a. Adjust unit to fire at rate; record fuel manifold pressure.

b. Adjust draft and/or fuel pressure to obtain acceptable, clean combustion at

both high, medium and low fire. Carbon Monoxide (CO) value should

always be below 400 parts per million (PPM) at 3% 02. If CO is high

make necessary adjustments.

Check to ensure boiler, steam generator, or process heater light offs are

smooth and safe. A reduced fuel pressure test at both high and low fire

should be conducted in accordance with the manufacturers instructions and

maintenance manuals.

c. Check and adjust operation of modulation controller. Ensure proper,

efficient and clean combustion through range of firing rates.

When above adjustments and corrections have been made, record all data.

5. FINAL TEST

Perform a final combustion analysis with a warmed up boiler, steam generator, or

process heater at high, medium and low fire, whenever possible. In addition to

data from combustion analysis, also check and record:

a. Fuel pressure at burner (High, Medium, and Low).

b. Draft above draft hood or barometric damper (High, Medium and Low).

c. Steam pressure or water temperature entering and leaving boiler, steam

generator, or process heater.

d. Unit rate if meter is available.

When the above checks and adjustments have been made, record data and attach

combustion analysis data to boiler, steam generator, or process heater records
Rule 1146, Attachment 1 (Cont.) (November 17, 2000)

1146-15

indicating name and signature of person, title, company name, company address

and date the tuneup was performed.