1146.1-1 (Adopted October 5, 1990)(Amended July 10, 1992)(Am ended May 13, 1994) (Amended September 5, 2008)

RULE 1146.1 EMISSIONS OF OXIDES OF NITROGEN FROM SM ALL

INDUSTRIAL, INSTITUTIONAL, AND COMMERCIAL BOILERS, STEAM GENERATORS, AND PROCESS HEATERS

(a) Applicability This rule applies to boilers, steam generators, an d process heaters that are greater than 2 million Btu per hour and less than 5 million Btu per hour rated heat input capacity used in any industrial, institutional, or commercial operation.

(b) Definitions (1) ANNUAL HEAT INPUT means the actual amount of h eat released by fuels burned in a unit during a calendar year, base d on the fuel's higher heating value. (2) ATMOSPHERIC UNIT means any natural gas fired unit with a non-sealed

combustion chamber in which natural draft is used t o exhaust combustion

gases. (3) BOILER OR STEAM GENERATOR means any combustio n equipment

fired with liquid and/or gaseous (including landfil l and digester gas) and/or solid fossil fuel, 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 tha t is used to recover
sensible heat from the exhaust of a combustion turb ine 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 or units. (5) HEALTH FACILITY has the same meaning as define d in Section 1250 of the California Health and Safety Code. (6) NOx EMISSIONS means the sum of nitric oxide and nitrogen dioxide in the flue gas, collectively expressed as nitrogen di oxide. (7) PROCESS HEATER means any combustion equipment fired with liquid

and/or gaseous (including landfill and digester gas ) and/or solid fossil fuel and which transfers heat from combustion gases to w ater or process streams. Process Heater does not include any kiln or oven used for drying,Rule 1146.1 (Cont.) (Amended September 5, 2008)

1146.1-2 curing, baking, cooking, calcining, or vitrifying; or any unfired waste heat recovery heater that is used to recover sensible he at from the exhaust of any combustion equipment. (8) RATED HEAT INPUT CAPACITY means the heat inpu t capacity

specified on the nameplate of the combustion unit. If the combustion unit
has been altered or modified such that its maximum heat input is different than the heat input capacity specified on the namep late, the new maximum heat input shall be considered as the rated heat in put capacity. (9) SCHOOL means any public or private school, inc luding juvenile detention facilities with classrooms, used for purposes of th e education of more than 12 children at the school, including in kindergarte n and grades 1 to 12, inclusive, but does not include any private school in which education is primarily conducted in private homes. The term inc ludes any building or structure, playground, athletic field, or other are a of school property, but does not include unimproved school property. (10) THERM means 100,000 Btu. (11) THERMAL FLUID HEATER means a PROCESS HEATER in which a process is heated indirectly by a heated fluid othe r than water. (12) UNIT means any boiler, steam generator, or pr ocess heater as defined in

paragraph (b)(3) or (b)(7).

(c) Requirements (1) On or after September 5, 2008, the owner or ope rator of any unit subject to subdivision (a) shall operate such unit so that it discharges into the atmosphere no more than 30 ppm of NOx emissions or for natural gas fired units 0.037 pound NOx per million Btu of heat input, as specified in the permit to operate. (2) An owner or operator of any unit subject to sub division (a) must select to comply with one of the following NOx emission limit s specified in Table 1146.1-1 and apply for a permit to construct to ope rate such unit in compliance with the selected emission limit and the corresponding permit application and full compliance dates.Rule 1146.1 (Cont.) (Amended September 5, 2008)

1146.1-3 Table 1146.1-1

(3) For dual fuel co-fired combustion units a weigh ted average limit calculated by Equation 1146.1-1 may be used provide d a totalizing fuel flow meter is installed pursuant to paragraph (c)(7 ), for units burning a
combination of both fuels.

Weighted Limit

= ______________________ Equation 1146.1-1
Q A + Q B

Where:
CL A

= compliance limit for fuel A
CL B = compliance limit for fuel B Q A = heat input from fuel A Q B = heat input from fuel B Category Limit Submit Application for Permit to Construct on or before Unit Shall be in

Full Compliance on or before

Any Units Fired on Landfill Gas 25 ppm January 1, 2014 January 1, 2015

Any Units Fired on Digester Gas 15 ppm January 1, 2014 January 1, 2015

Atmospheric Units 12 ppm or 0.015 lbs/10 6 Btu January 1, 2013 January 1, 2014

Any Units Fired on Natural Gas, Excluding Units Located at Schools and Universities, Atmospheric Units, and Thermal Fluid Heaters 9 ppm or January 1, 2011 January 1, 2012

Any Units Fired on Natural Gas Located at Schools and Universities, Excluding Atmospheric Units, and Thermal Fluid Heaters 0.011 lbs/10 6 Btu January 1, 2013 January 1, 2014

(CL A x Q A ) + (CL B x Q B )Rule 1146.1 (Cont.) (Amended September 5, 2008)

1146.1-4 (4) The owner or operator of any unit(s) with a hea t input capacity greater than or equal to 2 million Btu per hour shall not discha rge into the atmosphere carbon monoxide (CO) emissions in excess of 400 ppm or for natural gas
fired units 0.30 lbs/10 6 Btu. (5) In lieu of complying with the applicable emissi on limits specified in paragraph (c)(1) or (c)(2) any unit(s) subject to s ubdivision (a) in operation prior to September 5, 2008, and with an annual heat input of less than or equal to 18,000 therms per calendar year, shall: (A) be operated in a manner that maintains stack-g as oxygen

concentrations at less than or equal to 3 percent o n a dry basis for any 15-consecutive-minute averaging period; or (B) be tuned at least twice per year, (at interval s from four to eight

months apart) in accordance with the procedure desc ribed in Attachment 1 or the unit manufacturer's specified t uneup procedure. If a different tuneup procedure from th at described in attachment 1 is used then a copy of this procedure shall be kept on site. The operator of any unit(s) selecting the tu ne-up option shall maintain records for a rolling of twenty four month period verifying that the required tune-ups have been perf ormed. If the unit does not operate throughout a continuous six-m onth period within 12 month period, only one tuneup is required for the twelve month period that includes the entire period of non -operation. For this case, the tune-up shall be conducted within 30 days of start-up. No tune-up is required during a rolling twelve mont h period for any unit that is not operated during that rolling t welve month period; this unit may be test fired to verify avail ability of the unit for its intended use but once test firing is comple ted it shall be shutdown. Records of test firings shall be maintai ned for a rolling twenty four month period, and shall be made accessi ble upon request from an authorized District representative upon request. (6) An owner or operator that has installed or modi fied a natural gas fired unit prior to September 5, 2008 complying with the appli cable BACT emission limit of 12 ppm or less of NOx may defer compliance with paragraph (c)(2) until the unit’s burner(s) replacement. (7) Any owner or operator who chooses the pound per million Btu of heat input compliance option in paragraph (c)(1), (c)(2) , or (c)(4) for naturalRule 1146.1 (Cont.) (Amended September 5, 2008)

1146.1-5 gas fired units or chooses the weighted average emi ssion limit using Equation 1146.1-1 under paragraph (c)(3) shall inst all a non-resettable, totalizing fuel meter for each fuel used on an indi vidual unit basis, as approved by the Executive Officer. (8) On or after January 1, 2015, an owner operator of any landfill or digester gas (biogas) unit co-fired with natural gas shall n ot operate the unit in a manner that exceeds the applicable landfill or dige ster gas emission concentration limits specified in paragraph (c)(2), provided that the facility monthly average biogas usage by the biogas units is 90% or more, based on the higher heating value of the fuels used. (A) The Executive Officer may approve the burning o f more than

10% up to: (i) 25% natural gas in a biogas fired unit at the 1 5 ppm (digester gas) or 25 ppm (landfill gas) NOx level, when it is necessary, if the only alternative to limiting n atural gas to 10% would be shutting down the unit and flaring more biogas. (ii) 50% natural gas in a digester gas-fired unit a t the 15 ppm NOx level, when it is necessary as specified in cla use (c) (8)(A)(i) and for units installed on or after Septe mber 5, 2008 provided the unit has demonstrated compliance with the NOx limits in paragraph (c)(2) applicable to un its fired exclusively on natural gas. For units subject to this subparagraph, the percent natural gas usage shall be based on the facility monthly averag e biogas usage by the biogas units and the higher heating va lue of the
fuels used. (B) Any biogas-fired unit burning more than the app roved percent

natural gas as determined under subparagraph (c)(8) (A) shall comply with the weighted average NOx limit specifie d in paragraph (c)(3).

(d) Compliance Determination (1) Owners or operators of any units shall have the option of complying with either the pound per million Btu of heat input or p arts per million emission limits specified in paragraph (c)(1), (c)(2), (c)(3 ), or (c)(4).Rule 1146.1 (Cont.) (Amended September 5, 2008)

1146.1-6 (2) All emission determinations shall be made in th e as-found operating condition, except no compliance determination shall be established during unit start up, shutdown, or under breakdown conditi ons. Start up or shutdown intervals shall not last longer than is ne cessary to reach stable temperatures. In no case shall the start up or shu tdown interval last longer than six hours or the time specified in the permit to operate, whichever is less. Start-ups and shutdowns shall not last longe r than is necessary to
reach stable conditions. An compliance determination as specified in paragraph (d)(6) shall be conducted at least 250 op erating hours, or at least thirty days subsequent to the tuning or servicing o f any unit, unless it is an unscheduled repair. (3) All parts per million emission limits specified in subdivision (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 require ments of paragraphs (c)(1) through (c)(4) and the stack-gas oxygen conc entration requirement of subparagraph (c)(5)(A) shall be determined using a District approved contractor under the Laboratory Approval Program ac cording to the following procedures: (A) District Source Test Method 100.1 - Instrumenta l Analyzer Procedures for Continuous Gaseous Emission Sampling (March 1989), or (B) District Source Test 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/Non-Dispersive Infrared Detector (GC/ NDIR) - Oxygen by Gas Chromatograph-Thermal Conductivity (G C/TCD) (March 1989), or (C) United States Environmental Protection Agency C onditional Test Method CTM-030, Determination of Nitrogen Oxides, C arbon Monoxide, and Oxygen Emissions from Natural Gas-Fir ed Engines, Boilers and Process Heaters Using Portable Analyzer s; or (D) ASTM D6522-00(2005) Standard Test Method for De termination of Nitrogen Oxides, Carbon Monoxide, and Oxygen Con centrations in Emissions from Natural Gas-Fired Reciprocating E ngines,Rule 1146.1 (Cont.) (Amended September 5, 2008)

1146.1-7 Combustion Turbines, Boilers, and Process Heaters U sing Portable Analyzers (E) any other test method determined to be alternat ive and approved before the test in writing by the Executive Officer s of the District and the California Air Resources Board and the Regi onal
Administrator of the United States Environmental Pr otection Agency, Region IX.
Records of all source tests shall be maintained for a period of two years (five years for Title V facilities) and shall be ma de available to District personnel upon request. Emissions determined to ex ceed 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 owner or operator who chooses the pound s of per million Btu of heat input compliance option of paragraph (c)(1), ( c)(2), or (c)(4) for natural gas fired units, NOx emissions in pounds pe r million Btu of heat input shall be calculated using the procedures in 4 0 CFR Part 60, Appendix A, Method 19, Sections 2 and 3 and CO emis sions in pounds per million Btu of heat input shall be calculated a ccording to the Protocol for the Periodic Monitoring of Nitrogen Oxides, Car bon Monoxide, and Oxygen from Units Subject to South Coast Air Qualit y Management
District Rules 1146 and 1146.1. (6) Compliance determination with the NOx emission requirements specified in paragraph (d)(4) shall be conducted once every f ive years. (7) Any owner or operator of units subject to this rule shall check NOx emissions with a portable NOx, CO and oxygen analyz er according to the Protocol for the Periodic Monitoring of Nitrogen Ox ides, Carbon Monoxide, and Oxygen from Units Subject to South Co ast Air Quality Management District Rules 1146 and 1146.1 according to the following
schedule: (A) On or after July 1, 2009, the owner or operator of units subject to paragraphs (c)(1) through (c)(4) shall check NOx em issions at least quarterly or every 2,000 unit operating hours, whic hever occurs later. If a unit is in compliance for four consecu tive required emission checks, without any adjustments to the oxy gen sensor set points, then the unit may be checked semi-annually or every 4,000Rule 1146.1 (Cont.) (Amended September 5, 2008)

1146.1-8 unit operating hours, whichever occurs later, until there is an emission check indicating noncompliance. (B) On or after January 1, 2015 or during burner replac ement, whichever occurs later, units subject to paragraph (c)(5) shall check NOx emissions according to the tune-up schedu le specified in subparagraph (c)(5)(B). (C) Records of all monitoring data required under subpa ragraphs (d)(7)(A) and (d)(7)(B) shall be maintained for a r olling twelve month period of two years (five years for Title V f acilities) and shall be made available to District personnel upon request. An owner or operator shall not be considered in violat ion of the emissions limits of this rule or in permit conditio ns if the owner or operator complies with requirements specified in pa ragraph (d)(9). Any emission check conducted by District staff that finds excess
emissions is a violation. (D) The portable analyzer tests required under subp aragraphs (d)(7)(A) and (d)(7)(B) shall only be conducted by a person w ho has completed an appropriate District-approved training program in the operation of portable analyzers and has received a certification issued by the District. (8) An owner or operator shall opt to comply with t he requirements as applied to CO emissions specified in paragraph (d)(6) or (d )(7). (9) A source test specified under paragraph (d)(6) or an emission check conducted under the requirements specified in parag raph (d)(7) that finds emissions in excess of those allowed by this rule o r a permit condition
shall not constitute a violation of this rule if th e owner or operator corrects the problem and demonstrate compliance with another source test or
emission check within 72 hours from the time the ow ner or operator knew of excess emissions, or reasonably should have know n, or shut down the unit by the end of an operating cycle, whichever is sooner. (10) An owner or operator may opt to lower the unit ’s rated heat input capacity. The lowered rated heat input capacity shall not be less than 2 million Btu per hour and shall be based on manufacturer’s ident ification or rating plate or permit condition.Rule 1146.1 (Cont.) (Amended September 5, 2008)

1146.1-9 (e) Compliance Schedule (1) Owners or operators of units shall comply with the applicable schedule specified in paragraphs (c)(1) and (c)(2). (2) On or after January 1, 2015 or during burner re placement, whichever is later, no person shall operate in the District any unit subject to paragraph (c)(5) which does not meet the emissions limits spe cified in paragraph (c)(1). (3) If any unit subject to paragraph (c)(5) exceeds 18,000 therms of annual heat input from all fuels used in any twelve month period, the owners or operators shall: (A) within 4 months after exceeding 18,000 therms o f heat input in any twelve month period, submit required applications f or permits to construct and operate; and (B) within 18 months after exceeding 18,000 therms of heat input in any twelve month period, demonstrate and maintain c ompliance with all applicable requirements specified in parag raphs (c)(1) through (c)(4) for the life of the unit. (4) The Executive Officer shall grant a time extens ion to the full compliance date with the applicable NOx compliance limits for any natural gas fired units specified in paragraph (c)(2) for any health facility as defined in Section 1250 of the California Health and Safety Co de that can
demonstrate that the Office of Statewide Health Pla nning and Development has approved an extension of time to co mply with seismic safety requirements pursuant to Health and Safety C ode Sections 130060 and 130061.5. The extension of time granted by the Executive Officer shall be consistent with the time extension granted pursuant to Health and Safety Code Section 130060 but not to exceed Januar y 1, 2015 and shall be consistent with the time extension granted pursu ant to Health and Safety Code Section 130061.5 but not to exceed Janu ary 1, 2020. Those health facilities granted a time extension shall su bmit a compliance plan to the Executive Officer on or before January 1, 2010.Rule 1146.1 (Cont.) (Amended September 5, 2008)

1146.1-10 ATTACHMENT 1

A. Equipment Tuning Procedure 1 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, Industri al Risk Insurers, National Fire Prevention Association, the California Department of Industria l Relations (Occupational Safety and Health Division), the Federal Occupational Safety a nd Health Administration, or other relevant regulations and requirements. 1. Operate the unit at the firing rate most typical of normal operation. If the unit experiences significant load variations during norm al operation, operate it at its average firing rate. 2. At this firing rate, record stack gas temperatur e, oxygen concentration, and CO concentration (for gaseous fuels) or smoke-spot num ber 2 (for liquid fuels), and observe flame conditions after unit operation stabi lizes at the firing rate selected. If the excess oxygen in the stack gas is at the lower end of the range of typical minimum
values 3 , and if CO emissions are low and there is not smok e, the unit is probably operating at near optimum efficiency - at this part icular firing rate.
3. Increase combustion air flow to the furnace unti l stack gas oxygen levels increase by one to two percent over the level measured in Step 2. As in Step 2, record the stack gas temperature, CO concentration (for gaseous fuel s) or smoke-spot number (for liquid fuels), and observe flame conditions for the se higher oxygen levels after boiler operation stabilizes. However, complete the remaining portion of this pro cedure to determine whether still lower oxygen levels are practical.

1 This tuning procedure is based on a tune-up procedu re developed by KVB, Inc. for the United States EPA. 2 The smoke-spot number can be determined with ASTM T est Method D-2156 or with the Bacharach method. ASTM Test Method D-2156 is inclu ded in a tuneup kit that can be purchased from the Bacharach Company. 3 Typical minimum oxygen levels for boilers at high f iring rates are: 1. For natural gas: 0.5% - 3% 2. For liquid fuels: 2% - 4%Rule 1146.1 (Cont.) (Amended September 5, 2008)

1146.1-11 4. Decrease combustion air flow until the stack gas oxygen concentration is at the level measured in Step 2. From this level gradually redu ce 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 a ny 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 im pingement on furnace walls or burner parts, excessive flame carryover, or flam e instability. b. Stack gas CO concentrations greater than 400 ppm

. c. Smoking at the stack. d. Equipment-related limitations - such as low wind box/furnace pressure differential, built in air-flow limits, etc. 6. Develop an O 2 /CO curve (for gaseous fuels) or O 2 /smoke curve (for liquid fuels) similar to those shown in Figures 1 and 2 using the excess oxygen and CO or smokespot number data obtained at each combustion air fl ow setting.Rule 1146.1 (Cont.) (Amended September 5, 2008)

1146.1-12 7. From the curves prepared in Step 6, find the sta ck 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 manu facturer, burner adjustments can probably be made to improve fuel and air mixing, th ereby allowing operation with
less air. 8. Add 0.5 to 2.0 percent O2 to the minimum excess oxygen level found in Step 7 and reset burner controls to operate automatically at t his higher stack gas oxygen level. This margin above the minimum oxygen level accounts for fuel variations, variationsRule 1146.1 (Cont.) (Amended September 5, 2008)

1146.1-13 in atmospheric conditions, load changes, and nonrep eatability or play in automatic
controls. 9. If the load of the combustion unit varies signif icantly 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 ra te may affect conditions at other firing rates, it may not be possible to establish t he optimum excess oxygen level at all firing rates. If this is the case, choose the burn er 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 th e 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 set tings 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-Fir ed 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, Industri al Risk Insurers, National Fire Prevention Association, the California Department of Industria l Relations (Occupational Safety and Health Division), the Federal Occupational Safety a nd Health Administration, or other relevant codes, regulations, and equipment manufact urers 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 th e District personnel on request.Rule 1146.1 (Cont.) (Amended September 5, 2008)

1146.1-14 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 temper ature that will be used as a basis for comparative combustion analysis before an d after tuneup.
b. CHECK OPERATING HOURS. Plan the workload so that the boiler, steam genera tor, or process heater

operates only the minimum hours and days necessary to perform the work required. Fewer operating hours will reduce fuel u se and emissions. For units requiring a tuneup to comply with the rule, a total izing non-resettable fuel meter will be required for each fuel used and for e ach boiler, steam generator, and heater to prove fuel consumption is less than t he 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 w ith applicable codes and regulations. Air openings must be kept wide open w hen the burner is firing
and clear from restriction to flow.
d. CHECK VENT. Proper venting is essential to assure efficient co mbustion. Insufficient draft or

overdraft promotes hazards and inefficient burning. Check to be sure that vent is in good condition, sized properly and with no ob structions.
e. COMBUSTION ANALYSIS. Perform an "as is" combustion analysis (CO, O 2 , 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 fir e) ii. Draft at inlet to draft hood or barometric damp er 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.Rule 1146.1 (Cont.) (Amended September 5, 2008)

1146.1-15 iv. Unit rate if meter is available. 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 boile r, steam generator, or process

heater output rate and thermal efficiency to decrea se. 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 d iffuser spuds, gas canes, etc. Look for any burned-off or missing burner par ts, and replace as needed. b. CHECK FOR CLEAN BOILER, STEAM GENERATOR, OR PRO CESS

HEATER TUBES & HEAT TRANSFER SURFACES. External and internal build-up of sediment and sc ale on the heating surfaces

creates an insulating effect that quickly reduces u nit efficiency. Excessive fuel cost will result if the unit is not kept clean. Cl ean 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 flush ing 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 LEA KS Repair all leaks immediately since even small hig h-pressure leaks quickly lead

to considerable fuel, water and steam losses. Be s ure there are no leaks through the blow-off, drains, safety valve, by-pass lines or at the feed pump, if
used.
3. SAFETY CHECKS a. Test primary and secondary low water level cont rols. b. Check operating and limit pressure and temperat ure controls. c. Check pilot safety shut off operation. d. Check safety valve pressure and capacity to mee t boiler, steam generator or

process heater requirements.Rule 1146.1 (Cont.) (Amended September 5, 2008)

1146.1-16 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 adju stments as follows: a. Adjust unit to fire at rate; record fuel manifo ld pressure. b. Adjust draft and/or fuel pressure to obtain acc eptable, clean combustion at

both high, medium and low fire. Carbon Monoxide (C O) value should always be below 400 parts per million (PPM) at 3% 0 2 . If CO is high make necessary adjustments. Check to ensure boiler, steam generator, or proce ss heater light offs are

smooth and safe. A reduced fuel pressure test at b oth high and low fire should
be conducted in accordance with the manufacturers i nstructions and
maintenance manuals. c. Check and adjust operation of modulation contro ller. 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, whenev er 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 (Hi gh, Medium and Low). c. Steam pressure or water temperature entering an d leaving boiler, steam

generator, or process heater.
d. Unit rate if meter is available. When the above checks and adjustments have been ma de, record data and attach combustion analysis data to boiler, steam generator , or process heater records indicating name and signature of person, title, com pany name, company address and date the tuneup was performed.