and Statement of the Legal and Factual Basis

Shasta County Department of Resource Management

Air Quality Management District 1855 Placer Street, Suite 101

Redding, CA 96001 530-225-5674

Evaluation Report and

Statement of the Legal and Factual Basis Regarding Proposed Renewal of a

Title V Operating Permit to

Sierra Pacific Industries, Anderson Division

For Equipment Located at:

19794 Riverside Avenue

Anderson, CA 96007

July 19, 2019

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Introduction The Shasta County Air Quality Management District proposes to renew the Title V operating permit to Sierra Pacific Industries, Anderson Division. This evaluation, with the proposed Title V operating permit, sets forth the legal and factual basis for the conditions contained within the proposed permit. The proposed permit contains several administrative permit amendments ranging from corrections of typographical errors to the significant permit modification by updating a recently replace permitted piece of equipment. Applicable Federal, State, and Local requirements are discussed in the following sections of this evaluation. Facility Description Sierra Pacific Industries, Anderson Division is a wood manufacturing facility with a newly constructed 31 MW (net) biomass "Qualifying Facility" capable of providing 250,000 lb/hr process steam to lumber drying kilns through the use of a steam turbine. Sierra Pacific Industries, Anderson Division is considered to be a Federal Major Source and subject to the Title V permitting program due to the facility’s potential to emit emissions of oxides of nitrogen (NOX). The facility was issued a Prevention of Significant Deterioration (PSD) Permit on June 6, 2014. Equipment Description The major equipment located at the Sierra Pacific Industries, Anderson Division, facility include:

Cogeneration Plant 1 Each – 250,000 lbs/hr. (468.5 MM Btu/Hr.) Dieffenbacher, Step-Grate Stoker Type

Wood-Fired Boiler 2 Each – 62.5 MMBtu/hr Low NOx Natural Gas Burners 1 Each – 31 Megawatt Steam Turbine 1 Each – Multicone for Control of Coarse Particulate 1 Each – Three-Field Electrostatic Precipitator for Fine Particulate Matter 1 Each – Selective Non-Catalytic Reduction Ammonia Injection System for NOx Control 1 Each – Three-Cell Water Cooling Tower 1 Each – 35’ Ash Storage Silo 1 Each – 8.5’ Diameter Exhaust Stack, 85’ AGL

1 Each - Hydraulic Truck Trailer Dumper 1 Each - 32,400 cuft Fuel Storage Building 2 Each – Wood Chip Fuel Bins Planer Mill Air Conveyance System 2 Each - 8'D x 27'L Cyclones with combined flow rate of 51,004 SCFM 1 Each - 7,118 ft2 MAC Pulse Jet Baghouse with 300 HP TCF Blower 1 Each - 35" x 45" Rotary Airlock 1 Each - Buhler en-masse, 19", 22tph Conveyor 2 Each - Overhead Storage Bins with enclosed sides

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Closed Loop Spray Mist Unit 1 Each - Closed Loop Spray Mist Unit with Integrated, Negative Pressure, Mist Collection System and 65' Exhaust Stack

Wood Chip Loading Facility

1 Each - Wood Chip Loading Facility consisting of: One Platform Truck Dumper, One Electrically Powered, Pneumatic, Wood Chip Conveying System with Dust Containment Hood, Blower Specifications; Rader 200 H.P., 59,000 CFM

As approved by the U.S. Environmental Protection Agency (U.S. EPA), all equipment exempted from permit, per Shasta County Air Quality Management District (District) Rule 2.5, are each considered an insignificant activity. These include the following: Insignificant Emissions Sources

7 Each - Non-Solvent Based Degreasing Tanks 1 Each - 10,000 gal. Above Ground, Gasoline Storage Tank 1 Each - Painting Operation 1 Each – 256 H.P. Natural Gas-Fired Emergency Backup Feedwater Pump Engine

APPLICABLE FEDERAL REQUIREMENTS:

Based upon information submitted in the application and the District's review, the following applicable requirements are included:

SIP Requirements:

Rule 1.1 Title This rule establishes the Title of the Shasta County Air Quality Management District and the Rules and Regulations known and enforced by the District. The Title of the District shall be incorporated throughout the proposed Title V permit. Rule 1:2 Definitions This rule lists the definitions used throughout the District book of Rules and Regulations. This rule is an administrative rule and the District believes that the environmental benefits are not such that this rule should be included in the proposed Title V permit. Permits Rule 2.1 and 2.1A New Source Review, Permits Required These are the District’s requirements for preconstruction permits and permits to operate. This rule is an administrative and procedural rule that is applied when a source is modified or constructed. The District believes that the environmental benefits are not such that this rule should be included in the proposed Title V permit.

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Rule 2:4 Permits to Sell or Rent Incinerators This rule pertains to the use of incinerators. There are no incinerators at this facility. Therefore, this requirement is not applicable to this facility and will not be incorporated within the proposed Title V permit. Rule 2:5 Exemptions This rule lists the types of devices or operations that the Air Pollution Control Officer may exempt. This rule is addressed in Rule 5, attachment 1 (insignificant activities), therefore, the District believes that the environmental benefits are not such that this rule should be included in the proposed Title V permit. Rule 2:6 Open Burning (2:6.a.4.c & 2:6.b) Rule 2:7 Conditions for Open Burning Rule 2:8 Agricultural Burning These rules list the regulations required to conduct open burning operations. Sierra Pacific Industries, Anderson Division, does not conduct open burning operation at this facility. This rule is not included in the proposed Title V permit. Rule 2:10 Applications This rule states that all applications for an Authority to Construct, Permit to Operate, or permit to sell or rent shall be filed in the manner and on the form prescribed by the Air Pollution Control Officer. This rule is an administrative rule and the District believes that the environmental benefits are not such that this rule should be included in the proposed Title V permit. Rule 2:12 Expiration of Applications This rule requires that an Authority to Construct application will expire after the Permit to Operate has been issued or eighteen (18) months after the Authority to Construct was issued unless construction has commenced on the site or a time extension is granted by the Air Pollution Control Officer. It also states that a Permit to Operate application will expire two years after being issued. This rule is an administrative rule and the District believes that the environmental benefits are not such that this rule should be included in the proposed Title V permit.

Rule 2:14 Testing Facilities This rule requires the operator to provide and maintain testing and sampling facilities as specified in the Authority to Construct or Permit to Operate. This requirement is included in the proposed Title V permit.

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Rule 2:21 Transfer This rule states that an Authority to Construct, Permit to Operate, or Permit to Sell or Rent shall not be transferable, whether by operation of law or otherwise, either from one location to another, from one person to another, except on the written approval of the Air Pollution Control Officer. This requirement is included in the proposed Title V permit. Rule 2:23 Posting of Permit This rule requires that the permit be posted. This requirement is included in the proposed Title V permit. Rule 2:24 Defacing Permit (formerly Rule 2:21) This rule requires that a permit not be defaced. This requirement is included in the proposed Title V permit.

Rule 2:25 Public Records, Trade Secrets This rule lists the requirements for what may or may not be public records and includes labeling requirements. This requirement is included in the proposed Title V permit. Prohibitions and Enforcement Rule 3:1 Applicability of State Laws This rule adopts by reference all state and federal rules for air contaminants. This requirement is included in the proposed Title V permit. Rule 3:2 Specific Air Contaminants This rule specifies limits for emissions of: 1) Combustion particulate matter in gr/dscf; 2) Particulate matter less than or equal to 10 microns in gr/dscf; 3) All other particulate matter in gr/dscf; 4) Particulate matter process weight: maximum hourly emissions as a function of process

weight in tons per hour; 5) Oxides of Sulfur (as SO2) in ppm; 6) Oxides of Nitrogen (as NO2) in ppm; and 7) Opacity. The requirements of this rule are included in the proposed Title V permit. Other permit conditions found in the Title V Permit limiting emissions from the facility are more stringent than the emission limitations of this rule and, therefore, subsume the requirements of this rule for the particular emission unit. (See section below titled New Source Performance Standards.)

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Rule 3:3 Gasoline Loading and Transfer This rule limit the amount of volatile organic compounds (VOC’s) emissions from the transfer of gasoline into stationary storage containers, delivery vessels, bulk plants and terminals, and into motor vehicle fuel tanks. These operations do not occur at this facility therefore, this requirement is not included in the proposed Title V permit. Rule 3:4 Industrial Use of Organic Solvents This rule requires that a control device achieving 85 percent control be utilized unless listed lb/day emission limits of solvents into the atmosphere are met. Industrial Use of Organic solvents do occur at this facility, therefore, this requirement is included in the proposed Title V permit. Rule 3:5 Agricultural Uses This rule exempts discharges in the course of applying agricultural materials. This facility does not apply agricultural materials. Therefore, this requirement is not included in the proposed Title V permit.

Rule 3:6 Circumvention This rule requires that emissions cannot be concealed by circumvention. This requirement is included in the proposed Title V permit. Rule 3:8 Enhanced Monitoring and Compliance Certification for Major Sources as Defined

by Title V. This rule provides standards or compliance determinations required by, or derived from, federal law for the operation of any article, machine, equipment, or other contrivance within the District which may cause the issuance of air contaminants, or the use of which may eliminate, reduce, or control the issuance of air contaminants. This rule is relevant to this facility because it is subject to the Federal Boiler MACT Subpart DDDDD and the District believes that the environmental benefits are such that this rule should be included in the proposed Title V permit. Rule 3:9 Recommendations of Control Officer This rule states that no recommendation of the Air Pollution Control Officer is a guarantee that the recommended device or process will result in compliance. This rule is an administrative rule, and the District believes that the environmental benefits are not such that this rule should be included in the proposed Title V permit. Rule 3:11 Local Rules This rule states that any city or public agency, having authority to do so, may enact by ordinance more restrictive rules than contained in the District's rule book. Because this permit is a federal permit and does not concern local rules, the District believes that the environmental benefits are not such that this rule should be included in the proposed Title V permit.

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Rule 3:12, Reduction of Animal Matter, Rule 3:14, Petroleum Solvent Dry Cleaners, Rule 3:15, Cutback Asphalt Paving, Sierra Pacific Anderson does not conduct any of these operations. Therefore, these requirements are not included in the permit action. Rule 3:17 Organic Solvent Degreasing Operations This rule required degreasing operations to meet design and operating practice specifications. This rule was passed by the District when the District adopted a revised organic solvent operations rule. The new Rule 3:17 has not been submitted for inclusion into the SIP and, therefore, the District believes that the environmental benefits are not such that this rule should be included in the proposed Title V permit. Rule 5 Additional procedures for issuing permits to operate for sources subject to Title V

of the Federal Clean Air Act Amendments of 1990 This rule lists the requirements of the Title V program. All specific applicable requirements imposed by this rule are included in the proposed Title V permit. 40 CFR 82.161- Ozone Depleting Substances This regulation requires that equipment utilizing ozone depleting substances be maintained by certified technicians. These requirements are included in the proposed Title V permit. New Source Performance Standards (NSPS) This facility is subject to 40 CFR Part 60 - Standards of Performance for New Stationary Sources and Subparts A and Db. The requirements of these standards are included and are, in some instances, subsumed by other more stringent conditions in the proposed Title V permit. Prevention of Significant Deterioration (PSD) Permitting This regulation sets the procedures for the review of new sources or modifications to existing major stationary emission sources. Since the wood-fired boiler was issued a PSD permit as the Authority to Construct for the facility, most conditions of the Authority to Construct/PSD Permit have been incorporated in the proposed Title V permit unless a specific condition was revised (or added) in subsequently issued Permits to Operate.

Applicable Rules not included in the Shasta County SIP: Rule 3:11, Hexavalent Chromium Airborne Toxic Control Measure For Cooling Towers The requirements of this rule have been added to the proposed permit. See Specific Permit Actions and Modifications section.

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Risk Management Plans Preparation and Registration, 112 (r) Section 112(r), Accidental Release Prevention and Management Program, affects facilities at which certain substances are present above the specified annual threshold. Sierra Pacific Industries, Anderson Division, is not required to submit a 112(r) Risk Management Plan. MACT Standards for Halogenated Solvent Cleaning Operations This regulation requires de-greasers using certain halogenated solvents to meet certain requirements. Because the degreaser does not use solvents regulated by the standard, the Maximum Achievable Control Technology (MACT) standard is not an applicable requirement for this facility. The permit is conditioned so that the permittee must notify the District prior to changing the type of solvent used at the facility. Federal/State Greenhouse Gas Permitting and Reporting Requirements Both the State of California and the United States Environmental Protection Agency (EPA) regulate greenhouse gases (GHG’s) under the Clean Air Act (CAA) and the Global Solutions Act (AB32) from mobile and stationary sources of air pollution. These regulations set forth thresholds for greenhouse gas emissions as well as reporting requirements for facilities permitted under New Source Review and PSD programs. At the time of regulation adoption, EPA proposed a three-year deferral of the regulation for “biogenic” carbon dioxide, non-fossil fuel carbon dioxide sources such as ethanol and biomass. SPI Anderson is a biomass fueled cogeneration plant and therefore fit into this initial “deferral” category. Now that the deferral period is over, the GHG regulations requires that all facilities which emit 25,000 metric tons or more of CO2 per year provide EPA with accurate and timely GHG emissions data. SPI is a biomass-fired electricity generation facility which utilizes power on-site as well as supplies power to the Pacific Gas & Electric (PG&E) grid. Because the SPI Anderson facility’s combustion of biomass results in emissions greater than 25,000 metric tons of carbon dioxide, SPI Anderson is subject to the GHG reporting and verification requirements. A condition of Greenhouse Gas mandatory reporting requirements will be incorporated into the Title V permit. 40 CFR Part 63 Subpart DDDD National Emission Standards for Hazardous Air Pollutants HAP’s for Plywood and Composite Wood Products This subpart establishes national compliance options, operating requirements, and work practice requirements for hazardous air pollutants (HAP) emitted from plywood and composite wood products (PCWP) manufacturing facilities (including kiln-dried lumber) designated as a major source of HAP. SPI Anderson operates lumber drying kilns but according to section 63.2252 of this subpart, lumber kilns are not required to comply with the compliance options, work practice requirements, performance testing, monitoring, SSM plans, and recordkeeping or reporting requirements except for the initial notification requirements, therefore, SPI Anderson’s operation of kiln dried lumber does not apply to this section so additional conditions will not be incorporated into the Title V permit.

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National Emission Standards for Hazardous Air Pollutants for Industrial, Commercial, and Institutional Boilers and Process Heaters; Final Rule (40 CFR Part 63, Subpart DDDDD) This subpart establishes national emission limitations and work practice standards for hazardous air pollutants (HAP) emitted from industrial, commercial, and institutional boilers and process heaters located at major sources of HAP. This subpart also establishes requirements to demonstrate initial and continuous compliance with the emission limitations and work practice standards. Sierra Pacific Industries, Anderson is considered a major source of HAP, therefore, requirements within this subpart will be incorporated in the Title V Permit. §63.7480 – This section defines the purpose of the subpart. It establishes the national emission limitations and work practice standards for hazardous air pollutants emitted from industrial boilers that are located at a major source of HAPs. This subpart also establishes the requirements to demonstrate initial and continuous compliance with the emission limitations and work practice standards. §63.7485 – This section determines whether a facility is subject to this subpart. A facility is subject to this subpart if the facility is an industrial, commercial, or institutional boiler or process heater as defined by §63.7575 and it is located at a major source of HAPs as defined by §63.2. An industrial boiler is defined as “a boiler used in manufacturing, processing, mining, and refining or any other industry to provide steam, hot water and/or electricity.” A major source is defined as “any stationary source or group of stationary sources located within a contiguous area and has the potential to emit, considering controls, in the aggregate, 10 tons per year or more of any hazardous air pollutant or 25 tons per year or more of any combination of hazardous air pollutants…” Sierra Pacific Anderson meets both the definitions for an industrial boiler and a major source of HAPs, therefore the facility is subject to all applicable sections of this subpart. §63.7490 – This section defines what sources are affected by the implementation of this subpart. An affected source is the collection of all existing, new, and reconstructed industrial, commercial, and institutional boilers located at a major source of HAPs. Sierra Pacific Anderson is considered an existing facility at a major source. §63.7491 – This section lists the types of boilers and process heaters that are not subject to this subpart. The boiler at Sierra Pacific Anderson does not meet any of the exemptions criteria, therefore this subpart applies. §63.7495 – This section specifies the compliance dates for new, reconstructed, and existing boilers. Sierra Pacific Anderson was considered an area source that has increased its emissions above the major source threshold when the new boiler was constructed. Subparagraph (c) states that new boilers must comply with this subpart upon startup. Subparagraph (d) states that the facility must meet the notification requirements in §63.7545 according to the schedule in §63.7545 and in 40 CFR, Part 63 subpart A. This facility is subject to this subpart. §63.7499 – This section defines the subcategories of boilers. The boiler at Sierra Pacific Anderson meets the definition of a stoker/sloped grate/other units designed to burn wet biomass/bio-based solid, therefore, this subpart applies to this facility.

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§63.7500 – This section specifies the emission limitations, work practice standards, and operating limits that the facility must meet. Paragraph (a) states the facility must meet the requirements in paragraphs (a)(1) through (3) of this section. The facility is required to meet these requirements at all times that the boiler is operating, except as provided in paragraph (f) of this section. Paragraph (a)(1) states the facility must meet each emission limit and work practice standard in Tables 1 through 3, and 11 through 13 of this subpart that applies to each affected boiler at the facility, except as provided under §63.7522. Additionally, section (a)(2) defines operating limits as indicated in Table 4. Table 1 is applicable to the Sierra Pacific Anderson boiler since it contains the emission limits for new boilers. Section (1) a. and b. designate the HCl and mercury emission limits. Section (7) a. and b. designate the CO and filterable PM limits. Below is an excerpt of Table 1 that contains all the applicable work standard practices for the Sierra Pacific Anderson boiler. These emission limits have been included in the proposed Title V Permit, Condition A1.

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Table 1 to Subpart DDDDD of Part 63 – Emission Limits for New Boilers and Process Heaters

If your boiler or process heater is in this subcategory

For the following pollutants

The emissions must not exceed the following emission limits, except during startup and shutdown

The emissions must not exceed the following alternative output-based limits, except during startup and shutdown

Using this specified sampling volume or test run duration

1. Units in all subcategories designed to burn solid fuel.

a. HCl 2.2E-02 lb per MMBtu of heat input 2.5E-02 lb per MMBtu of steam output or 0.28 lb per MWh

For M26A, collect a minimum of 1 dscm per run; for M26 collect a minimum of 120 liters per run.

b. Mercury 8.0E-07a lb per MMBtu of heat input

8.7E-07a lb per MMBtu of steam output or 1.1E-05a lb per MWh

For M29, collect a minimum of 4 dscm per run; for M30A or M30B, collect a minimum sample as specified in the method; for ASTM D6784b collect a minimum of 4 dscm.

7. Stokers/sloped grate/others designed to burn wet biomass fuel

a. CO (or CEMS)

620 ppm by volume on a dry basis corrected to 3 percent oxygen, 3-run average; or (390 ppm by volume on a dry basis corrected to 3 percent oxygen,d 30-day rolling average)

5.8E-01 lb per MMBtu of steam output or 6.8 lb per MWh; 3-run average

1 hr minimum sampling time.

b. Filterable PM (or TSM)

3.0E-02 lb per MMBtu of heat input; or (2.6E-05 lb per MMBtu of heat input)

3.5E-02 lb per MMBtu of steam output or 4.2E-01 lb per MWh; or (2.7E-05 lb per MMBtu of steam output or 3.7E-04 lb per MWh)

Collect a minimum of 2 dscm per run.

Table 3 contains the work practice standards for the various boilers and process heaters with a continuous oxygen trim system. Below is an excerpt of Table 3 that contains all the applicable work practice standards for the Sierra Pacific Anderson boiler. To summarize briefly the work practice standards for the boiler at Sierra Pacific Anderson, the facility shall be required to conduct a tune-up of the boiler every 5 years, and follow startup and shutdown procedures. The work practice standards have been incorporated into the Title V Permit, Condition C4.

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Table 3 to Subpart DDDDD of Part 63 – Work Practice Standards

If your unit is… You must meet the following… 1. A new or existing boiler or process heater with a continuous oxygen trim system that maintains an optimum air to fuel ratio, or a heat input capacity of less than or equal to 5 million Btu per hour in any of the following subcategories: unit designed to burn gas 1; unit designed to burn gas 2 (other); or unit designed to burn light liquid, or a limited use boiler or process heater

Conduct a tune-up of the boiler or process heater every 5 years as specified in §63.7540.

5. An existing or new boiler or process heater subject to emission limits in Table 1 or 2 or 11 through 13 to this subpart during startup

You must operate all CMS during startup. For startup of a boiler or process heater, you must use one or a combination of the following clean fuels: natural gas, synthetic natural gas, propane, distillate oil, syngas, ultra-low sulfur diesel, fuel oil-soaked rags, kerosene, hydrogen, paper, cardboard, refinery gas, and liquefied petroleum gas.

If you start firing coal/solid fossil fuel,biomass/bio-based solids, heavy liquid fuel, or gas 2 (other) gases, you must vent emissions to the main stack(s) and engage all of the applicable control devices except limestone injection in fluidized bed combustion (FBC) boilers, dry scrubber, fabric filter, selective non-catalytic reduction (SNCR), and selective catalytic reduction (SCR). You must start your limestone injection in FBC boilers, dry scrubber, fabric filter, SNCR, and SCR systems as expeditiously as possible. Startup ends when steam or heat is supplied for any purpose. You must comply with all applicable emission limits at all times except for startup or shutdown periods conforming with this work practice. You must collect monitoring data during periods of startup, as specified in §63.7535(b). You must keep records during periods of startup. You must provide reports concerning activities and periods of startup, as specified in §63.7555.

6. An existing or new boiler or process heater subject to emission limits in Tables 1 or 2 or 11 through 13 to this subpart during shutdown

You must operate all CMS during shutdown. While firing coal/solid fossil fuel, biomass/bio-based solids, heavy liquid fuel, or gas 2 (other) gases during shutdown, you must vent emissions to the main stack(s) and operate all applicable control devices, except limestone injection in FBC boilers, dry scrubber, fabric filter, SNCR, and SCR.

You must comply with all applicable emissions limits at all times except for startup or shutdown periods conforming with this work practice. You must collect monitoring data during periods of shutdown, as specified in §63.7535(b). You must keep records during periods of shutdown. You must provide reports concerning activities and periods of shutdown, as specified in §63.7555.

§63.7500 – Paragraph (a)(2) states that the facility must meet each operating limit in Table 4 to this subpart that applies to the boiler or process heater. If you use a control device or combination of control devices not covered in Table 4 to this subpart, or you wish to establish and monitor an alternative operating limit or an alternative operating parameter, you must apply to the EPA Administrator for approval of alternative monitoring under §63.8(f). This section applies to Sierra Pacific Anderson, and no request for an alternative monitoring parameter was made.

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Table 4 to Subpart DDDDD of Part 63 – Operating Limits for Boilers and Process Heaters When complying with a Table 1, 2, 11, 12 or 13 numerical emission limit using… You must meet these operating limits… 4. Electrostatic precipitator control on units not using PM CPMS

a. This option is for boilers and process heaters that operate dry control systems (i.e., an ESP without a wet scrubber). Existing and new boilers and process heaters must maintain opacity to less than or equal to 10 percent opacity or the highest hourly average opacity reading measured during the performance test run demonstrating compliance with the PM (or TSM) emission limitation (daily block average); or

b. This option is only for boilers and process heaters not subject to PM CPMS or continuous compliance with an opacity limit (i.e., dry ESP). Maintain the 30-day rolling average total secondary electric power input of the electrostatic precipitator at or above the operating limits established during the performance test according to §63.7530(b) and Table 7 to this subpart.

7. Performance testing For boilers and process heaters that demonstrate compliance with a performance test, maintain the operating load of each unit such that it does not exceed 110 percent of the highest hourly average operating load recorded during the most recent performance test.

§63.7500 – Paragraph (a)(3) states that at all times, the facility must operate and maintain the boilers, including associated air pollution control equipment and monitoring equipment, in a manner that is consistent with safety and good air pollution practices for minimizing emissions. §63.7500 – Paragraph (f) states that the standards apply at all times the boilers are operating, except during startup and shutdown, during which time the facility must comply only with the requirements specified in Table 3 of this subpart. §63.7505 – This section includes the general requirements for complying with this subpart. Paragraph (a) states that the facility must be in compliance with the emission limits, work practice standards, and operating limits at all times that the boilers are operating, except for periods of startup and shutdown making the requirements that are specified in §63.7500(f) applicable. Paragraph (c) states that the facility must demonstrate compliance with all applicable emission limits using performance stack testing, fuel analysis, or continuous monitoring systems. The facility may demonstrate compliance with the applicable emission limit for hydrogen chloride (HCl), mercury, or total selected metals (TSM) using fuel analysis if the emission rate calculated according to §63.7530(c) is less than the applicable emission limit, otherwise the facility must demonstrate compliance using performance testing. According to paragraph (d) a facility that demonstrates compliance with any applicable emission limit through performance testing and subsequent compliance with operating limits, or with a continuous emission or opacity monitor, the facility must develop a site-specific monitoring plan according to the requirements specified in paragraphs (d)(1) through (d)(4) for the use of any continuous emission monitor or opacity monitor.

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Paragraph (d)(1) states that for each continuous monitor that is required by this section, the facility must develop and submit to the Administrator for approval upon request, a site-specific monitoring plan that addresses design, data collection, and the quality assurance and quality control elements outlined in §63.8(d) and the elements described in paragraphs (d)(1)(i) through (iii). The facility must submit the site-specific monitoring plan at least 60 days before the initial performance evaluation of the continuous monitors, if requested. The requirement for the site-specific monitoring plan does not apply to the boilers that have existing CEMS or COMS that are operated according to the performance specifications under 40 CFR 60, appendix B, and meet the requirements of §63.7525. Paragraph (d)(2) states that the site-specific monitoring must also include the requirements of (d)(2)(i) through (iii) of this section. Paragraphs (d)(3) and (d)(4) state that the facility must conduct a performance evaluation of each continuous monitor in accordance with the site-specific monitoring plan. And the facility must operate and maintain the continuous monitor in continuous operation according to the site-specific monitoring plan. §63.7510 – This section specifies the initial compliance requirements and the compliance dates for the initial compliance requirements. Paragraph (a) specifies that for each boiler that is required to demonstrate compliance with the applicable emission limits in Table 1, through performance testing, the initial compliance requirements include the following:

• Conduct the performance test according to §63.7520 and Table 5. • Conduct a fuel analysis for each type of fuel burned in the boiler according to §63.7521

and Table 6. For each boiler that burns a single type of fuel, the facility is not required to conduct a fuel analysis for each type of fuel burned in the boiler. For boilers that use a supplemental fuel only for startup, shutdown, and flame stability purposes, the boiler is still considered as using a single fuel and the supplemental fuel is not subject to the fuel analysis requirement.

• Establish operating limits according to §63.7530 and Table 7. • Conduct continuous monitor performance evaluations according to §63.7525.

Table 5 to Subpart DDDDD of Part 63 – Performance Testing Requirements

To Conduct a performance test for the following pollutant You must… Using… 1. Filterable PM a. Select sampling ports

locations and the number of traverse points

Method 1 at 40 CFR part 60, appendix A-1 of this chapter.

b. Determine velocity and volumetric flow-rate of the stack gas

Method 2, 2F, or 2G at 40 CFR part 60, appendix A-1 or A-2 to part 60 of this chapter.

c. Determine oxygen or carbon dioxide concentration of the stack gas

Method 3A or 3B at 40 CFR part 60, appendix A-2 to part 60 of this chapter, or ANSI/ASME PTC 19.10-1981.a.

d. Measure the moisture content of the stack gas


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e. Measure the PM emission concentration

Method 5 or 17 (positive pressure fabric filters must use Method 5D) at 40 CFR part 60, appendix A-3 or A-6 of this chapter.

f. Convert emissions concentration to lb per MMBtu emission rates

Method 19 F-factor methodology at 40 CFR part 60, appendix A-7 of this chapter.

2. TSM a. Select sampling ports locations and the number of traverse points








e. Measure the TSM emission concentration




3. Hydrogen chloride a. Select sampling ports locations and the number of traverse points








e. Measure the hydrogen chloride emission concentration

Method 26 or 26A (M26 or M26A) at 40 CFR part 60, appendix A-8 of this chapter.



4. Mercury a. Select sampling ports locations and the number of traverse points






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e. Measure the mercury emission concentration

Method 29, 30A, or 30B (M29, M30A, or M30B) at 40 CFR part 60, appendix A-8 of this chapter or Method 101A at 40 CFR part 61, appendix B of this chapter, or ASTM Method D6784.a.



5. CO a. Select sampling ports locations and the number of traverse points


b. Determine oxygen concentration of the stack gas

Method 3A or 3B at 40 CFR part 60, appendix A-3 of this chapter, or ASTM D6522-00 (Reapproved 2005), or ANSI/ASME PTC 19.10-1981.a.

c. Measure the moisture content of the stack gas


d. Measure the CO emission concentration

Method 10 at 40 CFR part 60, appendix A-4 of this chapter. Use a measurement span value of 2 times the concentration of the applicable emission limit.

Table 6 contains fuel analysis requirements along with the proper test/collection procedures depending on which pollutant the fuel analysis is for. Table 6 to Subpart DDDDD of Part 63 – Fuel Analysis Requirements

To conduct a fuel analysis for the following pollutant… You must… Using… 1. Mercury a. Collect fuel samples Procedure in §63.7521(c) ASTM D6323a (for

solid) d. Determine heat content

of the fuel type ASTM E711a (for biomass), or ASTM D5864a for liquids and other solids, or ASTM D240a or equivalent.

e. Determine moisture content of the fuel type

ASTM E871a, or ASTM D5864a.

f. Measure mercury concentration in fuel sample

EPA SW-846-7471Ba or EPA 1631 or EPA 1631E (for solid samples), or EPA 821-R-01-013 (for liquid or solid), or equivalent.

g. Convert concentration into units of pounds of mercury per MMBtu of heat content

Equation 8 in §63.7530.

2. HCl a. Collect fuel samples Procedure in §63.7521 ASTM D6323a (for coal or biomass),

d. Determine heat content of the fuel type

ASTM E711a (for biomass), ASTM D5864, ASTM D240a or equivalent.

e. Determine moisture ASTM E871a, or ASTM D5864a.

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content of the fuel type f. Measure chlorine

concentration in fuel sample

EPA SW-846-5050a or ASTM E776a (for solid fuel), or EPA SW-846-9056a or SW-846-9076a (for solids or liquids) or equivalent.

g. Convert concentrations into units of pounds of HCl per MMBtu of heat content

Equation 7 in §63.7530. Equations 10 and 11 in §63.7530.

4. TSM a. Collect fuel samples ASTM D6323a (for coal or biomass) d. Determine heat

content of the fuel type ASTM E711a (for biomass), or ASTM D5864a for liquids and other solids

e. Determine moisture content of the fuel type

ASTM E871a, or ASTM D5864a.

f. Measure TSM concentration in fuel sample

ASTM D3683,a or ASTM D4606,a or ASTM D6357a or EPA 200.8a or EPA SW-846-6020,a or EPA SW-846-6020A,a or EPA SW-846-6010C,a EPA 7060a or EPA 7060Aa (for arsenic only), or EPA SW-846-7740a (for selenium only).

g. Convert concentrations into units of pounds of TSM per MMBtu of heat content

Table 7 to Subpart DDDDD of Part 63 – Establishing Operating Limits

If you have an applicable emission limit for …

And your operating limits are based on…

You must… Using… According to the following requirements

4. Carbon monoxide

a. Oxygen i. Establish a unit-specific limit for minimum oxygen level according to §63.7520

(1) Data from the oxygen analyzer system specified in 63.7525(a)

(a) You must collect oxygen data every 15 minutes during the entire period of the performance tests.

(b) Determine the hourly average oxygen concentration by computing the hourly averages using all of the 15-minute readings taken during each performance test.

(c) Determine the lowest hourly average established during the performance test as your minimum operating limit.

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5. Any pollutant for which compliance is demonstrated by a performance test

a. Boiler or process heater operating load

i. Establish a unit specific limit for maximum operating load according to 63.7520(c)

(1) Data from the operating load monitors or from steam generation monitors

(a) You must collect operating load or steam generation data every 15 minutes during the entire period of the performance test.

(b) Determine the average operating load by computing the hourly averages using all of the 15-minute readings taken during each performance test.

(c) Determine the average of the three test run averages during the performance test, and multiply this by 1.1 (110 percent) as your operating

SPI Anderson utilizes both biomass and natural gas in the boiler. The natural gas is only used for startup, shutdown, and flame stabilization, therefore the boiler is classified as burning a single fuel as defined in 63.7510 (a)(2)(i). Therefore, the facility is not subject to the fuel analysis requirement found in Table 6. Paragraph (b) states that for each boiler that the facility elects to demonstrate compliance with the applicable emission limits in Table 2 to this subpart for HCl, mercury, or TSM through fuel analysis, the initial compliance requirement is to conduct a fuel analysis for each type of fuel burned in the boiler according to §63.7521 and Table 6 of this subpart. The facility must also establish operating limits according to §63.7530 and Table 8 of this subpart. Table 8 to Subpart DDDDD of Part 63 – Demonstrating Continuous Compliance

If you must meet the following operating limits or work practice standards… You must demonstrate continuous compliance by… 1. Opacity a. collecting the opacity monitoring system data according to

63.7525(c) and §63.7535; and b. Reducing the opacity monitoring data to 6-minute

averages; and c. Maintaining opacity to less than or equal to 10 percent

(daily block average). 7. Electrostatic Precipitator Total Secondary Electric Power Input

a. Collecting the total secondary electric power input monitoring system data for the electrostatic precipitator according to §§63.7525 and 63.7535; and

b. Reducing the data to 30-day rolling averages; and c. Maintaining the 30-day rolling average total secondary

electric power input at or above the operating limits established during the performance test according to

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§63.7530(b). 8. Emission limits using fuel analysis

a. Conduct monthly fuel analysis for HCl or mercury or TSM according to Table 6 to this subpart; and

b. Reduce the data to 12-month rolling averages; and c. Maintain the 12-month rolling average at or below the

applicable emission limit for HCl or mercury or TSM in Tables 1 and 2 or 11 through 13 to this subpart.

9. Oxygen Content a. Continuously monitor the oxygen content using an oxygen analyzer system according to §63.7525(a). This requirement does not apply to units that install an oxygen trim system since these units will set the trim system to the level specified in §63.7525(a)(2).

b. Reducing the data to 30-day rolling averages; and c. Maintain the 30-day rolling average oxygen content at or

above the lowest hourly average oxygen level measured during the most recent CO performance test.

10. Boiler or process heater operating load

a. Collecting operating load data or steam generation data every 15 minutes

b. Maintaining the operating load such that it does not exceed 110 percent of the highest hourly average operating load recorded during the most recent performance test according to §63.7520(c).

Paragraph (c) states that if the boiler is subject to a carbon monoxide (CO) limit, the initial compliance demonstration for CO is to conduct a performance test according to Table 5 of Subpart DDDDD or conduct a performance evaluation of the continuous CO monitor according to §63.7525(a). Paragraph (d) states that if the boiler is subject to a PM limit, the initial compliance demonstration for PM is to conduct a performance test in accordance with §63.7520 and Table 5 of this subpart. Paragraph (e) states that if the facility demonstrates compliance with the mercury, HCl, or TSM based on fuel analysis, the facility must conduct a monthly fuel analysis according to §63.7521 for each type of fuel burned that is subject to an emission limit in Tables 1, 2, or 11 through 13. The monthly fuel analysis may be completed any time during the calendar month as long as the analysis is at least 14 days after the previous fuel analysis. If a new fuel type is to be combusted, prior to introducing the fuel into the boiler, a fuel analysis must be completed. If twelve consecutive monthly fuel analyses demonstrates that the facility’s at 75 percent or less of the compliance level, the facility may decrease the fuel analysis to quarterly for that fuel. If any quarterly sample exceeds the 75 percent threshold of the compliance level, or a new fuel type is introduced, the facility is required to return to monthly monitoring, until 12 months of fuel analyses are less than 75 percent of the compliance level. §63.7515 – This section specifies when the facility must conduct subsequent performance tests, fuel analyses and boiler tune-up. The facility must conduct all applicable performance tests according to §63.7520 on an annual basis, except as specified in paragraphs (b) through (e), (g), and (h). Annual performance tests must be complete no more than 13 months after the previous

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performance test, as specified in paragraphs (b) through (e), (g), and (h). If the results from the performance tests for a given pollutant for at least 2 consecutive years indicate that the facility’s emissions are at or below 75 percent of the emission limit for the pollutant, and if there are no changes in the operation of the boiler or air pollution control equipment that could result in an increase in emissions, then the facility may choose to conduct performance tests for the pollutant every third year. Each performance test must be conducted no more than 37 months after the previous performance test. If the facility elects to demonstrate compliance using emission averaging under §63.7522, the facility must conduct the performance test annually. If a performance test indicates that emissions exceed the emission limit or 75 percent of the emission limit for a pollutant, the facility must conduct the performance tests annually. If the facility is required to meet an applicable tune-up work practice standard, the facility is required to conduct an annual, biennial, or 5-year tune-up according to §63.7540(a)(10), (11), or (12), respectively. Each subsequent tune-up must be conducted no more than 13 months, 25 months, or 61 months, depending on if the facility is required to conduct annual, biennial, or 5-year tune-up, respectfully. The results of the performance tests and the associated fuel analyses are to be reported within 60 days after completion of the performance tests. The report must also verify that the operating limits for each boiler have not changed or provide documentation of revised operating limits established according to §63.7530 and Table 7. The report for the performance tests must include all applicable information required in §63.7550. §63.7520 – This section specifies the stack test methods and procedures that the facility must use. Paragraph (a) states that the facility must conduct all performance tests according to requirements of §63.7(c), (d), (f), and (h). The facility is required to develop a site-specific stack test plan according to the requirements found in §63.7(c). All performance tests shall be conducted under such conditions that are based on the representative performance of each boiler for the period being tested. Paragraph (b) requires that the facility conduct each performance test according to the requirements in Table 5. Paragraph (c) requires that the facility conducts each performance test under the specific conditions listed in Tables 5 and 7. The performance tests must be conducted at representative operating load conditions, while combusting the type of fuel or mixture of fuels that has the highest content of chlorine and mercury, and TSM if the facility is opting to comply with the TSM alternative standard. And the facility must demonstrate initial compliance and establish the operating limits based on the performance tests. Following each performance test and until the next performance test, the facility must comply with the operating limit for operating load conditions specified in Table 4. The facility must conduct a minimum of three separate test runs for each performance test. Each test run must comply with the minimum applicable sampling times or volumes as specified in Tables 1 and 2 or 11 through 13. To determine compliance with the emission limits, the facility is required to use the F-Factor methodology and equations in Sections 12.2 and 12.3 of EPA

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Method 19 at 40 CFR part 60, appendix A-7 of this chapter to convert the measured concentrations of PM, HCl, mercury, and TSM concentrations from the performance tests to pounds per million Btu heat input emission rates. §63.7521 – This section specifies the fuel analyses, fuel specifications, and procedures that the facility will be required to perform. For facilities that combust solid fuels, the facility must conduct fuel analyses for chloride and mercury according to the procedures outlined in paragraphs (b) through (e) of this section and Table 6, as applicable. If the facility is opting to comply with the TSM alternative standard, then the facility must also conduct fuel analyses for TSM. The facility is not required to conduct fuel analyses for fuels that are used exclusively for startup, shutdown, and transient flame stability purposes. The fuel analysis requirement is only for fuels and units that are subject to emission limits for mercury, HCl, or TSM in Tables 1 and 2 or 11 through 13. Paragraph (b) states that the facility must develop a site-specific fuel monitoring plan according to the procedures and requirements in paragraphs (b)(1) and (2) of this section, if the facility is required to conduct fuel analysis. If an alternative analytical method other than those required by Table 6, then the facility must submit the fuel analysis plan to the Administrator for review and approval no later than 60 days prior to the date the facility intends to conduct the initial compliance demonstration described in §63.7520. The following information must be included in the fuel analysis plan:

• Identification of all fuel types anticipated to be burned in each boiler. • For each anticipated fuel type, notification if the facility or fuel supplier will be conducting

the fuel analysis. • For each anticipated fuel type, a detailed description of the sample location and specific

procedures to be used for collecting and preparing the composite samples, if the procedures are different than those specified in paragraph (c) or (d) of this section. Samples should be collected at a location that most accurately represents the fuel type. And where possible, the fuel should be sampled at a point prior to mixing with other dissimilar fuel types.

• For each anticipated fuel type, the analytical methods from Table 6 to be used for the measurement of chlorine or mercury.

• If the facility requests to use an alternative analytical method other than those required by Table 6, the facility must also include a detailed description of the methods and procedures that are be proposed. The methods in Table 6 shall be used until the requested alternative is approved.

• If the facility opts to use a fuel analysis from the fuel supplier in lieu of site-specific sampling and analysis, the fuel supplier must use the analytical methods required by Table 6.

Paragraph (c) states that at a minimum, the facility must obtain three composite fuel samples for each fuel type according to the procedures in paragraphs (c)(1) and (2) of this section, or the methods listed in Table 6, or use an automated sampling mechanism that provides representative composite fuel samples for each fuel that includes both coarse and fine material. If sampling from a belt (or screw) feeder, the samples must be collected by the following:

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• Stop the belt and withdraw a 6-inch wide sample from the full cross-section of the stopped belt to obtain a minimum two pounds of sample. All the material, both fine and coarse, must be collected. The sample is to be transferred to a clean plastic bag.

• Each composite sample will consist of a minimum of three samples collected at approximately equal one-hour intervals during the testing period for sampling during performance stack testing. For monthly sampling, each composite sample shall be collected at approximately equal 10-day intervals during the month.

If the sampling from a fuel pile or truck, the samples must be collected by the following:

• For each composite sample, the facility must select a minimum of five sampling locations uniformly spaced over the surface of the pile.

• At each sampling site, the facility shall dig into the pile to a uniform depth of approximately 18 inches. A clean shovel must be used to withdraw a sample, making sure that large pieces do not fall off during sampling. The same shovel must be used to collect all the samples.

• The samples are to be transferred to a clean plastic bag for further processing. The fuel samples must be prepared according to the following procedures:

• Mix and pour the entire composite sample over a clean plastic sheet. • Break large sample pieces (larger than 3 inches) into smaller sizes. • Make a pie shape with the entire composite sample and subdivide it into four equal parts. • Separate one of the quarter samples as the first subset. • If this subset is too large for grinding, make the subset sample into a pie shape and

subdivide the subset into four equal parts. • Grind the sample in a mill. • Make the ground subset into a pie shape and subdivide into four equal parts. If this quarter

sample is too large, subdivide it further using the same procedure. Paragraph (e) requires that the facility determine the concentration of pollutants in the fuel in units of pounds per million Btu of each composite sample for each fuel type according to the procedures in Table 6, for use in Equations 7, 8, and 9 of this subpart. §63.7522 – This section outlines the procedures for emissions averaging over two or more units to comply with this subpart. Paragraph (a) states as an alternative to meeting the requirements of §63.7500 for PM, HCl, or mercury on a boiler, for a facility that has more than one existing boiler in any of the subcategories, the facility may demonstrate compliance by emissions averaging. To utilize the emissions averaging, the averaged emissions are not more than 90 percent of the applicable emission limit, according to the procedures in this section. New boilers may not be included into the emissions average. Paragraph (b) states that for a group of two or more existing boilers in the same subcategory that vent to a separate stack, the facility may average PM, HCl, or the mercury emission to demonstrate

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compliance with the limits in Table 2 as specified as follows, if the facility satisfies the requirement in paragraphs (c) through (g).

• The facility may average units using a Continuous Emissions Monitor. • For mercury and HCl, averaging is allowed for units in any of the solid fuel subcategories. • For PM averaging is allowed for stoker/sloped grate/other units designated to burn wet

biomass solids. Paragraph (c) states that for each boiler in the averaging group, the emission rate achieved during the initial compliance test for the hazardous air pollutant being averaged must not exceed the emission level that was being achieved on January 31, 2013, or the control technology employed during the initial compliance test must not be less effective for the hazardous air pollutant being averaged than the control technology employed on January 31, 2013. Paragraph (d) states that the averaged emissions rate from the existing boilers that are participating in the emissions averaging option must not exceed 90 percent of the limits that are specified in Table 2 at all times the boilers are operating following the compliance date in §63.7495. Paragraphs (e) and (f) specify the required equations for the initial and ongoing compliance using emissions averaging based on the maximum rated heat input capacity or maximum steam generation capacity of each unit and the results of the performance tests or fuel analysis. The facility must develop and submit to the Administrator for review and approval, an implementation plan for emissions averaging according to the procedures and requirements that are specified in paragraphs (g)(1) through (4) of this section. §63.7525 – This section specifies the monitoring, installation, operating, and maintenance requirements for the facility. If the boiler is subject to a CO emission limit specified in Table 1, 2, or 11 through 13 of this subpart, the facility must install, operate, and maintain an oxygen analyzer system, as defined in §63.7575, or install, certify, operate, and maintain continuous emission monitoring system for CO and oxygen according to the procedures in paragraphs (a)(1) through (7) of this section. The procedures specified in paragraph (a) include:

• Install the CO CEMS and O2 analyzer by the compliance date specified in §63.7495. The CO and O2 shall be monitored at the same location at the outlet of the boiler.

• To demonstrate compliance with the alternative CO emission standards, the facility must install, certify, operate, and maintain a CO CEMS and O2 analyzer according to the requirements specified in paragraph (a)(2).

• Complete a minimum of one cycle of CO and O2 operation, which includes sampling, analyzing, and data recording, for each successive 15-minute period. The CO and O2 data must be collected concurrently.

• The CO CEMS data must be reduced as specified in §63.8(g)(2). • The facility must calculate the one-hour arithmetic averages, corrected to 3 percent O2 for

each hour of CO CEMS data in parts per million CO concentration. This data shall be used to calculate the 30-day or 10-day rolling average emissions. To calculate the average CO emissions from the hourly averages, Equation 19-19 in Section 12.4.1 of Method 19 of 40 CFR part 60, appendix A-7 shall be used.

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• The CO CEMS shall be operated as specified in §63.7535(b). All the data collected during all periods must be used in calculating data averages and assessing compliance, except certain data must be excluded as specified in §63.7535(c). Periods when CO data are unavailable, may constitute monitoring deviations as specified in §63.7535(d).

• The facility must operate an oxygen trim system with the oxygen level set no lower than the lowest hourly average O2 concentration measured during the most recent CO performance test as the operating limit for O2 according to Table 7 of this subpart.

If the facility has an applicable opacity operating limit as specified in this rule, and are not required or elect to install and operate a PM CPMS, PM CEMS, or a bag leak detection system, the facility must install, operate, certify and maintain each COMS according to the procedures in paragraphs (c)(1) through (7) by the specified compliance dates. The procedures specified in paragraph (c) include:

• Each COMS must be installed, operated, and maintained according to Performance Specification 1 at appendix B to part 60 of this chapter.

• The facility is required to conduct a performance evaluation of each COMS according to the requirements in §63.8(e), and according to Performance Specification 1.

• Each COMS must complete a minimum of one cycle of sampling and analyzing for each successive 10-second period and one cycle of data recording for each successive 6-minute period.

• The CO CEMS data must be reduced as specified in §63.8(g)(2). • The facility must include in the site-specific monitoring plan procedures and acceptance

criteria for operating and maintaining each COMS according to the requirements in §63.8(d). At a minimum the monitoring plan must include a daily calibration drift assessment, a quarterly performance audit, and an annual zero alignment audit of each COMS.

• The facility must operate and maintain each COMS according to the requirements in the monitoring plan and the requirements of §63.8(e). All periods that the COMS is out of control including any periods that the COMS fails to pass a daily calibration drift assessment, a quarterly performance audit, or an annual zero alignment audit must be identified. Any 6-minute period for which the monitoring system is out of control and the data are not available for a required calculation constitutes a deviation.

• The facility shall be required to determine and record all 6-minute average (and daily block average) collected for periods during which the COMS is not out of control.

§63.7530 – This section specifies the requirements to demonstrate the initial compliance with the emission limitations, fuel specifications, and work practice standards. Paragraph (a) states that the facility is required to demonstrate the initial compliance with each applicable emission limit by conducting initial performance tests and fuel analyses, and establishing operating limits according to §63.7520, paragraphs (b) and (c), and Tables 5 and 7. The requirement for fuel analyses is not applicable to facilities that only burn a single type of fuel, as specified by §63.7510(a)(2)(i). The facility is also required to install, operate, and maintain all applicable Continuous Monitoring Systems according to §63.7525.

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Paragraph (b) states that if the facility demonstrates compliance through performance testing, the facility must establish each site-specific operating limit in Table 4 to this subpart that applies to the facility according to the requirements in §63.7520, Table 7 of this subpart, and paragraph (b)(4) of this section, as applicable. This section also requires the facility to conduct a fuel analyses according to §63.7521 and establish maximum fuel pollutant input levels according §63.7521 (a)(2). However, since the facility only combusts a single fuel type, biomass, the fuel testing requirements that are specified in this section are not applicable due to the exemption found in §63.7521 (a)(2)(i). However, if the facility switches to a different fuel and cannot show that the new fuel does not increase the chlorine, mercury, or TSM input into the unit through the results of fuel analysis, then the facility must repeat the performance tests to demonstrate compliance while burning the new fuel type. Paragraph (b)(4) specifies that the facility must establish parameter operating limits according to the subparagraphs under (b)(4). None of the scenarios specified in paragraphs (b)(4)(i) through (ix) are applicable to this facility. If the facility elects to demonstrate compliance with an applicable emission limit through fuel analysis, the facility must conduct the fuel analyses according to §63.7521, and follow the procedures in (c)(1) through (5) of this section. Paragraph (e) states that the facility must include with the Notification of Compliance Status a signed certification that the energy assessment was completed according to Table 3 to this subpart and is an accurate depiction of the facility at the time of the assessment. Paragraph (f) specifies that the facility must submit the Notification of Compliance Status containing the results of the initial compliance demonstration according to the requirement found in §63.7545(e). Paragraph (h) specifies that if the facility is subject to emission limits in Tables 1 or 2 or 11 through 13, the facility is required to meet the work practice standard according to Table 3. During startup and shutdown, the facility must only follow the work practice standards according to item 5 of Table 3. §63.7533 – This section details procedures if the facility decides to utilize efficiency credits earned from implementation of energy conservation measures to comply with this subpart. Paragraph (a) states that if the facility elects to comply with the alternative equivalent output-based emission limits, instead of the heat input-based limits as listed in Table 2, and the facility wants to take credit for implementing an energy conservation measure identified in an energy assessment, the facility may demonstrate compliance using efficiency credits according to the procedures in this section. This method may be used for demonstrating initial compliance according to §63.7522(e) and for demonstrating monthly compliance according to §63.7522(f). Paragraph (b) specifies for each affected boiler for which the facility intends to apply emissions credits, the facility shall establish a benchmark from which emission reductions credits may be generated by determining the actual annual fuel heat input to the affects boiler before initiation of an energy conservation activity to reduce energy demand according to paragraphs (b)(1) through (4).

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The efficiency credits can be generated if the energy conservation measures were implemented after January 1, 2008, and sufficient information is available to determine the appropriate value of credits. Paragraph (c)(1) specifies emission points that cannot be used to generate efficiency credits. And paragraph (c)(2) specifies the calculations required for the emissions credits. The facility shall develop and submit an Implementation Plan containing the information required in this paragraph for all boilers to be included in an efficiency credit approach. The Implementation Plan shall identify all existing affected boilers to be included in applying the efficiency credits. The Plan shall include a description of the energy conservation measures implemented and the energy saving generated, and an explanation of the criteria used for determining that savings. The emissions rate shall be calculated by use of Equation 20 and demonstrate compliance by demonstrating that the emissions from the affected boiler do not exceed the emission limits in Table 2. Documentation must be included with each compliance report that demonstrate that the energy conservation measures implemented continue to generate the credit for use in demonstrating compliance with the emission limits. §63.7535 – This section specifies the minimum amount of monitoring data the facility must obtain to demonstrate continuous compliance with the emission limits set forth in this subpart. The facility must monitor and collect data according to this section and the site-specific monitor plan, set forth in §63.7505(d). The facility is required to operate the monitoring system and collect data at all the required intervals at all times the boilers are operating, except for periods of monitoring system malfunctions or out of control periods, and required monitoring systems quality assurance activities. These activities include calibration checks, zero and span adjustments, and scheduled maintenance as defined in the site-specific monitoring plan. A monitoring` system malfunction is any sudden, infrequent, not reasonably preventable failure of the monitoring system. Monitoring system failures that are caused by poor maintenance or careless operation are not malfunctions. The facility is required to complete monitoring system repairs as expeditiously as practicable. The data during periods of monitoring system malfunctions, repairs associated with monitoring system malfunctions, or required monitoring system quality assurance activities, the facility may not use the data recorded to report emissions or operating levels. The facility must record and make available upon request the results of the continuous monitoring systems performance audits, and the dates and durations of periods with continuous monitoring systems are out of control to completion of the corrective action necessary to return the continuous monitors to proper operation. §63.7540 – This section specifies the requirements for the facility to demonstrate continuous compliance with the emission limitations, fuel specifications and work practice standards.

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The facility must demonstrate continuous compliance with each applicable emission limit in Tables 1 and 2 or 11 through 13, the work practice standards in Table 3, and the operating limits in Table 4 according to the methods in Table 8 and paragraph (a)(1) through (19) of this section. The applicable requirement for the demonstration of continuous compliance specified in Table 8 can be found earlier in this evaluation. In addition to the requirements specified in Table 8, the following will be required to demonstrate continuous compliance:

• After the initial compliance demonstration, operation above the established maximum or below the establish minimum operating limits shall constitute a deviation of the established operating limits listed in Table 4, except during performance tests conducted to determine compliance or establish new operating limits. The operating limits must be confirmed or reestablished during the performance tests.

• The facility is required to keep records of the type and amount of all fuels burned in each boiler, according to §63.7750(c) to demonstrate that all fuel types and mixtures of fuels burned would result in either lower emissions or lower fuel input of HCl (or chlorine), mercury, and TSM that are applicable emission limits.

• If the facility demonstrates compliance with the HCl emission limit through fuel analysis, and the facility plans to burn a new fuel type, then the facility must recalculate the HCl emission rate using Equation 12 from §63.7530 according to paragraphs (a)(3)(i) through (iii) of this section. But, the facility is not required to conduct fuel analysis for the fuels described in §63.7510(a)(2)(i). That section states for boilers that burn a single type of fuel, the facility is not required to conduct a fuel analysis for each type of fuel burned.

• If the facility demonstrates compliance with an applicable HCl emission limit through performance testing, and a new fuel type or mixture is planned on being burned, then the facility must recalculate the maximum chlorine input using Equation 7 found in §63.7530. If the calculated maximum chlorine input is greater than the maximum chlorine input level established during the previous performance test, then a new performance test within 60 day of burning the new fuel or fuel mixture is required. The facility, also, must establish new operating limits based on the new performance test and establish the new operating limits. For boilers that combust one fuel type, the facility is not required to conduct fuel analyses to recalculate the maximum chlorine input and establish new operating limits.

• If the facility demonstrates compliance with an applicable mercury emission limit through fuel analysis, and the facility plans to burn a new type of fuel, then the facility is required to recalculate the mercury emission rate using Equation 13 that is found in §63.7530 according to the procedures outlined in paragraphs (a)(5)(i) through (iii) of this section. But, the facility is not required to conduct fuel analysis for the fuels described in §63.7510(a)(2)(i). That section states for boilers that burn a single type of fuel, the facility is not required to conduct a fuel analysis for each type of fuel burned. The facility may also exclude those fuels when recalculating the mercury emissions.

• If the facility demonstrates compliance with an applicable mercury emission limit through performance testing, and a new fuel type or mixture is planned on being burned, then the facility must recalculate the maximum chlorine input using Equation 8 found in §63.7530. If the calculated maximum chlorine input is greater than the maximum chlorine input level established during the previous performance test, then a new performance test within 60 day of burning the new fuel or fuel mixture is required. The facility, also, must establish new operating limits based on the new performance test and establish the new operating

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limits. For boilers that combust one fuel type, the facility is not required to conduct fuel analyses to recalculate the maximum chlorine input and establish new operating limits.

• To demonstrate compliance with the applicable alternative CO CEMS emission limit listed in Tables 1, 2, or 11 through13, the facility must meet the following requirements:

o Continuously monitor CO emissions according to §§63.7525(a) and 63.7535. o Maintain CO levels at or below the alternative CO CEMS based standard in Tables

1, 2, or 11 through 13 at all times the boiler is operating. o Keep records of CO levels according to §63.7555(b). o The facility must make available results of CO CEMS performance audits, dates

and duration of periods that the CO CEMS is out of control. • For boilers that have a continuous oxygen trim system that maintains an optimum air to

fuel ratio, the facility is required to conduct a tune-up of the boiler every 5 years. The boiler tune-up includes:

o Inspect the burner, and clean or replace any components of the burners, as needed. The burner inspection may be scheduled during an outage, but no longer than 72 months from the previous inspection.

o Inspect the flame pattern, and adjust the burner to optimize the flame patterned, as needed.

o Inspect the system controlling the air-to-fuel ratio, and ensure that it is correctly calibrated and functioning properly.

o Optimize total CO emissions consistent with the manufacturer’s specifications and with NOx requirements.

o Measure the CO concentration in ppmv and O2 in volume percent, before and after adjustments are made.

o Maintain on-site and submit, if requested, an annual report containing the information found in paragraphs (a)(10)(vi)(A) through (C).

The facility is required to report each instance in which the facility did not meet each emission limit and operating limit from Tables 1 through 4, or 11 through 13. These instances are considered deviations and must be reported according to the requirements in §63.7550. For startup and shutdown, the facility is required to meet the work practice standards according to item 5 of Table 3. §63.7541 – This specifies the requirements for the facility to demonstrate continuous compliance under the emissions averaging provision. The facility must demonstrate compliance with this subpart on a continuous basis by meeting the following requirements:

• For each calendar month, demonstrate compliance with the average weighted emissions limit for units participating in the emissions averaging option as determined in §63.7522(f) and (g).

• The facility must maintain the opacity at or below the applicable limit. • For each unit that has an approved alternative operating parameter, the facility must

maintain the 30-day average parameter value consistent with the approved monitoring plan.

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At any time that the facility fails to comply with the above continuous monitoring requirements that is a deviation. §63.7545 – This section specifies what notifications the facility is required to submit and the date the notification is required to be submitted. For facilities that started up before January 31, 2013, an Initial Notification must be submitted no later than 120 days after January 31, 2013. SPI Anderson has fulfilled this requirement within the 120 day timeframe. Notification of Intent to conduct a performance test must be submitted 60 days before the performance test is scheduled to begin. If the facility is required to conduct an initial compliance demonstration, as specified in §63.7530, then the facility must submit a Notification of Compliance Status. For the initial compliance demonstration for each boiler, the facility must submit the Notification of Compliance Status, including all performance test results and fuel analyses and/or any other initial compliance demonstrations for the boilers. The Notification of Compliance Status report must contain all of the following information:

• A description of the boilers, including which subcategories the boiler is in, design heat input capacity, description of the add-on controls used on the boiler to comply with this subpart, description of the fuels burned, and justification for the selection of fuel burned during the compliance demonstration.

• Summary of the results of all performance tests and fuel analyses, and calculations conducted to demonstrate initial compliance including all operating limits.

• Summary of the maximum CO emission levels recorded during the performance test to verify that the facility has met any applicable emission standards, if the facility is not utilizing a CO CEMS to demonstrate compliance.

• State whether the facility plans to demonstrate compliance with each applicable emission limit through performance testing, CEMS, or fuel analyses.

• State whether the facility plans to demonstrate compliance by emissions averaging and identification of whether the facility plans to demonstrate compliance by using efficiency credits through energy conservation.

• A signed certification that the facility has met all the applicable emission limits and work practice standards.

• If the facility had deviations from any emission limit, work practice standard, or operating limit, the facility must also submit a description of the deviation, duration, and correction taken.

• In addition to in the information required in §63.9(h)(2), the notification of compliance status must include the certifications of compliance found in §63.7545(e)(8)(i) through (iii), as applicable, and signed by a responsible official.

If the facility switches fuel or makes modifications to the boiler, and that results in the applicability of a different subcategory, the facility must provide notice of the date of fuel change or modification with 30 days of such change. §63.7550 – This section specifies what reports the facility must submit and when the reports are due. The facility is required to submit each applicable report specified in Table 9.

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Table 9 to Subpart DDDDD of Part 63 –Reporting Requirements

You must submit a(n) The report must contain…

You must submit the report

1. Compliance report

a. Information required in §63.7550(c)(1) through (5); and Semiannually, annually, biennially, or every 5 years according to the requirements in 63.7550(b).

b. If there are no deviations from any emission limitation (emission limit and operating limit) that applies to you and there are no deviations from the requirements for work practice standards in Table 3 to this subpart that apply to you, a statement that there were no deviations from the emission limitations and work practice standards during the reporting period. If there were no periods during which the CMSs, including continuous emissions monitoring system, continuous opacity monitoring system, and operating parameter monitoring systems, were out-of-control as specified in 63.8(c)(7), a statement that there were no periods during which the CMSs were out-of-control during the reporting period; and

c. If you have a deviation from any emission limitation (emission limit and operating limit) where you are not using a CMS to comply with that emission limit or operating limit, or a deviation from a work practice standard during the reporting period, the report must contain the information in §63.7550(d); and

d. If there were periods during which the CMSs, including continuous emissions monitoring system, continuous opacity monitoring system, and operating parameter monitoring systems, were out-of-control as specified in §63.8(c)(7), or otherwise not operating, the report must contain the information in §63.7550(e)

The facility must submit each report according to paragraph (h), and according to the requirements in paragraphs (b)(1) through (4). The initial compliance report must cover the period beginning on the compliance date specified for each boiler and ending on July 31 or January 31, as applicable. The initial compliance report must be postmarked or submitted no later than 180 days after the end of the initial time period. Each subsequent compliance report must cover the semiannual reporting period from January 1 through June 30 or July 1 through December 31. And each subsequent report must be postmarked 180 days after the end of the reporting period. The compliance report must contain the following information, depending on how the facility chooses to comply with the limits.

• If the facility is subject to tune-up requirements, then the compliance report must contain the information in paragraphs (c)(5)(i) through (iv), and (xiv).

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• If the facility is complying with the fuel analysis, then the compliance report must contain the information in paragraphs (c)(5)(i) through (iv), (vi), (x), (xi), (xiii), (xv), and paragraph (d).

• If the facility is complying with the emissions limit with performance testing, the compliance report must contain the information in paragraphs (c)(5)(i) through (iv), (vi), (vii), (ix), (xi), (xiii), (xv), and paragraph (d).

• If the facility is complying with an emissions limit using a continuous monitoring system, the compliance report must contain the information in paragraphs (c)(5)(i) through (iv), (vi), (xi), (xiii), (xv) through (xvii), and paragraph (d).

For each deviation from an emission limit or operating limit that occurs at a boiler where the facility is not using a CMS to comply, the compliance report must contain the following information:

• A description of the deviation and which emission limit or operating limit was deviated from.

• Information on the number, duration, cause of deviations, and the corrective action taken. • If the deviation occurred during an annual performance test, provide the date the annual

performance test was completed. For each deviation from an emission limit, operating limit, and monitoring requirement that occurs at a boiler where the facility is using a CMS to comply with the applicable limits, the compliance report must additionally contain the following information, which includes any deviation from the site-specific monitoring plan.

• The date and time of when each deviation started and stopped, and the description of the deviation.

• The date and time that each CMS was inoperative, except for zero and span checks. • The date, time, and duration that each MCS was out of control, including the information

in §63.8(c)(8). • A summary of the total duration of the deviation during the reporting period and the total

duration as a percent of the total source operating time during the reporting period. • A characterization of the total duration of the deviations during the reporting periods into

those that are due to control equipment problems, process problems, other known causes, and other unknown causes.

• A summary to the total duration of the CMS’s down time during the reporting period and the total duration of the CMS down time as a percent of the total source operating time.

• A brief description of the source for which there was a deviation. • A description of any changes in CMS’s processes, or controls since the previous reporting

periods for which there was a deviation. Within 60 days after the date of completing each performance test, CEMS performance evaluation, and all reports required by Table 9 to the facility must submit the results of the tests, including any associated fuel analyses, to the EPA’s WebFire database by using the Compliance and Emission Data Reporting Interface (CEDRI) that is accessed through the EPA’s Central Data Exchange (CDX). Test data must be submitted in the file format generated through use of the EPA’s

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Electronic Reporting Tool (ERT). Only data collected using test methods on the ERT Web site are subject to this requirement for submitting reports electronically to WebFire. If the report form specific to this subpart is not available in CEDRI at the time that the report is due, the report must be submitted to the Administrator to the address listed in §63.13. If any material is to be submitted is confidential business information, the facility must complete the ERT file including the confidential business information on a commonly used electronic storage media to the EPA. And the media must be clearly marked as CBI and mailed to EPA. The same ERT file with the CBI omitted must be submitted to the EPA via CDX. §63.7555 – This section specifies what records must be kept by the facility. The facility must keep a copy of each notification and report that the facility submitted to comply with this subpart, including all documentation supporting any Initial Notification or Notification of Compliance Status or semiannual compliance report, according to the requirements in §63.10(b)(2)(xiv). Records of the performance test, fuel analyses, or other compliance demonstrations and performance evaluations as required in §63.10(b)(2)(viii). For each continuous monitoring system, the facility must keep records according to the following:

• Records as described in §63.10(b)(2)(vii) through (xi). • Monitoring data for continuous opacity monitoring system during a performance

evaluation as required in §63.6(h)(7)(i) and (iii). • Previous versions of the performance evaluation plan as required in §63.8(d)(3). • Requires for alternatives to relative accuracy test for CEMS as required in §63.8(f)(6)(i). • Records of the date and time that each deviation started and stopped.

The facility must keep the records required in Table 8 including records of all monitoring data and calculated averages for applicable operating limits to show continuous compliance with each applicable emission limit and operating limit. For each boiler that is subject to an emission limit in Tables 1, 2, or 11 through 13, the facility must also keep the following applicable records:

• Records of the monthly fuel use by each boiler, including the type of fuel and amount used. • A copy of all calculations and supporting documentation of maximum chlorine fuel input,

using Equation 7 from §63.7530, that were done to demonstrate continuous compliance with the HCl emission limit, for sources that demonstrate compliance through fuel analysis, a copy of all calculations and supporting documentations of HCl emission rates, using Equation 12 from §63.7530, that were done to demonstrate compliance with the HCl emission limit. Supporting documentation should include results of any fuel analyses and basis for the estimates of maximum chlorine fuel input or HCl emission rates. The facility can use the results from one fuel analyses for multiple boilers, since the facility burns only one fuel type. However, the facility must calculate chlorine fuel input, or HCl emission rate for each boiler.

• A copy of all calculations and supporting documentation of maximum mercury fuel input, using Equation 8 from §63.7530, that were done to demonstrate continuous compliance with the mercury emission limit, for sources that demonstrate compliance through fuel analysis, a copy of all calculations and supporting documentations of mercury emission

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rates, using Equation 13 from §63.7530, that were done to demonstrate compliance with the mercury emission limit. Supporting documentation should include results of any fuel analyses and basis for the estimates of maximum mercury fuel input or mercury emission rates. The facility can use the results from one fuel analyses for multiple boilers, since the facility burns only one fuel type. However, the facility must calculate mercury fuel input, or mercury emission rate for each boiler.

• A copy of all calculations and supporting documentation of maximum TSM fuel input, using Equation 9 from §63.7530, that were done to demonstrate continuous compliance with the TSB emission limit, for sources that demonstrate compliance through fuel analysis, a copy of all calculations and supporting documentations of TSM emission rates, using Equation 14 from §63.7530, that were done to demonstrate compliance with the TSM emission limit. Supporting documentation should include results of any fuel analyses and basis for the estimates of maximum TSM fuel input or TSM emission rates. The facility can use the results from one fuel analyses for multiple boilers, since the facility burns only one fuel type. However, the facility must calculate TSM fuel input, or mercury emission rate for each boiler.

• If, consistent with §63.7515(b), the facility is able to stack test less frequently than annually, the facility must keep a record that documents that the emissions in the previous stack tests were less than 75 percent of the applicable emission limit, and document that there were no changes in the source operations including fuel composition and operation of air pollution control equipment that would cause emissions of the pollutant to increase with the past year.

• Records of the occurrence and duration of each malfunction of the boiler, or of the associated air pollution control and monitoring equipment.

• Records of actions taken during periods of malfunction to minimize emissions in accordance with the general duty to minimize emissions in §63.7500(a)(3), including corrective actions to restore the malfunctioning boiler, air pollution control, or monitoring equipment to its normal or usual manner of operation.

• Records of the calendar date, time, occurrence, and duration of each startup and shutdown. • Records of the types and amounts of fuels used during each startup and shutdown.

If the facility elects to average emissions, the facility must keep a copy of the emissions averaging Implementation Plan, all calculations, including monthly records of heat input or steam generation, and monitoring records. If the facility elects to use efficiency credits from an energy conservation measure to demonstrate compliance, the facility must keep a copy of the Implementation Plan and copies of all data and calculations used to establish credits. §63.7560 – This section states that the records must be in a form suitable and readily available for review. The records must be retained for 5 years following the date of each occurrence, measurement, maintenance, correction action, report, or record. The records must be retained on-site initially for two years, and the records may be retained off-site for the remaining three years. §63.7565 – This section specifies that Table 10 shows which parts of the General provisions in §§63.1 through 63.15 are applicable.

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Table 10 to Subpart DDDDD of Part 63 –Applicability of General Provision to Subpart DDDDD Citation Subject Applies to subpart DDDDD §63.1 Applicability Yes §63.2 Definitions Yes. Additional terms defined in §63.7575 §63.3 Units and

Abbreviations Yes

§63.4 Prohibited Activities and Circumvention

Yes

§63.5 Preconstruction Review and Notification Requirements

Yes

§63.6(a),(b)(1)-(b)(5), (b)(7), (c)

Compliance with Standards and Maintenance Requirements

Yes

§63.6(e)(1)(i) General duty to minimize emissions.

No. See §63.7500(a)(3) for the general duty requirement.

§63.6(e)(1)(ii) Requirement to correct malfunctions as soon as practicable.

No.

§63.6(e)(3) Startup, shutdown, and malfunction plan requirements.

No.

§63.6(f)(1) Startup, shutdown, and malfunction exemptions for compliance with non-opacity emission standards.

No.

§63.6(f)(2) and (3) Compliance with non-opacity emission standards.

Yes.

§63.6(g) Use of alternative standards

Yes.

§63.6(h)(1) Startup, shutdown, and malfunction exemptions to opacity standards.

No. See §63.7500(a).

§63.6(h)(2) to (h)(9) Determining compliance with opacity emission standards

Yes.

§63.6(i) Extension of compliance

Yes. Note: Facilities may also request extensions of compliance for the installation of combined heat and power, waste heat recovery, or gas pipeline or fuel feeding infrastructure as a means of complying with this subpart.

§63.6(j) Presidential exemption. Yes. §63.7(a), (b), (c), and (d) Performance Testing

Requirements Yes.

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§63.7(e)(1) Conditions for conducting performance tests

No. Subpart DDDDD specifies conditions for conducting performance tests at 63.7520(a) to (c).

§63.7(e)(2)-(e)(9), (f), (g), and (h)

Performance Testing Requirements

Yes.

§63.8(a) and (b) Applicability and Conduct of Monitoring

Yes.

§63.8(c)(1) Operation and maintenance of CMS

Yes.

§63.8(c)(1)(i) General duty to minimize emissions and CMS operation

No. See §63.7500(a)(3).

§63.8(c)(1)(ii) Operation and maintenance of CMS

Yes

§63.8(c)(1)(iii) Startup, shutdown, and malfunction plans for CMS

No.

§63.8(c)(2) to (c)(9) Operation and maintenance of CMS

Yes

§63.8(d)(1) and (2) Monitoring Requirements, Quality Control Program

Yes

§63.8(d)(3) Written procedures for CMS

Yes, except for the last sentence, which refers to a startup, shutdown, and malfunction plan. Startup, shutdown, and malfunction plans are not required.

§63.8(e) Performance evaluation of a CMS

Yes

§63.8(f) Use of an alternative monitoring method.

Yes

§63.8(g) Reduction of monitoring data

Yes

§63.9 Notification Requirements

Yes

§63.10(a), (b)(1) Recordkeeping and Reporting Requirements

Yes

§63.10(b)(2)(i) Recordkeeping of occurrence and duration of startups or shutdowns

Yes

§63.10(b)(2)(ii) Recordkeeping of malfunctions

No. See §63.7555(d)(7) for recordkeeping of occurrence and duration and 63.7555(d)(8) for actions taken during malfunctions.

§63.10(b)(2)(iii) Maintenance records Yes §63.10(b)(2)(iv) and (v) Actions taken to

minimize emissions during startup, shutdown, or malfunction

No.

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§63.10(b)(2)(vi) Recordkeeping for CMS malfunctions

Yes

§63.10(b)(2)(vii) to (xiv) Other CMS requirements

Yes

§63.10(b)(3) Recordkeeping requirements for applicability determinations

No.

§63.10(c)(1) to (9) Recordkeeping for sources with CMS

Yes

§63.10(c)(10) and (11) Recording nature and cause of malfunctions, and corrective actions

No. See §63.7555(d)(7) for recordkeeping of occurrence and duration and 63.7555(d)(8) for actions taken during malfunctions.

§63.10(c)(12) and (13) Recordkeeping for sources with CMS

Yes.

§63.10(c)(15) Use of startup, shutdown, and malfunction plan

No.

§63.10(d)(1) and (2) General reporting requirements

Yes.

§63.10(d)(3) Reporting opacity or visible emission observation results

No.

§63.10(d)(4) Progress reports under an extension of compliance

Yes.

§63.10(d)(5) Startup, shutdown, and malfunction reports

No. See §63.7550(c)(11) for malfunction reporting requirements.

§63.10(e) Additional reporting requirements for sources with CMS

Yes.

§63.10(f) Waiver of recordkeeping or reporting requirements

Yes.

§63.11 Control Device Requirements

No.

§63.12 State Authority and Delegation

Yes.

§63.13-63.16 Addresses, Incorporation by Reference, Availability of Information, Performance Track Provisions

Yes.

§63.1(a)(5),(a)(7)-(a)(9), (b)(2), (c)(3)-(4), (d), 63.6(b)(6), (c)(3),(c)(4), (d), (e)(2), (e)(3)(ii), (h)(3), (h)(5)(iv), 63.8(a)(3), 63.9(b)(3), (h)(4), 63.10(c)

Reserved No.

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(2)-(4), (c)(9). Tables 2, 11 through 13 are not applicable to the boiler at Sierra Pacific Anderson and therefore are not included in this evaluation or the proposed Title V Permit. §63.7575 – This section contains the definitions that are applicable to this subpart. The applicable requirements have been added to the Title V permit. MACT Standards for Industrial Process Cooling Towers, Section 63.400 This regulation applies to major source cooling towers utilizing chromium compounds for water treatment. SPI, Anderson does not use chromium compounds for water treatment in its cooling water. National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines; New Source Performance Standards for Stationary Ignition Internal Combustion Engines, Subpart JJJJ §60.4230 The provisions of this subpart applies to manufacturer’s, owners, and operators of stationary spark ignition (SI) internal combustion engines (ICE). Sierra Pacific Industries operates a SI ICE as an emergency feed water pump for continuous water supply to the boiler in the event of a power failure, therefore, are subject to this subpart and conditions will be incorporated in the Title V permit which will include emission limits, testing and maintenance requirements, hours of operation limits and recordkeeping. NESHAP Standards for Reciprocating Internal Combustion Engines, Subpart ZZZZ §63.6580 This subpart establishes national emission limitation and operating limitations for hazardous air pollutants (HAP) emitted from stationary reciprocating internal combustion engines (RICE) located at major and area sources of HAP emissions. Sierra Pacific Industries, Anderson operates an Emergency SI RICE that is <500 hp but > 250 hp and is considered a Major Source of HAP, therefore, this subpart refers to the JJJJ requirements which will be incorporated in the Title V permit. SPECIFIC PERMIT ACTIONS AND MODIFICATIONS 1. Modification of Equipment List- On May 6, 2016, the District issued an Authority to Construct to install a new 468 MMBtu/hr wood fired boiler. 2. Administrative Permit Amendments- CAM Plan Update (New Boiler) On June 29, 2016, SPI submitted a Compliance Assurance Monitoring Plan (CAM Plan) for particulate matter to the District as part of a Title V Application. It was determined that a CAM Plan was not necessary for CO or NOx due to the utilization of a Continuous Emissions Monitor (CEM’s) that is challenged and tested exhaustively to assure compliance. The proposed CAM

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plan was developed using source test data from a neighboring SPI facilities. This testing indicated the minimum electrostatic precipitator power requirements needed to ensure compliance with mass emission limits. Once this data had been processed, it was extrapolated to derive the performance indicator ranges for the subject ESP. These ranges were then extrapolated to the Anderson plant operating data and an ESP 3-field average of greater than 12 kV was arrived at. Since this time, SPI Anderson has operated according to this plan and has maintained continuous compliance with the opacity limit. This CAM Plan was reviewed and found to meet all current requirements for CAM plans. RENEWAL PROCESS The Title V Operating Permit renewal application was deemed administratively complete on June 29, 2016. According to District Rule 5, the District must issue a renewed permit no later than 18 months after an application is deemed complete. A permit shield was issued to the facility making the current Title V Permit 94-TV-18d to remain in force as this renewal process becomes complete. A copy of the proposed permit will be submitted to the California Air Resources Board (CARB) for the required 30-day comment and review period. A 30-day notification of the proposed action will be published in the Redding Record Searchlight and the Anderson Valley Post in concurrence with the CARB 30-day comment period. All comments will be addressed by the District and will be attached as a document titled Compilation of Public Comments- Sierra Pacific Anderson Title V Renewal- 2019 and submitted to EPA for review. A 45-day notification of the proposed action and a copy of the proposed permit will be submitted to the Environmental Protection Agency, Region IX.

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EXPIRATION DATE: PERMIT NO: XX, XX, 2021 94-VP-18e

SHASTA COUNTY DEPARTMENT OF RESOURCE MANAGEMENT

AIR QUALITY MANAGEMENT DISTRICT SIERRA PACIFIC INDUSTRIES, ANDERSON DIVISION (Applicant) IS HEREBY GRANTED A

TITLE V OPERATING PERMIT SUBJECT TO CONDITIONS NOTED COGENERATION FACILITY WITH SAWMILL, PLANER MILL and ASSOCIATED

EQUIPMENT (Nature of Activity) AT: 19758 Riverside Ave., Anderson, CA 96007 (Assessor’s Parcel No. 050-110-038/039) DATE ISSUED: XX, XX, 2019 APPROVED: _________________________________ Air Pollution Control Officer

SIERRA PACIFIC INDUSTRIES, ANDERSON DIVISION Title V Operating Permit #94-VP-18e

Issue Date: XX, XX, 2019

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TABLE OF CONTENTS

Equipment List .........................................................................................................................................................2 A - Emission Limits and Standards .........................................................................................................................3 B - Operating Conditions .......................................................................................................................................10 C - Testing, Monitoring and Reporting Requirements ..........................................................................................13 D - Standard Conditions.........................................................................................................................................23 E - Wood Chip Loading Facility (specific conditions) ..........................................................................................29 F - Fungicide Spray Misting Unit (specific conditions) ........................................................................................29 G - Natural Gas-Fired Emergency Backup Feed Water Pump Engine…...………………………………...……32 H - 40 CFR Part 63 Subpart DDDDD, NESHAPS for Major Source Boilers (Boiler MACT) .....…………..…33 I - 40 CFR Part 98 Subpart A & C Mandatory Greenhouse Gas Reporting.........……………………………...44

EQUIPMENT LIST

Wood Fired Boiler 1 Each – 468.5 MM btu/hr Step Grate, Stoker Type, Wood Fired Boiler 2 Each – 62.5 MM btu/hr Low NOx Natural Gas Burners 1 Each – 31 Megawatt Steam Turbine 1 Each – Multicone for Control of Course Particulate Matter 1 Each – Three Field Electrostatic Precipitator for Control of Fine Particulate Matter 1 Each – SNCR Emission Control System for NOx Control 1 Each – Three Cell Water Cooling Tower 1 Each – 35’ Tall Ash Storage Silo 1 Each – 8.5’ Diameter Exhaust Stack, 85’ AGL 1 Each – 256 H.P. Natural Gas-Fired Emergency Backup Feedwater Pump Engine 1 Each – Hydraulic Truck Trailer Dumper 1 Each – 32,400 ft3 Fuel Storage Building 2 Each – Wood Chip Fuel Bins

Planer Mill Air Conveyance System 2 Each – 8’D x 27’L Cyclones with combined flow rate of 51,004 SCFM 1 Each – 7,118 ft2 MAC Pulse Jet Baghouse with 300 H.P. TCF Blower 1 Each – 35” x 45” Rotary Airlock 1 Each – Buhler en-masse, 19”– 22tph Conveyor 2 Each – Overhead Storage Bins with Enclosed Sides



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Closed Loop Spray Mist Unit 1 Each – Closed Loop Spray Mist Unit with Integrated, Negative Pressure, Mist Collection

System and 65’ Exhaust Stack

Wood Chip Loading Facility 1 Each – Wood Chip Loading Facility consisting of: One Platform Truck Dumper, One

Electrically Powered, Pneumatic, Wood Chip Conveying System with Dust Containment Hood, Blower Specifications; Rader 200 H.P., 59,000 CFM Insignificant Emissions Sources

7 Each – Non-Solvent Based De-greasing Tanks 1 Each – 10,000 Gallon Aboveground Gasoline Storage Tank 1 Each – Painting Operation 1 Each – Natural Gas-Fired Emergency Backup Feedwater Pump Engine

A. EMISSION LIMITS AND STANDARDS A1. No person shall discharge pollutants from any single source listed above into the atmosphere in amounts

greater than those designated below (unless governed by EPA New Source Performance Standard). All emissions are to be measured by methods approved for use by the Air Pollution Control Officer (APCO). Any method approved by the U.S. Environmental Protection Agency (EPA) and/or the California Air Resources Board (CARB) is approved for use by the APCO:

a) Particulate Matter (as PM10) – At all times including startup and shutdown

i. 37.3 tons/year (front-half and back-half) [Permit to Operate 10-PO-06 Condition VI.3]

Particulate Matter (as PM, PM10, PM2.5) – At all times including startup and shutdown ii. 41.0 tons/year (based on a 12-month rolling sum basis) [PSD Permit SAC 12-01 Condition X.A.1]

Particulate Matter (PM, PM10, PM2.5) – At all times excluding startup and shutdown iii. 0.02 lbs / MMBtu (3-hour block average)(front-half and back-half) iv. 9.4 lbs/hr (hourly average at 12% CO2, front-half and back-half) v. 0.019 grains/dscf (at 12% CO2)(front-half and back-half) [PSD Permit SAC 12-01 Condition X.C.1, Permit to Operate 10-PO-06 Condition VI.3]

Particulate Matter (PM, PM10, PM2.5) – during startup or shutdown vi. 8.93 lb/hr (24-hour average) the duration of operation under the startup and shutdown

limits shall not exceed 24-hours. [PSD Permit SAC 12-01 Condition X.D.5, Permit to Operate 10-PO-06 Condition VI.9.f]



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Boiler MACT (compliance either by filterable PM or by TSM testing) Reference test methods as specific in Table 5 of Part 63 Subpart DDDDD. Collect a minimum of 2 dscm per run. vii. Filterable PM (Boiler MACT):

0.03 lb/MMBtu of heat input; or alternative output based limit of 0.035 lb/MMBtu (steam output); or 0.42 lb/MMBtu (per MWH).

viii. As an alternative to Filterable PM, the Permitee may use Total Selected Metals (TSM) limits not to exceed: 2.6E-05 lb/MMBtu of heat input; or alternative output based limit of 2.7E-05 lb/MMBtu (steam output); or 3.7E-04 lb/MWH

[40 CFR Part 63, Subpart DDDDD; §63.7500(a)(1); and, Table 1 to Subpart DDDDD of Part 63]

b.) Oxides of Nitrogen (NOx)

Oxides of Nitrogen (NOx) – At all times including startup and shutdown i. 0.12 lbs/MMBtu (based on a 12-month rolling average of 3-hour block averages) ii. 1,287 lbs/day iii. 242 tons/year (based on a 12-month rolling sum basis) iv. 20 ppmv ammonia slip (12% CO2; dry basis)

[Permit to Operate #10-PO-06 Condition VI.4]

Oxides of Nitrogen (NOx) – during startup or shutdown. The duration of operation under the startup and shutdown limits shall not exceed 24-hours. v. 70.2 lb/hour (8-hour average)

[PSD Permit SAC 12-01 Condition X.D.5] Oxides of Nitrogen (NOx) – At all times excluding startup or shutdown vi. 70.2 lb/hour (3-hour average) vii. 0.13 lbs/MMBtu (12-month rolling basis) viii. 0.15 lbs/MMBtu (3-hr-block average)

[PSD Permit SAC 12-01 Condition X.C.1]



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c) Carbon Monoxide (CO) Carbon Monoxide (CO) – At all times including startup and shutdown

i. 432 lbs/hr (hourly average)

[PSD Permit SAC 12-01 Condition X.C.1] ii. 472 tons/year (based on a 12-month rolling sum basis) [PSD Permit SAC 12-01 Condition X.A.1]

iii. 2,585 lbs/day (on a 30-day rolling average)

[Permit to Operate 10-PO-06 Condition VI.5]

Carbon Monoxide (CO) – during startup or shutdown. The duration of operation under the startup and shutdown limits shall not exceed 24-hours. iv. 108 lbs/hour (8-hour average) [PSD Permit SAC 12-01 Condition X.D.5] Carbon Monoxide (CO) – except during periods of startup and shutdown v. 107.7 lbs/hr (on a 3-hour block average) vi. 0.23 lbs/MMBtu (3-hr block average) [PSD Permit SAC 12-01 Condition X.C.1]

vii. 390 ppmv dry basis corrected to three-percent (3%) O2, 30-day rolling average

[40 CFR Part 63, Subpart DDDDD §63.7500(a)(1); and Table 1 to Subpart DDDDD of Part 63]

d) Oxides of Sulfur (SOx)

i. 0.005 lbs/MMBtu ii. 2.34 lbs/hr iii. 9.32 tons/year

e) Reactive Organic Compounds / Volatile Organic Compounds (ROC/VOC)

i. 0.017 lbs/MMBtu ii. 7.96 lbs/hr iii. 31.7 tons/yr

f.) Hydrogen Chloride (HCL) – except during periods of startup and shutdown [40 CFR Part 63,

Subpart DDDDD: §63.7500(a)(1); and, Table 2 to Subpart DDDDD of Part 63] Performance i. 0.022 lbs/MMBtu of heat input; or may use the alternative output-based limits ii. 0.025 lbs/MMBtu of steam output; or iii. 0.28 lbs/MWH



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g.) Mercury (Hg) - except during periods of startup and shutdown [40 CFR Part 63, Subpart DDDDD: §63.7500(a)(1); and, Table 2 to Subpart DDDDD of Part 63] Performance i. 0.0000008 lbs/MMBtu of heat input; or may use the alternative output-based limits ii. 0.00000087 lbs/hr of steam output; or iii. 0.000011 lbs/MWH

h.) Stack Opacity1

Stack Opacity – except during periods of startup, shutdown, or malfunction

i. Stack Opacity shall be less than or equal to twenty percent (20%) per six (6) minute average except for one 6-minute period per hour of not more than twenty-seven percent (27%) as determined by a continuous opacity monitor operating in accordance with 40 CFR Part 60 Appendix B Performance Specification 1.

[PSD Permit SAC 12-01 Condition X.C.4, Permit to Operate 10-PO-06 Condition VI.5]

ii. MACT – 10% Opacity (daily block average) [40 CFR Part 63, Subpart DDDDD; Table 1] Stack Opacity – At all times including startup and shutdown iii. Less than Ringelmann #2 and/or forty percent (40%) equivalent opacity for a period or

periods aggregating more than three (3) minutes in any one (1) hour. [PSD Permit SAC 12-01 Condition X.C.4]

i.) The SNCR system for the control of NOx in regards to the boiler unit shall be in operation at all

times that the boiler unit exceeds the low SNCR activation temperature.

Boiler MACT (compliance by CEMS only) Reference test methods as specified in Table 5 of Part 63 Subpart DDDDD. 1 hour minimum sampling time. The CEMS unit must operate during startup and shutdown periods. Time, date and duration of each startup and shutdown event must be recorded. Verifiable records shall include calculations of NOx, CO, PM, PM10, PM2.5, and emissions in lb/hr and lb/MMBtu during each startup and shutdown event based on CEMS and fuel usage data. [40 CFR Part 63, Subpart DDDDD: §63.7500(a)(1); and, Table 2 to Subpart DDDDD of Part 63, PSD Permit SAC 12-01 Condition X.D.6-8 X.F.14]



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Definitions: i.) Normal operating temperature for the boiler unit shall be defined as the normal operating

temperature specified by the unit manufacturer. [PSD Permit SAC 12-01 Condition X.D.2]

ii.) Startup shall be defined as the period beginning with the boiler unit not in operation and

concluding when the boiler unit has reached a normal operating temperature. [PSD Permit SAC 12-01 Condition X.D.3]

iii.) Shutdown shall be defined as the period beginning with curtailment of fuel feed and

concluding when the recorded superheater outlet temperature reaches 150ºF and remains so for at least one hour.

[PSD Permit SAC 12-01 Condition X.D.4]

iv.) Low SNCR activation temperature shall be defined as the lowest operating temperature for

the boiler unit at which the SNCR system is recommended for operation to reduce NOx emissions as defined by the SNCR manufacturer. This temperature value shall be included in the operation and maintenance plan required by Condition III.C of the PSD permit and Condition B1.

[PSD Permit SAC 12-01 Condition X.F.1]

Footnotes: 1 This requirement does not apply to smoke emissions from burners used to produce energy and fired by forestry and

agricultural residues with supplementary fuels when the emission result from startup or shutdown of the combustion process or from the malfunction of emission control equipment. However, this exemption does not apply to emissions which exceed a period or periods of time aggregating more than 30 minutes in any 24-hour period, or which result from the failure to operate and maintain in good working order any emission control equipment. Applies only to District permit conditions.

[SCAQMD Rule 3:2, Specific Air Contaminants, 54 Federal Register (FR) 14650, 4/12/89]

A2. A person shall not discharge more than forty (40) pounds of photochemically reactive solvents into the

atmosphere in any one day from any article, machine, equipment, or other contrivance used for employing, applying, evaporating, or drying any photochemically reactive solvent, as defined in District Rule 1:2, or material containing such solvent, unless all photochemically reactive solvents discharged from such article, machine, equipment, or other contrivance have been reduced either by at least 85 percent overall or to not more than forty (40) pounds in any one day. The provisions of this condition shall not apply to:

a. The spraying or other employment of insecticides, pesticides, or herbicides.

b. The employment, application, evaporation, or drying of saturated halogenated hydrocarbons or

perchloroethylene.

c. The employment or application of polyester resins or acetone used in a fiberglass reinforced plastics operation.



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Whenever any organic solvent or any constituent of an organic solvent may be classified from its chemical structure into more than one of the above groups of organic compounds, it shall be considered as a member of the most reactive chemical groups, i.e., the groups having the least allowable percent of the total of solvents. No person shall discharge from any device, contrivance, or machine more than forty (40) pounds per day of any photochemically reactive substance other than those described above unless such discharge is controlled to reduce emissions by eighty-five percent (85%).

[SCAQMD Rule 3:4, Industrial Use of Organic Solvents, 49 FR 47491, 10/3/84]

A3. With respect to stack opacity, the pertinent provisions and sections of the Code of Federal Regulations

(CFR) New Source Performance Standards (NSPS) and the California Health and Safety Code (CH&SC) 41701 shall apply at all times. The provisions of 40 CFR Part 60 Subpart Db limits stack opacity to less than or equal to twenty percent (20%) per six (6) minute average except for one (1) six (6) minute period per hour of not more than twenty-seven percent (27%), as determined by a continuous opacity monitor operating in accordance with 40 CFR Part 60 Appendix B Performance Specification 1. These opacity limits shall apply at all times, except during periods of startup, shutdown, or malfunction. The CH&SC Section 41701 limits a stack opacity to as dark or darker in shade of less than the equivalent No.2 on the Ringelmann Chart, as stated by the United States Bureau of Mines, for a period or periods aggregating more than three minutes in any one hour, except for periods of time resulting from startup, shutdown of the combustion process or from the malfunction of emission control equipment. In addition, emissions during a period or periods of time aggregating less than thirty (30) minutes in an twenty-four (24) hour period as allowed by the CH&SC Section 41704(n).

[District Permit 10-PO-06, Condition VI.8]

A4. Best available control technology (BACT) for the wood-fired boiler shall be defined as:

Particulate Matter (as PM10) a.) Electrostatic precipitator b.) Multicone collector in-line with ESP; closed system c.) Proper combustion practices and combustion controls d.) Proper ash handling practices

Oxides of Nitrogen (NOx)

a.) SNCR (ammonia injection) b.) Proper combustion practices c.) Proper combustion controls

Carbon Monoxide (CO) and Oxides of Sulfur (SOx) and Reactive Organic Compounds / Volatile Organic Compounds (ROC/VOC)

a.) Proper combustion practices b.) Proper combustion controls c.) Proper fuel management practices

[District Permit 10-PO-06, Condition VI.2]



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A5. Fugitive emissions, including but not limited to any of the following, shall be controlled at all times such that a public nuisance is not created at any point beyond the plant property line:

a. Dust from unpaved roads or any other non-vegetation-covered area; b. Fugitive sawdust from fuel-handling devices and/or storage areas;

c. Char and/or bottom ash which is processed by the char handling system or is removed from the wood-fired boiler by other means. Such ash shall be stored in containers in a wet condition and be disposed of, or reused, in such a manner so as to not create a public nuisance. Ash shall be transported in a closed or wet condition at all times to prevent a public nuisance in conformance with District rules governing fugitive, indirect, or non-traditional sources. It shall be the responsibility of the plant owner/operator to insure that any and all contract or company carriers adhere to this condition;

d. Accumulation of sawdust or ash on outside surfaces, including but not limited to the main

building, boilers, electrostatic precipitator, support pads, road areas. Surfaces shall be cleaned on a regular basis to prevent the build-up of ash and/or fugitive dust.

[District Permit 10-PO-06, Condition II.2] A6. Visible emissions from the cyclone or baghouse blower discharge shall not exceed 40 percent opacity

for more than three (3) minutes out of any one sixty (60) minute period.

[District Permit 87-PO-17f, Condition 16, District Permit 03-PO-09, Condition 15] A7. The emission of total particulate matter from the air conveyance blower discharge shall not exceed 0.15

grains/dscf or six (6) pounds per hour.

[District Permit 87-PO-17f, Condition 17]

A8. The emission of particulate matter less than or equal to10 microns in diameter from the air conveyance blower discharge shall not exceed 0.05 grains/dscf.


A9. The operation schedule allowed for this facility shall be 8,760 hours per year. [District Permit 10-PO-06, Condition II.3]

A10. Permittee shall not discharge or cause the discharge into the atmosphere from the following unit:

Cooling Tower: a) PM/PM10 .272 lbs/hr (hourly average) b) Drift Rate shall not exceed 0.0005%

[PSD Permit SAC 12-01 Condition X.E.1]



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A11. The Permittee shall comply with the following:

a) Perform weekly tests of cooling tower blow-down water quality using an EPA-approved method. The operator shall maintain a log that contains the date and result of each blow-down water quality test, the water circulation rate at the time of the test, and the resulting mass emission rate. This log shall be maintained on site for a minimum of five (5) years and shall be provided to EPA and District personnel upon request.

b) Calculate PM, PM10, and PM2.5 emission rate using an EPA-approved calculation based on the

total dissolved solids (TDS) and water circulation rate. c) Conduct all required cooling tower water quality tests in accordance with an EPA-approved test

and emissions calculation protocol. Thirty (30) days prior to the first test, the operator shall provide a written test and emissions calculation protocol for EPA review and approval, with a copy to the District as specified in Condition C12.

d) Establish a maintenance procedure that states how much and what procedures will be used to ensure the integrity of the drift eliminators. This procedure is to be kept onsite and made available to EPA and District personnel upon request. The Permittee shall promptly report any deviations from this procedure.

[PSD Permit SAC 12-01 Condition X.I.3]

A12. Upon the date of Commercial Operation of the new wood-fired boiler, this facility shall be subject

to and comply with 40 CFR Part 63 Subpart DDDDD, National Emission Standards for Hazardous Air Pollutants for Industrial, Commercial, and Institutional Boilers, Major Sources. See Section H, below.

B. OPERATING CONDITIONS B1. The Permittee shall develop and implement an operation and maintenance plan for the Stoker Boiler,

Cooling Tower, and Emergency Engine. At a minimum, the plan shall identify measures for assessing the performance of the units, the acceptable range of performance measures for achieving the desired output, the methods for monitoring the performance measures, and the routine procedures for maintaining each unit in good operating condition.

[PSD Permit SAC 12-01 Condition III.C.] B2. Fuels utilized in the operation of this facility shall be limited to the following fuel source:

a) Sawmill residuals including hog fuel, shavings, sawdust, trimmings and bark;

b) Non-merchantable forest biomass consisting of byproducts and residuals of forest management activities identified to follow all of the following practices:

a. Biomass fuel procured from private and public lands that have been harvested in accordance with the Z’berg-Nejedly Forest Practice Act of 1973, a State Forest Practice Act, or a Management Plan consistent with the National Environmental Policy Act.

b. Harvested for the purposed of forest fire fuel reduction or forest stand improvement.



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c. Forest residues including treetops, non-merchantable sections of the stem, branches, bark, left on the ground after logging or accumulating as a result of a storm, fire, de-limbing, or other similar disturbance.

c) Agricultural tree orchard removal and prunings;

d) Urban biomass wood-fuel1 (as approved by the APCO) up to 10% by weight of total fuel input or not to exceed 21,900 bone dry tons per year;

e) Any agricultural crop derived woody fuel (non-tree) up to 5% of total fuel input;

f) Pipeline natural gas (annual limit up to 62,500 MMBtu). Annual capacity factor of 5.7% per EIR MM 3.2.3 which specifies 500 hrs/year, calculated on a 12-month rolling average and in accordance with 40 CFR Part 60 Subpart Db. The heat input from pipeline natural gas shall not exceed 10% of the total heat input on a 12-month rolling basis. Pipeline natural gas shall be used during start-up, shutdown, and for flame stabilization in order to maintain compliance with emission limits.

Footnote: 1 Untreated wood pallets, crates, dunnage, untreated manufacturing and construction wood debris from urban areas.

[District Permit #10-PO-06, Condition III.1, PSD Permit SAC 12-01 Condition X.G.2]

B3. Wood fuel shall not be charged to the boiler at a rate which causes the steam production rate to exceed a

daily twenty-four (24) hour block average of 250,000 pounds per hour averaged over the corresponding calendar month period. Daily steam generation data shall be made available to the District upon request and be maintained for a minimum of five (5) years.

[District Permit 10-PO-06, Condition III.2, PSD Permit SAC 12-01 Condition X.C.3 ]

B4. Combustion of wet fuel, i.e., fuel with moisture content greater than or equal to 55 percent, shall not be considered as an affirmative defense to an excess emission condition for the wood-fired boiler. Use of such fuels is a foreseeable occurrence, and as such, compliance with all permit limits and District regulations shall be required at all times unless the APCO has determined that the cause of the wet fuel condition is due to an unavoidable or emergency situation.

[District Permit 10-PO-06, Condition V.5]

B5. The following air pollution control equipment shall be operated in accordance with manufacturers

recommendations when the combustion process is occurring. Equipment e.-f. shall be operated and maintained in a manner consistent with good engineering practices for its full utilization:

a. Multicone collector; (Shall be in operation at all times during the combustion process) b. Electrostatic precipitator; (Shall be in operation at all times during the combustion process) c. Combustion controls; d. The Selective Non-Catalytic NOx reduction injection system shall be utilized as necessary

to meet the emission limit for Oxides of Nitrogen as specified in Condition A.1.b. (Shall



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be in operation at all times that the wood-fired boiler exceeds the low SNCR activation temperature)

e. Stoker Boiler; f. Cooling Tower; g. Emergency Engine

[District Permit 10-PO-06, Condition VI.1, PSD Permit SAC 12-01 Condition III.B, X.F.2-3] B6. Under no circumstances shall the Permittee be allowed to emit quantities of pollutants from the wood-

fired boiler in excess of the limits specified in Section A. If continuous monitoring or testing pursuant to Section A shows an increase in emissions above these limits, the Permittee will take immediate action to bring the emissions to within the specified limits. Immediate Action, for use in this permit shall be defined as within four (4) hours of the occurrence which leads to the emission exceedance.

[District Permit 10-PO-06, Condition II.1]

B7. The cyclones, baghouse and connecting blowpipe system in the air conveyance system shall be maintained

in a leak-free condition. Upon identification of a leak, the permittee shall take immediate action (within 4 hours) to correct the leak. Spare bags for the baghouse shall be kept on-site for immediate replacement of leaking or torn bags. The owner/operator shall take daily readings of the baghouse pressure drop to ensure continuous operation within manufacturer specifications. These records shall be maintained and kept on site for a minimum of five years.

[District Permit 87-PO-17f, Conditions 13, 14, 15]

B8. The air conveyance system shall not operate more than 22 hours per day, six (6) days per week.

[District Permit 87-PO-17f, Condition 19] B9. The wood waste collection and storage bins shall be maintained using best management practices to

prevent leaks and clean any spillage that might occur from loading operations. The bins shall be emptied on a schedule which insures that the cyclone-separator system shall not become plugged. The sides of the storage bins shall remain enclosed to mitigate the fugitive emissions from the unloading process. Upon identification of a leak, the permittee shall take immediate action (within 4 hours) to correct the leak. In no event shall spilled dust or ash be allowed to exist beyond 24 hours of the upset.

[District Permit 87-PO-17f, Condition 20, PSD Permit SAC 12-01 Condition X.C.6.e]

B10. Fugitive dust generated from access and on-site roads shall be controlled by application of water, dust

palliative, chip-sealing, or paving so as to prevent a public nuisance or violation of any applicable ambient air quality standard.

[District Permit 87-PO-17f, Condition 23, District Permit 03-PO-09, Condition 17]



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B11. All other surfaces shall be cleaned or washed sufficiently to prevent significant wind-blown dust from leaving the property boundaries as necessary to prevent a public nuisance or opacity violation of any applicable ambient air quality standard.


B12. All truck loading and unloading conducted at the facility, shall be done in a manner that minimizes spillage, and fugitive emissions as necessary to prevent a public nuisance or opacity violation of any applicable ambient air quality standard.


B13. Fugitive dust from storage piles, processing area, and disturbed areas shall be controlled by periodic cleanup and/or use of sprinklers, tarps, or dust palliative agents as necessary to prevent a public nuisance or opacity violation of any applicable ambient air quality standard. During periods of high winds, Sierra Pacific Industries, Anderson Division, shall take immediate action to correct fugitive dust emissions from the chip processing area.

[District Permit 87-PO-17f, Condition 25, District Permit 03-PO-09, Condition 20] C. TESTING, MONITORING, AND REPORTING REQUIREMENTS C1. The project owner/operator shall maintain, calibrate, and operate the following continuous emission

monitors (CEMS) and process monitors for the wood-fired boiler at all times, including periods of startup and shutdown when the combustion process is occurring:

a. Stack gas opacity monitor (COMS); b. Stack gas carbon monoxide monitor (CO);

c. Stack gas oxides of nitrogen and oxygen monitor (NOx, O2); d. Stack gas carbon dioxide monitor (CO2); e. Stack gas volumetric flow rate monitor; and f. Steam production rate monitor.

[District Permit 10-PO-06, Condition, VII.1] C2. The facility owner/operator shall operate and maintain the CEMs and COMs at all times when the

combustion process is occurring. Installation, maintenance, and calibration of these devices shall be performed as stated in 40 CFR Part 60 Subpart A, Appendix B, Specifications 1, 2, and 4 and Appendix F. Records regarding equipment maintenance and calibration performed shall be completed by the facility owner/operator. These records shall be maintained and kept on file for five (5) years, on an on-going schedule, and made available to District staff upon request. Mass emission rate, in lbs per MMBtu heat input, lbs per hr, and lbs per day shall be recorded for NOx and CO and shall be calculated per methods as stated in 40 CFR Part 60 Appendix A.

[District Permit 10-PO-06, Condition VII.2]



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C3. The project Owner/operator shall monitor the following combustion and control parameters for the wood-fired boiler on a continuous basis unless otherwise noted:

a. Combustion temperature (at the superheater tube area); b. Temperature at air heater outlet; c. Steam production rate; d. Ammonia injection rate (on a gallons per day basis); e. Fuel moisture content (intermittent basis).

[District Permit 10-PO-06, Condition VII.2(a-e)]

C4. The facility owner or operator shall conduct an initial performance test on the ESP stack no later than 45

days after the initial start-up date. The initial source test shall test the emission of particulate matter less than ten microns (PM10), oxides of Nitrogen (NOx); reactive organic compounds / volatile organic compounds (ROC/VOC), oxides of sulfur (SOx/SO2), carbon dioxide (CO2), carbon monoxide (CO), ammonia (NH3) slip, and opacity. The initial performance test shall be performed in accordance with procedures stated in 40 CFR part 40 – Subpart A, Subpart Db, and appendices A, B, and F.

Periodic emission testing shall be required pursuant to District Rule 2:11.a.3.(f) except as noted below.

Pollutant Emission Rate Test Schedule/Frequency < 25 tons/year voluntary – or at the request of the SCAQMD 25 tons/yr to <50 tons/year once every three (3) years 50 tons/year to <100 tons/year once every two (2) years 100 tons/year or greater once every year

Stack gas ammonia emissions (ammonia slip) shall be tested annually as per source test method BAAQMD Method ST-1B. Stack gas particulate matter emissions shall be tested annually per source test methods EPA Method 202 or ARB Method 5. The following emission tests using the specific test methods shall be used for emission testing:

PM10 ARB Method 5; or EPA Method 202 (front and back half) annually with a two-hour test run period for each test for PM10 and PM2.5 emissions. In lieu of Method 5, the Permittee may use Other Test Method 201A.

NOx (as NO2) ARB Method 100; EPA Method 7E, EPA Method 19 CO ARB Method 100; EPA Method 10 SOx (as SO2) ARB Method 100; EPA Method 6c ROC/VOC ARB Method 100; EPA Method 18 / 25A (as methane) NH3 (slip) BAAQMD Method ST-1B Boiler MACT Emission testing, as applicable: PM Method 1-4 and 5 (This performance test may be done concurrently with

EPA Method 29 for Pb emissions) Filterable PM EPA Method 5 HCL Method 26; or Method 26A



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Hg Method 29, or Method 30A or 30B, or ASTM D6784 Pb Method 1-4 and 19 CO2 Method 3A

The emission testing shall be conducted by an independent testing firm in strict compliance with the specific test methods. Any deviation from the test methods must receive prior approval from the District.

The facility owner/operator shall provide the APCO at least thirty (30) days prior notice of a compliance test, to afford the APCO the opportunity to have an observer present. Results of all stack emission tests shall be forwarded to the District within 10 days of SPI’s receipt. Additionally, the Permittee shall furnish the EPA with a written report of the results of performance tests as identified in this permit within 60 days of completion. Relative Accuracy Test Audits (RATA) on the CEMs shall be performed in accordance with the requirements of 40 CFR Part 60, Appendix B, Specifications 2, 3 & 4, and shall perform quarterly Cylinder Gas Audits (CGA’s) as described in 40 CFR Appendix F – (Quality Assurance Procedures);Each CEM shall be audited at least once each calendar quarter. Successive quarterly audits shall occur no closer than two (2) months. All performance tests shall be conducted at not less than ninety percent (90%) of 250,000 lbs/hr steam production rate as an hourly average.

The CEMS shall be audited quarterly and tested annually to demonstrate that it meets the specifications in C.2. The permittee shall perform a full stack traverse during the initial run of annual relative accuracy test auditing of the CEMS, with testing points selected according to 40 CFR Part 60 Appendix A, Method 1.

[District Permit 10-PO-06, Condition VIII.1-8, Permit SAC 12-01 Condition X.H.6, X.I.e-h, X.H.11]

C5. Monthly emission reports for the wood-fired boiler shall be required to be submitted by the 15th of the

month following data recording and shall include:

a. Daily average of CO and NOx emissions expressed in ppm (corrected to 12% CO2), and lb./hour dry basis. All time periods when the boiler is not in operation shall be excluded from the averages. The total monthly hours of operation and the monthly average of CO and NOx emissions expressed in lbs/hour shall also be included;

b. Notification of all periods six (6) minutes and longer in duration when opacity exceeds 20% and the reason for the excursion;

c. Notification of all three (3) hour and twenty-four (24) hour averaged periods exceeding the permit limitations for oxides of nitrogen and the reason for the excursion;

d. Notification of all three (3) hour and twenty-four (24) hour averaged periods exceeding the permit limitation for carbon monoxide and the reason for the excursion;

e. Notification of all periods the continuous monitors were not functioning and the reasons for the same;

f. If no permit limitations were exceeded, the report must so state.

[District Permit 10-PO-06, Condition VII.3]



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C6. The Permittee shall calculate and record on a daily basis the average boiler heat input in MMBtu/hr (24-hr daily block average). The calculation shall be based on manufacturer ratio of maximum design heat rating to design steam (maximum design (MMBtu/hr) divided by design steam (lb/hr)) multiplied by the total steam generated each day. The heat input, as determined from this, shall not exceed 468 MMBtu/hr on a monthly basis.

[Permit SAC 12-01 Condition X.J.2] C7. By the last day of each month, the Permittee shall calculate and record the 12-month rolling sum of CO,

NOx, PM, PM10, and PM2.5 emissions in tpy for the boiler unit for the previous 12 months in accordance with Condition A.1.

a. CO and NOx emissions calculations shall be based on emissions data acquired by the CO and NOx

CEMS. b. PM, PM10, and PM2.5, shall be based on emission factors from the most recent performance test. [Permit SAC 12-01 Condition X.J.3] C8. By the last day of each month, the Permittee shall calculate and record the 12-month rolling average of

CO2e in lbs CO2e/lbs steam produced for the boiler unit for the previous 12 months in accordance with Condition A1. a. CO2 emissions calculations shall be based on emissions data acquired by the CO2 CEMS, and the

applicable calculation methodology contained in 40 CFR 98.33(a)(4) in effect on January 1, 2014. b. CH4 and N2O emissions calculations shall be based on the following:

(1) The heat input of the applicable emission unit. (2) The default CH4 and N2O emission factors in Table C-2 of 40 CFR Part 98, Subpart C as published on November 29, 2013 (78 FR 71952) and effective on January 1, 2014, and provided in the following table.

Fuel Type GHG Pollutant Emission Factor (kg/MMBtu)

Wood and Wood Residuals

CH4 0.0072 N2O 0.0036

Natural Gas CH4 0.001 N2O 0.0001

(3) The applicable calculation methodology contained in 40 CFR 98.33 in effect on January 1, 2014.

c. The Permittee shall calculate the CO2e emissions based on the procedures and Global Warming

Potentials (GWP) contained in Greenhouse Gas Regulations, 40 CFR Part 98, Subpart A, Table A-1, as published on November 29, 2013 (78 FR 71948) and effective on January 1, 2014, and provided in the following table.



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GHG Pollutant GWP CO2 1 CH4 25 N2O 298

Sulfur hexafluoride (SF6) 22,800

d. The total CO2e shall be based on the sum of the CO2e for CH4, N2O and CO2. e. Steam production shall be based on daily records of the hourly steam production rate output monitoring

device.

[Permit SAC 12-01 Condition X.J.4] C9. Emissions exceeding any of the limits established in this permit shall be immediately reported to the

APCO as follows:

a. For scheduled maintenance of a permitted emission source, notice shall be provided to the APCO at least twenty-four (24) hours prior to shutdown, whether or not an emission exceedance is expected.

b. The emission source owner/operator shall notify the APCO within four (4) hours of the occurrence

of any excess emission and provide information on the time, specific location, equipment involved, duration, cause, and extent of the excess emission.

In addition, the Permittee shall notify EPA at [email protected] within two (2) working days following the discovery of any failure of air pollution control equipment or process equipment, or failure of a process to operate in a normal manner, which results in the increase in emissions above the allowable limits stated in Section A.1.a-e of this permit.

c. Corrective action shall be taken immediately by the owner/operator of the emission source to

correct the conditions causing excessive emissions and to reduce the frequency of the occurrence of such conditions. In no event shall equipment be operated in a manner that creates excessive emissions beyond twenty-four (24) hours, except for malfunctioning continuous monitoring equipment, for which the period shall be ninety-six hours.

In addition, the Permittee shall provide an additional notification to EPA in writing or electronic

mail within fifteen (15) days of any such failure described under condition C6.b. This notification shall include a description of the malfunctioning equipment or abnormal operation, the date of the initial malfunction, the period of time over which emissions were increased due to the failure, the cause of the failure, the estimated resultant emissions in excess of those allowed in Section A.1.a-e, and the methods utilized to mitigate emissions and restore normal operations.

d. An emergency constitutes an affirmative defense to any action brought for non-compliance with

technology-based emission limits if:

1) The emission source operator can identify the cause(s) of the emergency 2) The permitted facility was at the time being properly operated

mailto:[email protected]



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3) During the period of the emergency, the emission source operator took all reasonable steps to minimize levels of excess emission, and

4) The emission source operator submitted notice of the emergency to the APCO in accordance with this condition.

(For the purposes of this condition, emergency shall be as defined in Title 40 of the Code of Federal Regulations (CFR), Part 70, Section 70.6(g); i.e. "any situation arising from sudden and reasonably unforeseeable events beyond the control of the source, including acts of God, which situation requires immediate corrective action to restore normal operation, and that causes the source to exceed a technology-based emission limitation under the permit, due to unavoidable increases in emissions attributable to the emergency.")

Within two (2) working days of the emergency event, the permittee shall provide the District with a description of the emergency and any mitigating or corrective actions taken. Within two (2) weeks of an emergency event, the responsible official shall submit to the District a properly signed contemporaneous log or other relevant evidence that contains all the information for what constitutes an emergency (as described above in d.1-4 of this condition).

In any enforcement proceeding, the permittee has the burden of proof for establishing that an emergency occurred. e. An excess emission occurrence may not avoid enforcement action by the APCO if the occurrence

is caused by improperly designed equipment, lack of preventative maintenance, careless or improper operation, or operator error.

f. Nothing expressed in this Condition shall be construed to limit enforcement authorities under the Federal Clean Air Act.

g. Excess emissions during start-up and shut-down shall be considered a violation (except as allowed by Title 40 of the Code of Federal Regulations, Part 60, Section 60.8(c)) if the owner or operator cannot demonstrate that the excess emissions are unavoidable when requested to do so by the APCO. The APCO may specify for a particular source the amount, time, duration, and under what circumstances excess emissions are allowed during start-up or shut-down. The owner or operator shall, to the extent practicable, operate the emission source and any associated air pollution control equipment or monitoring equipment in a manner consistent with best practicable air pollution control practices to minimize emissions during start-up and shut-down.

[District Permit 10-PO-06 VII.4, SCAQMD Rule 3:10, Excess Emissions; SCAQMD Rule 5, PSD Permit SAC 12-01 Condition IV.A, B, & C]



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C10. The permittee shall report any deviation1 from permit requirements in this Title V Operating Permit, other than emergency events, to the APCO via phone or Fax within ninety-six (96) hours of the occurrence. A report using District approved forms, for each deviation from the permit requirement shall be prepared by the permittee if requested by the APCO within two (2) weeks after the initial detection of the deviation. Unless requested earlier by the APCO, these reports shall be submitted to the APCO as part of the permittee's semiannual monitoring report.

Footnote: 1 A deviation is a departure from a federally enforceable permit term or condition determined at permit issuance that establishes an

emissions limit. [40 CFR Part 70.2, Definitions, Emissions allowable under the permit, SCAQMD Rule 5]

C11. The permittee shall submit a written monitoring report to the APCO every six months. The reporting

periods shall be January 1 through June 30 and July 1 through December 31. These reports shall be submitted within forty-five (45) days of the end of each reporting period. When no deviations have occurred for the reporting period, such information shall be stated in the report. The monitoring report shall include at a minimum:

a. A report for each deviation from a permit requirement that occurred during the reporting period,

including emergency events. All reports of a deviation from permit requirements shall include the probable cause of the deviation and any preventative or corrective action taken. The permittee shall use District approved forms to report each deviation from permit requirements.

b. Results from any emission testing done during the reporting period if not provided earlier to the District immediately following the test.

c. A Certification Report form (Forms 5-K1-K2), which includes a written statement from the responsible official that certifies the truth, accuracy, and completeness of the report. All compliance reports and other documents required to be submitted to the District by the responsible official shall state that “Based upon information and belief formed after reasonable inquiry, the statements and information in the documents are true, accurate and complete.”

[SCAQMD Rule 5]



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C12. The permittee shall submit compliance certification reports to the U.S. EPA and the APCO every twelve (12) calendar months. The report shall be submitted within forty-five (45) days of the end of the reporting period. The permittee shall use District approved forms for the compliance certification and shall also include a written statement from the responsible official which certifies the truth, accuracy, and completeness of the report.

Compliance certifications shall be sent to EPA at the following address:

Enforcement Division Air, Waste, and Toxics Branch U.S. EPA Region IX (ENF-2) 75 Hawthorne Street San Francisco, CA 94105 Compliance certifications shall be sent to the APCO at the following address: Air Pollution Control Officer

Shasta County Air Quality Management District 1855 Placer Street Suite 101 Redding, CA 96001 [SCAQMD Rule 5]

C13. Records of all monitoring equipment maintenance and support information shall include the following:

a. Date, place, and time of measurement or monitoring equipment maintenance activity; b. Operating conditions at the time of measurement or monitoring equipment maintenance activity; c. Date, place, name of company or entity that performed the measurement or monitoring equipment

maintenance activity and the methods used; and d. Results of the measurement or monitoring equipment maintenance.

All monitoring and support information shall be retained for at least five (5) years from date of collection, measurement, report, or application.

[SCAQMD Rule 5]

C14. For the Boiler Unit, the Permittee shall maintain the following records:

a. The total monthly hours of operation;

b. 3-hour averages of CO and NOx emissions in units of lbs/MMBtu and lbs/hour dry basis. All time periods when the boiler is not in operation shall be excluded from the averages. The monthly average of CO and NOx emissions expressed in lbs/hour shall also be included;

c. 3-hour average calculations of PM10 emissions in units of lbs/MMBtu and lbs/hour dry basis using the most recent annual PM10 source test;



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d. Notification of all periods the continuous monitors were not functioning and the reasons for the same;

e. Steam production rate averaged over a daily (24-hour) period. f. The occurrence and duration of any startup, shutdown, or malfunction, performance testing, evaluations, calibrations, checks, adjustments maintenance, duration of any periods during which a CEMS or COMS is inoperative, and corresponding emission measurements. g. Applicable time and date of each period during which the CEMS or COMS was inoperative (monitor downtime), except for zero and span checks, and the nature of CEMS or COMS repairs or adjustments;

h. A statement in the report of a negative declaration; that is, a statement when no excess emissions occurred or when the CEMS or COMS has not been inoperative, repaired, or adjusted;

i. Any failure to conduct any required source testing, monitoring, or other compliance activities; and

j. Any violation of limitations on operation, including but not limited to restrictions on hours of operation. [PSD Permit SAC 12-01 Condition X.J.5, X.J.6.a, X.J.7.b-e]

C15. The owner or operator shall provide written notification to the District and EPA Administrator of any

physical or operational change to the facility that may increase the emission rate of any air pollutant to which a standard applies, unless that change is specifically exempted under an applicable subpart or in 40 CFR Part 60.14(e). This notice shall be post marked sixty (60) days or as soon as practical before the change is commenced and shall include information describing the precise nature of the change, present and proposed emission control systems, productive capacity of the facility before and after the change, and the expected completion date of the change. The District may request additional information subsequent to this notice.

[40 CFR Part 60.7(a) 4] C16. The Permittee shall maintain a file of all measurements, including continuous monitoring system,

monitoring device, and performance testing measurements, all continuous monitoring system performance evaluations, all continuous monitoring system or monitoring device calibration checks, adjustments and maintenance performed on these systems or devices; and all other information required by this part recorded in a permanent form suitable for inspection. The file shall be retained for at least five (5) years following the date of such measurements, maintenance, reports and records.

[40 CFR Part 60.7(f), District Rule 5] C17. The permittee shall provide the APCO (and the EPA Administrator when demonstrating compliance with

a specific standard under 40 CFR Part 60 & Part 63 DDDDD) at least thirty (30) days prior notice of any performance test, except as specified under other subparts, to afford the APCO the opportunity to have an observer present. The permittee shall provide the APCO at least 30 days prior notice of any performance test for demonstrating compliance with any federal, state or district limit.

[40 CFR Part 60.8(d)]



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C18. The permittee shall provide or cause to be provided, testing facilities as follows:

a. Sampling ports adequate for test methods applicable to such facility. This includes: 1) Constructing the air pollution control system such that volumetric flow rates and pollution emission rates can be accurately determined by applicable test methods and procedures and,

2) Providing stack or duct free of cyclonic flow during performance tests, as demonstrated by applicable test methods and procedures.

b. Safe sampling platform(s). c. Safe access to sampling platform(s). d. Utilities for sampling and testing equipment. [(District Rule 2:14), 40 CFR Part 60.8.e] C19. Upon request by the Air Pollution Control Officer, District staff shall be given access to the air conveyance

system blower for the purpose of testing. If testing is requested, test ports shall be added to the inlet pipe of the blower. These ports shall conform to the Districts guidelines.


C20. For the wood fired boiler, compliance with the opacity standard in this permit shall be determined by conducting observations in accordance with Reference Method 9 in Appendix A of 40 CFR Part 60, any alternative method that is approved by the APCO, or from the continuous opacity monitoring system as provided in 40 CFR Part 60.11(e)(5).

[40 CFR Part 60.11(b)] C21. The continuous monitoring system for measuring stack opacity shall have a span value of 100% and utilize

a computer or other facility which has the capability of interpreting sampling data and producing output to demonstrate compliance with applicable standards. The span value for the continuous measuring system for measuring opacity shall be between 60 and 80 percent. The span for the recording instrumentation for the opacity meter shall be 0 to 100%.

[40 CFR Part 60.48b(e)(1)] C22. For opacity, the owner or operator shall submit excess emission reports for any excess emissions which

occurred during the reporting period. The reporting period for the reports required under this subpart is each six-month period as designated in Condition C8 of this permit. All reports shall be submitted to the EPA Administrator and shall be postmarked by the 30th day following the end of the reporting period.

[40 CFR Part 60.49b(h)(1) and 40 CFR Part 60.49b(w)] C23. The owner or operator shall maintain records of opacity to demonstrate compliance with Condition A3 of

this permit. [40 CFR Part 60.49b(f)]



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C24. When nitrogen oxides emission data or other emissions data are not obtained because of continuous emissions monitoring system (CEMS) breakdown, the notification requirements of District Rule 3:10 shall apply. If the continuous monitoring equipment downtime exceeds ninety-six successive operating hours, the permittee shall submit a plan for alternate monitoring to be approved by the APCO.

[Revised District Rule 3:10] C.25. The Permittee shall continuously monitor the Electrostatic Precipitator (ESP) for transformer/rectifier

(T/R set) On/Off status and Rapper On/Off status. The Permittee shall also record hourly readings of the ESP zone voltage (minimum 10 kilovolts, maximum 60 kilovolts) and amps on a designated operators log or data acquisition and handling system.

[PSD Permit SAC 12-01 Condition X.H.12-13] C26. The owner or operator shall maintain an Accidental Release Prevention and Management Program (ARP)

for the ammonia injection system (AIS) at the facility. The ARP requires a Hazard Review update be completed at least every 5 years, and a Compliance Audit performed at least every 3 years.

[CCR Title 19, Chapter 4.5, Section 112(r)] C27. Compliance Assurance Monitoring (CAM): Compliance with the standards in the Boiler MACT with the

CEMS unit provides a reasonable assurance of compliance for NOx, therefore, a CAM plan is required for PM only.

[40 CFR Part 64.6(c)(3), Part 64.2(b)(1)(i)] D. STANDARD CONDITIONS D1. References to rules, regulations, etc., within this permit shall be interpreted as referring to such rules and

regulations in their present configuration and language as of the date of issuance of this permit.

[District Permit 10-PO-06, Condition I.14] D2. Acceptance of this permit is deemed acceptance of all conditions as specified. Failure to comply with any

condition of this permit shall be grounds for revocation, either by the Air Pollution Control Officer or the Air Quality Management District Hearing Board.

[District Permit 10-PO-06, Condition I.5, District Permit 03-PO-09 Condition 5, District Permit 02-PO-23 Condition 5, District Permit 87-PO-17 Condition 5]



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D3. At all times, including periods of startup, shutdown, and malfunction, owners and Permittees shall, to the extent practicable, maintain and operate any affected facility including associated air pollution control equipment in a manner consistent with good air pollution control practices for minimizing emissions. Determination of whether acceptable operating and maintenance procedures are being used will be based on information available to EPA, which may include, but is not limited to, monitoring results, opacity observations, review of operating maintenance procedures and inspection of the Facility.

[40 CFR Part 60.11(d), PSD Permit SAC 12-01 Condition III.A & X.B] D4. Upon notification from the APCO, the permittee will abate any air-quality-related nuisance associated

with the equipment defined under this Permit or from any process which is indirectly or directly associated with such equipment.

[SCAQMD Rule 3:16] D5. The permittee shall comply with all permit conditions of this Title V operating permit and all other

applicable federal, state and local environmental laws and regulations, including the Clean Air Act. [SCAQMD Rule 5, PSD Permit SAC 12-01 Condition VIII.] D6. This permit does not convey property rights or exclusive privilege of any sort. [SCAQMD Rule 5] D7. The non-compliance with any permit condition herein is grounds for Title V Operating Permit and District

Permit to Operate termination, revocation, modification, enforcement action, or denial of permit renewal. [SCAQMD Rule 5] D8. This permit may be modified, revoked, reopened and reissued, or terminated for cause as determined by

the District. [SCAQMD Rule 5] D9. It shall not be a defense for the permittee in an enforcement action that it would have been necessary to

halt or reduce the permitted activity in order to maintain compliance with the conditions of this permit. [SCAQMD Rule 5] D10. A pending permit action or notification of anticipated non-compliance does not stay any permit condition. [SCAQMD Rule 5]



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D11. Within a reasonable time period, the permittee shall furnish any information requested by the APCO, in writing, for the purpose of determining:

a. Compliance with the permit;

b. Whether cause exists for a permit or enforcement action. [SCAQMD Rule 5] D12. Any person who is building, erecting, altering, or replacing any article, machine, equipment or other

contrivance, or multi-component system including same, portable or stationary, and who is not exempt under Section 42310 of the CHSC, the use of which may cause the issuance of air pollutants, shall first obtain written authority for such construction from the APCO.

[SCAQMD Rule 2:1A, Permits Required 54 FR 26381, 6/18/82] D13. Before any article, machine, equipment or other contrivance, or multi-component system including same,

portable or stationary, not exempt under Section 42310 of the CHSC, the use of which may cause the issuance of air pollutants, may be operated or used, a written permit shall be obtained from the APCO.

[SCAQMD Rule 2:1A] D14. Where an application for or issuance of a permit is pending or in the event of an emergency occurring as

a result of an excusable malfunction of a device under permit, the APCO may authorize the operation of the article, machine, equipment, device, or other contrivance or multi-component system for which a permit is sought for periods of time not to exceed sixty (60) days each for the purpose of testing, experimentation, or obtaining necessary data for a permit or correcting a malfunction. No fee or application will be required for such authorization.

[SCAQMD Rule 2:1A] D15. No person shall willfully deface, alter, forge, counterfeit, or falsify a Permit to Operate, any article,

machine, equipment, or other contrivance. [SCAQMD Rule 2:21, Defacing Permit, 37 FR 19812, 9/22/72 (current Rule 2:24)] D16. A person who has been granted a Permit to Operate as described in Rule 2:1A.b., shall firmly affix such

permit, an approved facsimile, or other approved identification bearing the permit number upon the article, machine, equipment or other contrivance in such a manner as to be clearly visible and accessible. In the event that the article, machine, equipment or other contrivance is so constructed or operated that the Permit to Operate cannot be so placed, the Permit to Operate shall be mounted so as to be clearly visible in an accessible place within 25 feet of the article, machine, equipment, or other contrivance, or maintained readily available at all times on the operating premises.

[SCAQMD Rule 2:23, Posting of Permit to Operate, 54 FR 14650, 9/22/72]



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D17. All information, analyses, plans, or specifications that disclose the nature, extent, quantity, or degree of air pollutants or other pollution that any article, machine, equipment, or other contrivance will produce and that any air pollution control district or any other state or local agency or District requires any applicant to provide before such applicant builds, erects, alters, replaces, operates, sells, rents, or uses such article, machine, equipment, or other contrivance, are public records.

[SCAQMD Rule 2:25, Public Records - Trade Secrets, 42 FR 42223, 8/22/77]

D18. All air or other pollution monitoring data, including data compiled from stationary sources, are public

records.

[SCAQMD Rule 2:25, Public Records - Trade Secrets, 42 FR 42223, 8/22/77] D19. Except as otherwise provided in Condition D22 (below), trade secrets are not public records under this

Condition. As used in this Condition, "trade secrets" may include (but are not limited to) any formula, plan, pattern, process, tool, mechanism, compound, procedure, production data, or compilation of information that:

a. Is not patented, b. Is known only to certain individuals within a commercial concern who are using it to fabricate,

produce, or compound an article of trade or a service having commercial value, and c. Gives its user an opportunity to obtain a business advantage over competitors who do not know or

use it.

[SCAQMD Rule 2:25, Public Records -- Trade Secrets, 42 FR 42223, 8/22/77] D20. Notwithstanding any other provision of law, all air pollution emission data, including those emission data that constitute trade secrets as defined in subdivision c, are public records. Data used to calculate emission data are not emission data for the purposes of this subdivision, and data that constitute trade secrets and that are used to calculate emission data are not public records.

[SCAQMD Rule 2:25, Public Records -- Trade Secrets, 42 FR 42223, 8/22/77]

D21. Pursuant to District Rule 2:16, the APCO may revoke an existing Authority to Construct and/or Permit to

Operate if the applicant and/or permittee violate the conditions of such permit as specified by the APCO. The APCO may reinstate the permit at such time as the applicant and/or permittee shows that the condition(s) previously violated are now being attained. Such showing shall not bar the APCO from pursuing any legal remedy with respect to any violation that resulted from the failure to meet any permit condition as specified by the APCO.

[SCAQMD Rule 2:26, Revocation of Permit, 54 FR 14650, 4/12/89]

D22. Each and every provision of Federal or State law or applicable Air Basin Plan now or hereinafter enacted

or as amended that regulates the discharge of any air pollutants is incorporated here by reference. Where such provisions conflict with local rules and regulations; the more restrictive provisions shall apply.

[SCAQMD Rule 3:1, Applicability of State Laws, 42 FR 42223, 8/22/77]



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D23. The Regional Administrator of U.S. Environmental Protection Agency (U.S. EPA), the Executive Officer of the California Air Resources Board, the APCO, or their authorized representatives, upon the presentation of credentials, shall be permitted to enter upon the premises: a. To inspect the stationary source, including equipment, work practices, operations, and emission-

related activity; and b. To inspect and duplicate records required by this Permit to Operate; and c. To sample substances or monitor emissions from the source or other parameters to assure compliance with the permit or applicable requirements. Monitoring of emissions can include source testing.

[SCAQMD Rule 5] D24. The provisions of this Title V Operating Permit are severable, and, if any provision of this Permit is held

invalid, the remainder of this Permit to Operate shall not be affected thereby. [SCAQMD Rule 5] D25. Sierra Pacific Industries, Anderson Division, shall apply for renewal of this permit no earlier than six (6)

months before the date of expiration. Upon submittal of a timely and complete renewal application, this Operating Permit shall remain in effect until the APCO takes final action on the application.

[SCAQMD Rule 5] D26. The permittee shall remit the Title V supplemental annual fee to the district on a timely basis. Failure to

remit fees on a timely basis is grounds for forfeiture of this Operating Permit and the District Permit to Operate. Operation without a Permit to Operate subjects the source to potential enforcement action by the District and the U.S. EPA pursuant to section 502(a) of the Clean Air Act.

[SCAQMD Rule 5] D27. Persons performing maintenance, service, repair or disposal of appliances using CFC's, HCFC's, or other

ozone-depleting substances must be certified by an approved technician certification program.

[40 CFR Part 82.161, Stratospheric Ozone Protection] D28. Persons opening appliances using CFC's, HCFC's or other ozone depleting substances for maintenance,

service, repair, or disposal must comply with the required practices pursuant to 40 CFR 82.156. [40 CFR 82.156, Stratospheric Ozone Protection] D29. Equipment used during the maintenance, service, repair, or disposal of appliances using CFC's, HCFC's

or ozone-depleting substances must comply with the standards for recycling and recovery equipment pursuant to 40 CFR 82.158.

[40 CFR 82.158, Stratospheric Ozone Protection]



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D30. No person shall build, erect, install, or use any article, machine, equipment, or other contrivance, the use of which, without resulting in a reduction in the total release of air pollutants to the atmosphere, reduces or conceals an emission that would otherwise constitute a violation.

[SCAQMD Rule 3:6, Circumvention, 42 FR 42223, 8/22/77, 40 CFR Part 60.12]

D31. This permit is not transferable from either one location to another, one piece of equipment to another, or

from one person to another. Within 14 days of any such change in control of ownership, Permittee shall notify the succeeding owner and operator of the existence of all applicable permits and conditions by letter. Permittee shall send a copy of this letter to EPA Region IX within 30 days of its issuance.

[SCAQMD Rule 2:23, Transfer of Permit, PSD Permit SAC 12-01 Condition VI.] D32. Equipment is to be maintained so that it operates as it did when the permit was issued. [SCAQMD Rule 5] D33. All equipment, facilities, and systems shall be designed to be operated in a manner that minimizes air

pollutant emissions and maintains compliance with the conditions of this permit and the regulations of the District.


D34. This facility is subject to the applicable New Source Performance Standards codified at 40 CFR, Subparts

A, and Db.

[District Permit 10-PO-06, Condition I.16] D35. The right of entry described in CHSC 41510, Division 26, shall apply at all times.


D36. The operating staff of this facility shall be advised of and familiar with all the conditions of this permit.


D37. No hexavalent chromium containing compounds shall be added to the circulating water of any cooling tower used at this facility. [SCAQMD Rule 3:19]



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E. WOOD CHIP LOADING FACILITY E1. The railcar chip loader piping shall be maintained in a leak-free condition. [District Permit 03-PO-09, Condition 13] E2. The dust containment hood shall be utilized at all times that the chip loading system is loading railcars. [District Permit 03-PO-09, Condition 14] E3. The wood chip loading system shall not process more than 80,000 tons of wood chips per year. Sierra

Pacific Anderson shall keep sufficient records to demonstrate compliance with this limit. [District Permit 03-PO-09, Condition 16] F. FUNGICIDE SPRAY MISTING UNIT

F1. All fungicide coating operations shall be done inside the spray misting unit. Fungicide shall not be applied

by hand or with any hand held equipment. All operations shall be conducted in a controlled area such that a public nuisance is not caused to surrounding receptors.

[District Permit 02-PO-23, Condition 13] F2. The permittee shall maintain and make available to District personnel, a current list of coatings (including

specialty coatings) and additives in use that provides all of the data necessary to evaluate compliance, including the following information, as applicable:

a. Coatings used b. Mix ratio of components used

c. VOC content of coating as applied in grams/liter or lbs./gal. (less water and less exempt organic compounds)

d. Material Safety Data Sheets (MSDS) [District Permit 02-PO-23, Condition 14] F3. The permittee shall maintain records which indicate on a daily basis the following information:

a. VOC content of the coating used in grams/liter or lbs/gal b. Quantity of each coating (including each specialty coating) applied. If purchase records are used

to determine the amount of coatings used, then records and manifests of the amounts of coatings disposed of or sent to a recycler must also be maintained.

[District Permit 02-PO-23, Condition 15]



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F4. Each container holding volatile organic waste shall be labeled with the contents identified and the dates noted on when waste material was added.


F5. The owner or operator shall inspect all containers holding volatile organic compounds or waste, at least weekly, looking for leaks and for deterioration caused by corrosion or other factors.


F6. Containers holding ignitable or reactive waste must be located within the property boundary at least 15

meters (50 feet) from the facility's property line. [District Permit 02-PO-23, Condition 18]

F7. Incompatible wastes must not be placed in the same container. The treatment, storage, and disposal of ignitable or reactive waste, and the commingling of wastes, or wastes and materials, must be conducted so it does not:

a. Generate extreme heat, pressure, explosion, or violent reaction; b. Produce uncontrolled toxic mists, fumes, dusts or gases in sufficient quantities to threaten human

health; c. Produce flammable fumes or gases in sufficient quantities to pose a risk of fire or explosions; d. Damage the structural integrity of the device or facility containing the waste; or e. Through other means threaten human health or the environment.


F8. The owner or operator shall not dispose of any volatile organic waste unless the disposal of such waste has been approved by the State of California Regional Water Quality Control Board and the County Director of Environmental Health. All hazardous volatile organic waste as defined in Title 22 of the California Code of Regulations shall be disposed of in a Class I landfill or treated, stored, or handled in a manner acceptable to the State of California Department of Toxic Substance Control.


F9. Any person operating a facility for the treatment of volatile organic waste shall reduce the volatile organic

compound (VOC) content of the waste by no less than 99 percent by such treatment. The Air Pollution Control Officer (APCO) may establish requirements to ensure that emissions from the treatment process do not endanger public health. ARB Method 401 shall be used to quantify VOC content of treated and untreated waste.




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F10. Any person operating a process for the recovery of resources from any volatile organic waste shall recover or reduce at least 80 percent of the volatile organic compound (VOC) content of the waste during such recovery process. ARB Method 401 shall be used to quantify VOC content of the waste.


F11. Any facility which generates, stores, transfers, treats, recovers, recycles, or disposes of volatile organic wastes shall maintain records for a minimum of the most recent two (2) calendar years for inspection by the APCO documenting the following information:

a. Amount of solvent sent to waste; b. Amount of solvent sent to resource recovery; and c. Amount of solvent sent to treatment facility.


F12. The operator shall not discharge twenty-five (25) or more pounds per day of reactive organic

compounds/VOCs (as defined in Part 220 of District Rule 2:1) from this emission unit unless Best Available Control Technology (BACT) is applied. BACT for this facility shall be:

a. All VOC containing materials, including but not limited to, fresh or spent solvents and coatings

must be stored in closed containers. Containers shall be nonabsorbent. b. The spray mist system shall be turned off when not being used to coat lumber.

c. All mist overspray/runoff shall be immediately collected and either returned to the original closed container or stored in separate closed containers. d. The spray mist system shall only be used to apply water borne fungicide solutions. Any change in

coating type or manufacturer shall first be approved by the APCO. [District Permit 02-PO-23, Condition 24]

F13. The operator shall not discharge more than a total of twenty-five (25) tons per year of reactive organic compounds/VOCs (as defined if Part 220 of District Rule 2:1) from all emission units at this facility.


F14. The operation of the spray misting system shall not exceed: a. 22 hours per day b. 2288 hours per calendar year

The permittee shall maintain daily operating records as needed to show compliance with this condition. Records shall be maintained on site for a period of two years and shall be submitted to the APCO upon request.




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F15. Any wood or wood product that has been treated with fungicide solutions shall not be burned in the facility’s wood-fired boiler.


G. NATURAL GAS-FIRED EMERGENCY BACKUP FEED WATER PUMP ENGINE

G1. Visible emissions from the operation of the natural gas engine shall not be discharged for a period or

periods aggregating more than three (3) minutes in any one (1) hour which are as dark or darker than Ringelmann 2 or equivalent forty percent (40%) opacity as determined by EPA Method 9.

[CH&S Section 41701, District Permit 10-PO-06, Condition IX.a.1.]

G2. Daily operation (and maintenance) records shall be maintained. These records shall be retained for a

period of two (2) years and shall be available for review upon request of the Air Pollution Control Officer.

[40 CFR 60.4243(a)(1), District Permit 10-PO-06, Condition IX.a.2.] G3. Except during an emergency, the natural gas engine shall be limited to no more than one-hundred (100)

hours per 12-month period on a rolling average of operation in regards to testing and maintenance purposes. The engine shall have a non-resettable elapsed time meter installed for recording the operation time of the engine.

[40 CFR 60.4237(b), District Permit 10-PO-06, Condition IX.a.3.,PSD Permit SAC 12-01 Condition X.E.2]

G4. The natural gas engine shall be fired exclusively on propane or PUC quality natural gas. Any change in

the type of fuel used shall first be reviewed and approved by the District.

[District Permit 10-PO-06, Condition IX.a.4.]

G5. Emission limits for the natural gas engine shall be based on the BACT determination performed in the EPA final comments response document dated February 2013. They are as follows:

NOx: 0.78 lbs/hr CO: 4.0 g/hp-hr (3-hour block average)

6.11 lbs/hr PM10: 0.0216 lbs/hr

[District Permit 10-PO-06, Condition IX.a.6.] G.6 The natural gas engine shall not operate during startup of the Boiler Unit except when required for

emergency operations.

[PSD Permit SAC 12-01 Condition X.F.4]



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G.7 The Permittee shall conduct an initial performance test (as described in 40 CFR 60.4244) for NOx and CO at least every five years beginning ten years after the initial performance test (within 30 days of the tenth anniversary of the initial performance test date) Upon written request from the Permittee, and adequate justification, EPA may waive a specific annual test and/or allow for testing to be done at less than maximum operating capacity.

[PSD Permit SAC 12-01 Condition X.I.4, X.I.5]

H. 40 CFR Part 63 Subpart DDDDD, National Emission Standards for Hazardous Air Pollutants for Industrial, Commercial, and Institutional Boilers Major Sources H1. All notification and reporting requirements associated with the following Subpart DDDDD requirements shall be submitted to the Administrator as required.

[Table 1 Subpart DDDDD of 40 CFR part 63] H2. Boiler Emissions Limitations: The owner or operator shall maintain emissions of PM, CO, HCL, and Hg,

below the levels shown in section A1 of this permit.

[Table 1 Subpart DDDDD of 40 CFR part 63] H3. Work Practice Standards: The Permitee shall maintain an optimum air to fuel ratio within the oxygen trim

system and conduct a tune-up of the wood fired boiler no less than every 5 years.

[Table 3 to Subpart DDDDD of 40 CFR part 63] H4. Initial Compliance Demonstration Requirements: The Permitee must demonstrate initial compliance as

required under §63.7530 and Tables 5, 6, and 7 with filterable PM or TSM, CO, HCl and mercury emission limits for the wood fired boiler by: (a) If the Permitee chooses to demonstrate compliance through performance stack testing, then

conduct the initial performance tests according to §63.7520 and Table 5 by July 29, 2016; (b) If the Permitee chooses to demonstrate compliance through fuel analysis, then conduct a fuel

analysis for each type of fuel burned in the boiler, unless the boiler burns a single type of fuel, by July 29, 2016. For purposes of Subpart DDDDD, units that use a supplemental fuel only for startup, unit shutdown, and transient flame stability purposes still qualify as units that burn a single type of fuel;

(c) Establishing operating limits according to §63.7530 and Table 7; (d) If compliance is demonstrated through performance stack testing, the Permitee must establish each

site-specific operating limit in Table 4 that applies according to the requirements in §63.7520, Table 7 to Subpart DDDDD, and paragraph (b)(4) of §63.7530, as applicable;

(e) Conducting CMS performance evaluations according to §63.7525; (f) If the Permitee conducts multiple performance tests, the Permitee must set the minimum oxygen

level at the lower of the minimum values established during the performance tests;



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(g) Installing, operating, and maintaining all applicable Computer Monitoring System (CMS) (including CEMS, COMS, and CPMS) according to §63.7525;

[§63.7510(a)(1), (a)(2), (a)(3), (a)(4), (b), (c), (d), (e); §63.7520(c); §63.7525; §63.7530(a), (b)(4), (b)(4)(ii), (b)(4)(viii); Table 5 to Subpart DDDDD of 40 CFR part 63; §63.7]

H5. Ongoing Compliance Demonstration Requirements: The Permitee shall demonstrate ongoing compliance

with filterable PM or TSM, CO, HCl and mercury emission limits for the wood fired boiler by: (a) If compliance is chosen to be demonstrated through performance stack testing, then conduct annual

performance testing according to §63.7520. If the performance tests for a given pollutant for at least 2 consecutive years show that the emissions are at or below 75% of the emission limit for the pollutant, and if there are no changes in the operation of the unit or control equipment, the Permitee may choose to conduct performance tests for the pollutant every third year;

(b) Conducting a 5-year performance tune-up of the Wood fired boiler according to §63.7540. Each 5-year tune-up must be conducted no more than 61 months after the previous tune-up (completed January 27, 2015);

(c) If the Permitee elects to demonstrate compliance with the mercury, HCl, or TSM limits based on fuel analysis, conduct a monthly fuel analysis according to §63.7521 for each type of fuel burned in the Wood fired boiler. The Permitee may comply with this monthly requirement by completing the fuel analysis any time within the calendar month as long as the analysis is separated from the previous analysis by at least 14 calendar days; if multiple samples are taken per month, the 14-day restriction does not apply. If each of 12 consecutive monthly fuel analyses demonstrates 75 percent or less of the compliance level, the Permitee may decrease the fuel analysis frequency to quarterly for that fuel. If any quarterly sample exceeds 75 percent of the compliance level, or a new type of fuel is burned, the frequency of the fuel analysis for that fuel must return to monthly;

(d) The Permitee must meet the work practice standard according to 40 CFR part 63 Table 3. During startup and shutdown, the Permitee must only follow the work practice standards according to item 5 of Table 3 (for startup) and item 6 of Table 3 (for shutdown) of Subpart DDDDD;

(e) Ongoing compliance shall be demonstrated according to the methods specified in 40 CFR part 63 Table 8;

(f) If the Permitee operates a CO CEMS that meets the Performance Specifications outlined in §63.7525(a)(3) of Subpart DDDDD to demonstrate compliance with an applicable alternative CO CEMS emissions standard listed in 40 CFR part 63 Tables 1, 2 or 11 through 13, the Permitee is not required to conduct CO performance tests and is not subject to the oxygen concentration operating limit specified in §63.7510(a).

(g) The Permitee must demonstrate continuous compliance with the Subpart DDDDD emission limits, work practice standards and operating limits in accordance with §63.7540, as applicable.

[§63.7510(a)(1); §63.7515(a), (b), (c), (d), (e), (i); §63.7530(b), (h); §63.7540(a)(10) to Subpart DDDDD of 40 CFR part 63; §63.7]

H6. Fuel Analyses for Chlorine, Mercury and Total Suspended Metals (TSM): If the Permitee chooses to demonstrate compliance with the mercury, HCl, or TSM emission limits based on fuel analysis, monthly fuel analysis must be conducted according to §63.7521 for each type of fuel burned that is subject to an emission limit unless and until such time as fuel analysis frequency may be decreased as specified in Ongoing Compliance Demonstration Requirements and §63.7515(e). The Permitee shall conduct fuel



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analyses for chlorine and mercury according to the procedures in paragraphs (b) through (e) of §63.7521 for all fuels consumed in boilers except supplemental fuels used only during startup and shutdown or for transient flame stability. (a) The Permitee shall develop a site-specific fuel monitoring plan according to the procedures in

§63.7521(b) and submit the plan to the Administrator for approval no later than 60 days before the date the Permitee intends to conduct an initial compliance demonstration;

(b) Fuel analyses shall be conducted in accordance with the Permitee’s site-specific fuel monitoring plan and shall conform to the methods and procedures in §63.7521 and Table 6 to Subpart DDDDD of 40 CFR part 63;

(c) During the initial fuel analysis, the Permitee shall establish the fuel mixture that has the highest content of chlorine using the procedures in paragraphs (b)(1)(i)-(iii) of §63.7530;

(d) During the initial fuel analysis, the Permitee shall establish the fuel mixture that has the highest content of mercury using the procedures in paragraphs (b)(2)(i)-(iii) of §63.7530;

(e) During the initial fuel analysis, the Permitee shall establish the fuel mixture that has the highest content of TSM using the procedures in paragraphs (b)(3)(i)-(iii) of §63.7530;

(f) A fuel analysis may be used to demonstrate compliance with an emission limit for hydrogen chloride, mercury or TSM by following the procedures in §63.7521 and paragraph (c) of §63.7530; and

(g) If the Permitee demonstrates compliance with an emission limit for hydrogen chloride or mercury through fuel analysis and a new type of fuel is planned to be burned, the emission rate shall be recalculated according to the procedures specified in §63.7530.

[§63.7510(a)(2)(i); §63.7515(e); §63.7521 (a), (b); §63.7530 (b)(1), (b)(2), (b)(3), (c); §63.7540 (a)(3), (a)(5); Table 6 to Subpart DDDDD of 40 CFR part 63]

H7. Boiler Operating Limits: The Permitee shall establish site-specific operating limits for the wood fired boiler as shown in Table 4. Subsequent performance test results must verify that the operating limits for the boiler have not changed or provide documentation of revised operating limits established according to §63.7530 and Table 7, as applicable. [§63.7510(a)(3); §63.7515(f); §63.7530; Tables 4 and 7 to Subpart DDDDD of 40 CFR part 63]

H8. General Operating Requirements for CMS: The following requirements apply to CMS required for the

wood fired boiler as follows: (a) The Permitee shall maintain and operate each CMS in a manner consistent with good air pollution

control practices; (b) The Permitee shall maintain and operate each CMS according to the procedures in paragraphs

(d)(1) through (5) of §63.7525, as applicable; (c) The Permitee must operate and maintain each COMS and CMS in continuous operation according

to the site-specific monitoring plan and each COMS according to §63.7525(c); (d) The Permitee, as applicable, must operate and maintain each CEMS used to comply with mercury

or HCl limits according to §63.7525(l); (e) Except for periods of monitoring system malfunctions, repairs associated with monitoring system

malfunctions, and required monitoring system quality assurance or quality control activities



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(including, as applicable, system accuracy audits, calibration checks, and required zero and span adjustments), failure to collect required data is a deviation from the monitoring requirements;

(f) The CMS must complete a minimum of one cycle of operation every 15-minutes and must have a minimum of four successive cycles of operation, one representing each of the four 15-minute periods in an hour, to have a valid hour of data;

(g) The CMS shall be operated and shall collect data at all required intervals at all times that the boiler is operating and compliance is required, except for periods of monitoring system malfunctions or out of control periods as provided in §63.8(c)(7), and required monitoring system quality assurance or control activities, including, as applicable, calibration checks, required zero and span adjustments, and scheduled CMS maintenance as defined in the Permitee’s site-specific monitoring plan. A monitoring system malfunction is any sudden, infrequent, not reasonably preventable failure of the monitoring system to provide valid data. Monitoring system failures that are caused in part by poor maintenance or careless operation are not malfunctions;

(h) The Permitee is required to complete monitoring system repairs in response to monitoring system malfunctions or out-of-control periods and to return the monitoring system to operation as expeditiously as practicable;

(i) The Permitee may not use data recorded during periods of startup and shutdown, monitoring system malfunctions or out-of-control periods, repairs associated with monitoring system malfunctions or out-of-control periods, or required monitoring system quality assurance or control activities in data averages and calculations used to report emissions or operating levels. The Permitee must use all the data collected during all other periods in assessing compliance and the operation of the control device and associated control system;

(j) The Permitee must record and make available upon request results of CMS performance audits and dates and duration of periods when the CMS is out of control to completion of the corrective actions necessary to return the CMS to operation consistent with the Permitee’s site-specific monitoring plan;

(k) Any 15-minute period for which the monitoring system is out-of-control and data are not available for a required calculation constitutes a deviation from the monitoring requirements. Other situations that constitute a monitoring deviation are specified in §63.7535(d);

(l) The 30-day rolling average of all recorded readings shall be determined, except as provided in (e) above; and

(m) Results of each inspection, calibration, and validation check shall be recorded.

[§63.7500(a)(3); §63.7505(d)(4); §63.7510(a)(4); §63.7525(c)(5), (d)(1), (d)(2), (d)(3), (d)(4), (d)(5), (l); §63.7535(b), (c), (d)(3) to Subpart DDDDD of 40 CFR part 63; §63.8(1)(ii); §63.8(c)(3); §63.8(c)(4)(ii)]

H9. CMS Performance Evaluations: The Permitee shall conduct a performance evaluation of each required

CMS in accordance with the site-specific CMS monitoring plan. (a) CMS performance evaluations shall be conducted according to §63.7525; (b) Initial performance evaluations shall be completed no later than July 29, 2016; (c) Subsequent performance evaluations for flow monitoring systems shall be conducted at the time

of each performance test but no less frequently than annually

[§63.7510(a)(4); §63.7525(a)(2)(i), (a)(2)(v), (e)(4) to Subpart DDDDD of 40 CFR part 63; §63.8(e)]



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H10. CO and Oxygen Monitoring: The Permitee shall either install, operate, and maintain an oxygen analyzer system as defined in §63.7575, or install, certify, operate and maintain CEMS for CO and oxygen according to the following procedures: (a) The Permitee must install, operate, and maintain an oxygen analyzer system in accordance with

the manufacturer's recommendations, as defined in §63.7575, or install, certify, operate and maintain continuous emission monitoring systems for CO and oxygen (or carbon dioxide (CO2)) according to the procedures in paragraphs (a)(1) through (6) of §63.7525;

(b) The CO and oxygen levels shall be monitored at the same location at the outlet of the boiler; (c) To demonstrate compliance with the applicable alternative CO CEMS emission standard listed in

Table 2, the Permitee must install, certify, operate, and maintain a CO CEMS and an oxygen analyzer according to the applicable procedures under §63.7525. Any boiler that has a CO CEMS that is compliant with Performance Specification 4, 4A, or 4B at 40 CFR part 60, Appendix B, a site-specific monitoring plan developed according to §63.7505(d), and the requirements in §63.7540(a)(8) and paragraph (a) of this section must use the CO CEMS to comply with the applicable alternative CO CEMS emission standard listed in Tables 1, 2, or 11 through 13 to Subpart DDDDD:

(i) The Permitee must conduct a performance evaluation of each CO CEMS according to the requirements in §63.8(e) and according to Performance Specification 4, 4A, or 4B at 40 CFR part 60, Appendix B;

(ii) During each relative accuracy test run of the CO CEMS, the Permitee must collect emission data for CO concurrently (or within a 30- to 60-minute period) by both the CO CEMS and by Method 10, 10A, or 10B at 40 CFR part 60, appendix A-4. The relative accuracy testing must be at representative operating conditions;

(iii) The Permitee must follow the quality assurance procedures (e.g., quarterly accuracy determinations and daily calibration drift tests) of Procedure 1 of appendix F to part 60. The measurement span value of the CO CEMS must be two times the applicable CO emission limit, expressed as a concentration;

(iv) Any CO CEMS that does not comply with §63.7525(a) cannot be used to meet any requirement in Subpart DDDDD to demonstrate compliance with a CO emission limit listed in Tables 1, 2, or 11 through 13 to Subpart DDDDD; and

(v) Complete the initial performance evaluation no later than July 29, 2016. (d) Complete a minimum of one cycle of CO and oxygen CEMS operation (sampling, analyzing, and

data recording) for each successive 15-minute period. Collect CO and oxygen data concurrently. Collect at least four CO and oxygen CEMS data values representing the four 15-minute periods in an hour, or at least two 15-minute data values during an hour when CEMS calibration, quality assurance, or maintenance activities are being performed;

(e) Reduce CO CEMS data as specified in §63.8(g)(2). It is to be reduced to 1-hour averages computed from four or more data points equally spaced over each 1-hour period, except during periods when calibration, quality assurance, or maintenance activities pursuant to provisions of this part are being performed. During these periods, a valid hourly average shall consist of at least two data points with each representing a 15-minute period. Alternatively, an arithmetic or integrated 1-hour average of CEMS data may be used;

(f) Calculate one-hour arithmetic averages, corrected to 3 percent oxygen from each hour of CO CEMS data in parts per million CO concentration. The one-hour arithmetic averages required shall be used to calculate the 30-day or 10-day rolling average emissions. Use Equation 19-19 in



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section 12.4.1 of Method 19 of 40 CFR part 60, appendix A-7 for calculating the average CO concentration from the hourly values;

(g) For purposes of collecting CO data, operate the CO CEMS as specified in §63.7535(b). The Permitee must use all the data collected during all periods in calculating data averages and assessing compliance, except that the Permitee must exclude certain data as specified in §63.7535(c). Periods when CO data are unavailable may constitute monitoring deviations as specified in §63.7535(d); and

(h) Operate an oxygen trim system with the oxygen level set no lower than the lowest hourly average oxygen concentration measured during the most recent CO performance test as the operating limit for oxygen according to Table 7 to Subpart DDDDD.

[§63.7525(a), (a)(1), (a)(2), (a)(3), (a)(4), (a)(5), (a)(6), (a)(7); §63.7575 to Subpart DDDDD of 40 CFR part 63; §63.8(1)(ii); §63.8(c)(3); §63.8(c)(4)(ii); §63.8(g)(2)]

H11. Site-specific Stack Test Plan: The Permitee must also develop a site-specific stack test plan according to the requirements in §63.7(c). The site-specific test plan shall be in accordance with requirements in §63.7520(a) and §63.7(c)(2)(i), and shall include a test program summary, the test schedule, data quality objectives, and both an internal and external quality assurance (QA) program in accordance with §63.7(c).

[§63.7(c); §63.7520(a) to Subpart DDDDD of 40 CFR part 63]

H12. Monitoring Compliance with Operating Limits: The Permitee shall continuously monitor the following

operating conditions of the wood fired boiler as follows: (a) Any operating conditions for which an operating limit from Table 4 to Subpart DDDDD of 40

CFR Part 63 applies, such as the total secondary electric power input; (b) The operational status of the boiler; (c) Times and durations of startup, shutdown, standby and transient flame stabilization operation of

the boiler; (d) The rate and type of fuels combusted; (e) For each startup period, for units selecting paragraph (2) of the definition of “startup” in §63.7575

the Permitee must maintain records of the time that clean fuel combustion begins; the time when the Permitee starts feeding fuels that are not clean fuels; the time when useful thermal energy is first supplied; and the time when the PM controls are engaged (refer to the Startup Shutdown Plan (SSP) prepared by the facility); and

(f) Both the hourly and 24-hour average overall heat rate to the boiler in terms of MMBtu/hr.

[§63.7555(d)(6), (d)(11) to Subpart DDDDD of 40 CFR part 63] H13. Notifications:

A. Notifications: The following notifications must be submitted to the Administrator by the dates specified: (a) Initial Notifications: The Permitee must submit to the Administrator an initial notification when

a boiler becomes subject to Subpart DDDDD of 40 CFR Part 63 in accordance with §63.9(b), postmarked or delivered within 15 calendar days from the date of actual startup of the boiler;



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(b) Notification of Compliance Status. The Permitee must submit to the Administrator a Notification of Compliance Status for the boiler in accordance with §63.9(h)(2)(ii) and §63.7545(e), including all performance test results and fuel analyses. The Initial Compliance Status Report shall be submitted before the close of business on the 60th day following the completion of all performance tests and/or other initial compliance demonstrations for the boiler. The Permitee must include with the Notification of Compliance Status the information specified at §63.7545(e), as applicable, and a signed certification that the energy assessment was completed according to Table 3 to Subpart DDDDD and is an accurate depiction of the facility at the time of the assessment, or that the maximum number of on-site technical hours specified in the definition of energy assessment applicable to the facility has been expended;

(c) Submission of a CMS site-specific performance evaluation test plan. If requested, the Permitee must submit to the Administrator for approval any CMS site-specific monitoring plan at least 60 calendar days before the initial CMS performance evaluation is scheduled to begin, or on a mutually agreed upon date;

(d) Notification of fuel changes and modifications. The Permitee must provide notice of the date of any fuel change or physical changes in any boiler that results in the applicability of a different subcategory under Subpart DDDDD to the boiler within 30 days of the switch/change. The notification must identify the owner or operator and location of the source, the boiler that switched fuels or was physically changed, the date of the notice, the currently applicable subcategory and the date upon which the fuel switch or physical change occurred; and

(e) Notification of intent to conduct a performance test. The Permitee must submit a notification of intent to conduct a performance test at least 60 days before the performance test is scheduled to begin.

[§64.7(d); §63.7505(d)(1); §63.7530(e); §63.7530(f); §63.7545(a), (b), (d), (e), (h)) to Subpart DDDDD of 40 CFR part 63]

B. Compliance Reports. The Permitee must submit compliance reports for the boilers, including each report

in Table 9, as follows: (a) The initial semi-annual compliance report must be postmarked or submitted no later than January

31, 2017 and must cover the period beginning on January 31, 2016 and ending July 31, 2016; (b) Each subsequent semi-annual compliance report must cover the reporting period from January 1

through June 30 or the reporting period from July 1 through December 31. Annual, biennial, and 5-year compliance reports must cover the applicable 1-, 2-, or 5-year periods from January 1 to December 31;

(c) Each subsequent semi-annual compliance report must be postmarked or submitted no later than July 31 or January 31, whichever date is the first date following the end of the semiannual reporting period. Annual, biennial, and 5-year compliance reports must be postmarked or submitted no later than January 31;

(d) Compliance reports must contain the following information depending on how the Permitee chooses to comply: (i) Company and Facility name and address; (ii) Boiler identification, emissions limitations, and operating parameter limitations; (iii) Date of report and beginning and ending dates of the reporting period; (iv) The total operating time during the reporting period;



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(v) If a CMS is used for compliance monitoring, including CEMS, COMS, or CPMS, include the monitoring equipment manufacturer(s) and model numbers and the date of the last CMS certification or audit;

(vi) The total fuel use by each individual boiler within the reporting period, including, but not limited to, a description of the fuel, whether the fuel has received a non-waste determination by the EPA or the Permitee’s basis for concluding that the fuel is not a waste, and the total fuel usage amount with units of measure;

(vii) If the Permitee is conducting performance tests once every 3 years consistent with §63.7515(b) or (c), the date of the last 2 performance tests and a statement as to whether there have been any operational changes since the last performance test that could increase emissions; and

(viii) A statement indicating that no new types of fuel were burned, or if a new type of fuel was burned since the last performance test for any boiler, the following must be included: a) Submit the calculation of chlorine input, using Equation 7 of §63.7530

demonstrating that the boiler is still within its maximum chlorine input level established during the previous performance testing (for sources that demonstrate compliance through performance testing), or submit the calculation of HCl emission rate using Equation 12 of §63.7530 demonstrating that the boiler is still meeting the emission limit for HCl emissions (for boilers that demonstrate compliance through fuel analysis).

b) Submit the calculation of mercury input, using Equation 8 of §63.7530 demonstrating that the boiler is still within its maximum mercury input level established during the previous performance testing (for sources that demonstrate compliance through performance testing), or submit the calculation of mercury emission rate using Equation 13 of §63.7530 demonstrating that the boiler is still meeting the emission limit for mercury emissions (for boilers that demonstrate compliance through fuel analysis).

c) If complying with the TSM emission limit, submit the calculation of TSM input, using Equation 9 of §63.7530 demonstrating the boiler is still within its maximum TSM input level established during the previous performance testing (for sources that demonstrate compliance through performance testing), or submit the calculation of TSM emission rate, using Equation 14 of §63.7530 demonstrating that the boiler is still meeting the emission limit for TSM emissions (for boilers that demonstrate compliance through fuel analysis).

(e) If the Permitee plans to burn a new type of fuel in an individual boiler and cannot demonstrate compliance with the maximum chlorine input operating limit using Equation 7 of §63.7530 or the maximum mercury input operating limit using Equation 8 of §63.7530, or the maximum TSM input operating limit using Equation 9 of §63.7530, include in the compliance report a statement indicating the intent to conduct a new performance test within 60 days of starting to burn the new fuel;

(f) A summary of any monthly fuel analyses or fuel specification analyses conducted to demonstrate compliance;

(g) If there were no deviations from any applicable emission limits or operating limits for the boiler, a statement that there were no deviations from the applicable emission limits or operating limits during the reporting period;

(h) If there were no deviations from the monitoring requirements including no periods during which the CMSs, including CEMS, COMS, and CPMS, were out of control as specified in §63.8(c)(7),



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a statement that there were no deviations and no periods during which the CMS were out of control during the reporting period;

(i) If a malfunction occurred during the reporting period, the report must include the number, duration, and a brief description for each type of malfunction and whether the malfunction caused or may have caused any applicable emission limitation to be exceeded;

(j) A description of actions taken during a malfunction of a boiler or associated air pollution control device or CMS to minimize emissions, including actions taken to correct the malfunction;

(k) The date of the most recent tune-up for the boiler; (l) The date of the most recent burner inspection; (m) For each reporting period, the compliance reports must include all of the calculated 30 day rolling

average values based on the daily CEMS (10 day rolling average values for CO CEMS when the limit is expressed as a 10 day instead of 30 day rolling average) and CPMS data;

(n) Statement by a responsible official with that official's name, title, and signature, certifying the truth, accuracy, and completeness of the content of the report;

(o) For each instance of startup or shutdown include the information required to be monitored, collected, or recorded according to the requirements of §63.7555(d);

(p) For each deviation from an emission limit or operating limit that occurs at an individual boiler not using a CMS to comply with that emission limit or operating limit, or from the work practice standards for periods if startup and shutdown, the compliance report must additionally contain: (i) A description of the deviation and which emission limit or operating limit or work practice

standard from which was deviated; (ii) Information on the number, duration, and cause of deviations (including unknown cause),

as applicable, and the corrective actions taken; and (iii) If the deviation occurred during an annual performance test, provide the date the annual

performance test was completed. (q) For each deviation from an emission limit, operating limit, and monitoring requirement by an

individual boiler using a CMS to comply with that emission limit or operating limit, the compliance report must additionally contain: (i) The date and time that each deviation started and stopped and description of the nature of

the deviation; (ii) The date and time each CMS was inoperative, except for zero (low-level) and high-level

checks; (iii) The date, time, and duration each CMS was out of control, including the information in

§63.8(c)(8); (iv) The date and time that each deviation started and stopped. (v) A summary of the total duration of the deviation during the reporting period and the total

duration as a percent of the total source operating time during that reporting period; (vi) A characterization of the total duration of the deviations during the reporting period into

those that are due to control equipment problems, process problems, other known causes, and other unknown causes;

(vii) A summary of the total duration of downtime for each CMS during the reporting period and the total duration of CMS downtime as a percent of the total source operating time during that reporting period;

(viii) A brief description of the source for which there was a deviation; and A description of any changes in CMSs, processes, or controls since the last reporting period for the source for which there was a deviation.



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H14. Electronic Reporting: All reports required by Table 9 of Subpart DDDDD must be submitted electronically to the EPA via the CEDRI. (CEDRI can be accessed through the EPA's CDX.) The appropriate electronic report in CEDRI for Subpart DDDDD must be used. Instead of using the electronic report in CEDRI for Subpart DDDDD, the Permitee may submit an alternate electronic file consistent with the extensible markup language (XML) schema listed on the CEDRI Web site (http://www.epa.gov/ttn/chief/cedri/index.html), once the XML schema is available. If the reporting form specific to Subpart DDDDD is not available in CEDRI at the time that the report is due, the Permitee must submit the report to the Administrator at the appropriate address listed in §63.13. The Permitee must begin submitting reports via CEDRI no later than 90 days after the form becomes available in CEDRI.

(a) Test Reports: The Permitee must electronically submit the results of the performance tests,

including any associated fuel analyses, using test methods supported by the EPA's Electronic Reporting Tool (ERT) as listed on the EPA's ERT Web site (http://www.epa.gov/ttn/chief/ert/index.html) within 60 days after the date of completing each performance test. Performance test data must be submitted in a file format generated through the use of EPA’s ERT or an electronic file format consistent with the XML schema listed on the EPA’s ERT Web site. If the Permitee claims that some of the performance test data being submitted is confidential business information (CBI), the Permitee must submit a complete file generated through the use of the EPA’s ERT or an alternate electronic file consistent with the XML schema listed on the EPA’s ERT Web site, including information claimed to be CBI, on a compact disc, flash drive, or other commonly used electronic storage media to the EPA. The electronic media must be clearly marked as CBI and mailed to U.S. EPA/OAPS/CORE CBI Office, Attention: Group Leader, Measurement Policy, Group, MD C404-02, 4930 Old Page Rd., Durham, NC 27703. The same ERT or alternate file with the CBI omitted must be submitted to the EPA via the EPA’s CDX as described above. Also, for data collected using test methods that are not supported by the EPA’s ERT as listed on the EPA’s ERT Web site at the time of the test, the Permitee must submit the results of the performance tests at the appropriate address listed in §63.13;

(b) Relative Accuracy Test Audit (RATA) Data: The Permitee must electronically submit the results of the performance evaluations for the continuous monitoring systems measuring relative accuracy test audit (RATA) pollutants that are supported by the EPA's ERT, to the EPA via the CEDRI. (CEDRI can be accessed through the EPA's CDX.) within 60 days after the date of completing each CEMS performance evaluation. Performance evaluation data must be submitted in a file format generated through the use of the EPA's ERT or an alternate file format consistent with the XML schema listed on the EPA's ERT Web site. If the Permitee claims that some of the performance evaluation information being transmitted is CBI, the Permitee must submit a complete file generated through the use of the EPA's ERT or an alternate electronic file consistent with the XML schema listed on the EPA's ERT Web site, including information claimed to be CBI, on a compact disc, flash drive, or other commonly used electronic storage media to the EPA. The electronic media must be clearly marked as CBI and mailed to U.S. EPA/OAPQS/CORE CBI Office, Attention: Group Leader, Measurement Policy Group, MD C404-02, 4930 Old Page Rd., Durham, NC 27703. The same ERT or alternate file with the CBI omitted must be submitted to the EPA via the EPA's CDX as described above. Also, for any performance evaluations of continuous monitoring systems measuring RATA pollutants that are not supported by the EPA’s ERT as listed on the ERT Web site at the time of the evaluation, you must submit the results of the performance evaluation at the appropriate address listed in §63.13; and



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(c) Compliance Reports: The Permitee must submit Compliance Reports required by Table 9 electronically using CEDRI. However, if a specific reporting form is not available in CEDRI at the time that the report is due, the Permitee must submit the report to the Administrator at the appropriate address listed in §63.13. At the discretion of the Administrator, the Permitee must also submit these reports, to the Administrator in the format specified by the Administrator.

[§64.7(d); §63.7505(d)(1); §63.7530(e); §63.7530(f); §63.7545(a), (b), (d), (e), (h)) to Subpart DDDDD of 40 CFR part 63]

H15. In response to an action to enforce the standards set forth in § 63.11201 you may assert an affirmative defense to a claim for civil penalties for violations of such standards that are caused by malfunction, as defined at 40 CFR 63.2. Appropriate penalties may be assessed if you fail to meet your burden of proving all of the requirements in the affirmative defense. The affirmative defense shall not be available for claims for injunctive relief.

(a) Assertion of affirmative defense. To establish the affirmative defense in any action to enforce such a standard, you must timely meet the reporting requirements in paragraph (b) of this section, and must prove by a preponderance of evidence that:

(1) The violation:

(i) Was caused by a sudden, infrequent, and unavoidable failure of air pollution control equipment, process equipment, or a process to operate in a normal or usual manner; and (ii) Could not have been prevented through careful planning, proper design or better operation and maintenance practices; and (iii) Did not stem from any activity or event that could have been foreseen and avoided, or planned for; and (iv) Was not part of a recurring pattern indicative of inadequate design, operation, or maintenance; and

(2) Repairs were made as expeditiously as possible when a violation occurred; and (3) The frequency, amount, and duration of the violation (including any bypass) were minimized to the maximum extent practicable; and (4) If the violation resulted from a bypass of control equipment or a process, then the bypass was unavoidable to prevent loss of life, personal injury, or severe property damage; and (5) All possible steps were taken to minimize the impact of the violation on ambient air quality, the environment, and human health; and (6) All emissions monitoring and control systems were kept in operation if at all possible, consistent with safety and good air pollution control practices; and (7) All of the actions in response to the violation were documented by properly signed, contemporaneous operating logs; and (8) At all times, the affected source was operated in a manner consistent with good practices for minimizing emissions; and (9) A written root cause analysis has been prepared, the purpose of which is to determine, correct, and eliminate the primary causes of the malfunction and the violation resulting from the malfunction event at issue. The analysis shall also specify, using best monitoring methods and engineering judgment, the amount of any emissions that were the result of the malfunction.

(b) Report. The owner or Permitee seeking to assert an affirmative defense shall submit a written report to the Administrator with all necessary supporting documentation, that it has met the requirements set forth in paragraph (a) of this section. This affirmative defense report shall be



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included in the first periodic compliance, deviation report or excess emission report otherwise required after the initial occurrence of the violation of the relevant standard (which may be the end of any applicable averaging period). If such compliance, deviation report or excess emission report is due less than 45 days after the initial occurrence of the violation, the affirmative defense report may be included in the second compliance, deviation report or excess emission report due after the initial occurrence of the violation of the relevant standard.

[40 CFR Part 63.11225] I. 40 CFR Part 98 Subpart A Subchapter C, Mandatory Greenhouse Gas

Reporting I1. The Permitee must submit annual reports for greenhouse gas emissions to the Environmental Protection

Agency. The first report shall begin with the first operating month of which the facility became subject to mandatory GHG reporting and ending on December 31 of that year. Each subsequent annual report must cover emissions for each calendar year beginning January 1 through December 31. The annual report must contain the following information:

a) Company/Facility name and address;

b) Date of report and beginning and ending dates of the reporting period; c) Date of submittal; d) Annual emissions of CO2, CH4, and N2O; and

e) A signed and dated certification statement provided by the designated representative of the owner/operator.

Each subject facility shall have one and only one designated representative who shall be responsible for certifying, signing, and submitting GHG reports to the EPA.

Compliance certifications shall be sent to EPA at the following address: Enforcement Division Air, Waste, and Toxics Branch U.S. EPA Region IX (ENF-2) 75 Hawthorne Street San Francisco, CA 94105

[40 CFR part 98 Subpart A]

and Statement of the Legal and Factual Basis

Documents

Transcript of and Statement of the Legal and Factual Basis