TECHNICAL MEMORANDUM TO: DATE: SUBJECT: Docket for Rulemaking, "Revised Cross-State Air Pollution Rule (CSAPR) Update for the 2008 Ozone NAAQS" (EPA-HQ-OAR-2020-0272) March 12, 2021 Assessing Non-EGU Emission Reduction Potential - Updated for Final Rulemaking Introduction Because there are many types of non-EGU emissions sources or units that emit NOx and many control technologies or combinations of control technologies for these units, there are many approaches to assessing emission reduction potential from non-EGU emissions sources/units. The EPA completed an assessment of emission reduction potential from these sources/units on a compressed schedule for the proposed and final rules, and this memorandum presents one approach. The remainder of this memorandum summarizes this approach to assessing non-EGU emission reduction potential and the related air quality impacts associated with the estimated reductions. The memorandum includes the following sections: Model and Methodology Used to Assess Non-EGU Emission Reduction Potential Background for Determining Source Size/Threshold for Non-EGU Emissions Sources Air Quality Impacts from Potential Non-EGU Emissions Reductions Further Verifying and Refining Estimated Non-EGU NOx Emissions Reduction Potential Detailed Verification and Review of Controls on Non-EGU Sources in Four States Conclusions of Verification and Review of Controls on Non-EGU Sources in Four States and Potential Emissions Reductions Caveats and Limitations of the Cost Analysis Control Installation Timing Request for Comment and Additional Information Model and Methodology Used to Assess Non-EGU Emission Reduction Potential For this assessment the EPA used the Control Strategy Tool (CoST) with the maximum emission reduction algorithm1-2-3, the Control Measures Database (CMDb)4, and the 2023 emissions projections based off of the 2016 NEIvl.5 We used the maximum emission reduction algorithm to estimate the largest quantity of potential emissions reductions from each emissions source or unit that might impact downwind receptors. CoST also includes a least cost algorithm that works to identify the set of controls that achieves a given percent reduction or target emissions reduction at the least cost. If that target emission reduction can't be achieved, then the resulting strategy will be, by definition, the maximum emissions reduction strategy. That is, the primary objective of the strategy will be focused on getting emissions reductions and not on lowering costs. 1 Further information on CoST, including a peer review of the tool, can be found at the following link: https://www.epa.gov/economic-and-cost-analvsis-air-pollution-regulations/cost-analvsis-modelstools-air-pollution. 2 We made a few minor changes to the CoST tool that are not reflected in this assessment. These changes could result in less than 30 additional tpy of potential emissions reductions and ~$2 million less in total costs. 3 The maximum emission reduction algorithm assigns to each source the single measure (if a measure is available for the source) that provides the maximum reduction to the target pollutant, regardless of cost. For more information, see the CoST User's Guide available at the following link: https://www.cmascenter.org/cost/documentation/3.5/CoST%20User's%20Guide/. 4 The CMDb is available at the following link: https://www.epa.gov/economic-and-cost-analvsis-air-pollution- regulations/cost-analvsis-modelstools-air-pollution. 5We used the 2023 inventory files with/7? in filename. 1 March 12, 2021 ------- For 2023, we summarized emissions reductions and average annual cost per ton for the 12 states identified from the 2023 air quality modeling and linked to downwind receptors.6The cost per ton values are annual costs and the estimated reductions are annual emissions reductions. In addition, in the assessment CoST applied controls to emissions units with a 150 tons per year (tpy) or more pre-control NOx emissions threshold (see section below on Background for Determining Source Size for Non-EGU Emissions Sources for options on NOx emissions thresholds). The results of the CoST run are summarized in an Excel workbook titled CoST Control Strategy - Max Reduction $10k 150 tpy cutoff 12 States Updated Modeling - No Replace - 07-23-2020. The 12 states in this assessment are the 12 states EPA proposes to find linked to a downwind receptor in 2021 in the proposed and final actions: IL, IN, KY, LA, MD, Ml, NY, NJ, OH, PA, VA, and WV. States across the U.S. reported NOx emissions from approximately 81,000 non-EGU facilities with point sources/units. Of these, states reported control information for facilities with one or more controls for approximately 17,000 non-EGU facilities, or 21 percent of these facilities.7 As such, this assessment of emission reduction potential from non-EGU emissions sources/units reflects a large degree of uncertainty because information about existing controls on emissions sources/units is missing for some states and incomplete for some sources.8 As an example, Table 1 below includes emissions totals, uncontrolled emissions, and percent of uncontrolled emissions using information from the 2017 NEI. Table 1. For Facilities w/>150 tpy of Emissions in the 2017 NEI - By State, Total NOx Emissions and Uncontrolled NOx Emissions (ANNUAL tpy) Total Uncontrolled Percent of State Emissions NOx Emissions Emissions (ANNUAL) (ANNUAL) Uncontrolled IL 17,655 16,773 95% IN 32,926 31,567 96% KY 19,121 16,445 86% LA 91,952 87,295 95% MD 6,354 2,339 37% Ml 35,399 34,459 97% NJ 3,753 2,261 60% NY 12,418 11,065 89% 6 In projecting emissions from 2016 to 2023, a percent emissions reduction can be applied to certain emissions units or sources without knowledge of specific controls for those units or sources - these reductions are labeled as being from unknown measures. Some of the units or sources included in this assessment had reductions estimated from unknown measures. In some cases, CoST removed those unknown measures and applied controls to some of those units or sources, resulting in approximately 20 thousand tons of emissions reductions estimated from the CoST-applied controls. Because CoST didn't know what the unknown measures were, CoST might be applying controls that aren't appropriate. In addition, in some cases CoST didn't have a control, so it didn't remove those unknown measures and apply controls. 7 This summary was based on a query of the 2017 NEI. 8 As noted, control information in the NEI is not consistently provided, but there are two columns that contain control information. The Control IDs has a number associated with a control device, and the % Reduction has the control efficiency. Either of these columns may be populated, or both, or none. In cases where only the Control IDs column is populated and we don't know what the control efficiency is, CoST treats the source/unit as uncontrolled and applies a replacement control. We are likely overestimating potential emissions reductions in these cases. For the 12 states in this assessment there are 488 possible emissions sources/units to control with pre-control emissions >150 tpy. Of these, 130 have something in the Control IDs column (which means CoST may be inappropriately applying a control), 129 have something in the % Reduction column, and only 28 have both. 2 March 12, 2021 ------- Total Uncontrolled Percent of State Emissions NOx Emissions Emissions (ANNUAL) (ANNUAL) Uncontrolled OH 35,186 33,891 96% PA 31,680 30,437 96% VA 19,394 14,317 74% WV 11,507 11,255 98% From the CoST run, Table 2 below summarizes potential emissions reductions by industry sector and the range of annual cost per ton estimates across units to which CoST applied controls in each industry sector. This summary can be found in a worksheet titled Control Summary-by NAICS (2) in an Excel workbook titled Control Summary - Max Reduction $10k 150 tpy cutoff 12 States Updated Modeling - No Replace - 05-18-2020. Table 2. Annual NOx Emission Reduction Potential and Cost Per Ton Ranges by Industry Sector in 2023 for Twelve States NOx Emission Reduction Annual Cost/Ton Range NAICS Title Potential (ANNUAL tpy) (2016$) Chemical Manufacturing 11,577 $914 - $9,703 Nonmetallic Mineral Product Manufacturing 19,092 $64 - $4,204 Petroleum and Coal Products Manufacturing 4,363 $2,028- $8,911 Pipeline Transportation 32,593 $721 - $8,333 Paper Manufacturing 2,058 $3,796- $8,911 Other 1,346 $212 - $7,963 Utilities 392 $1,279 - $6,046 Primary Metal Manufacturing 6,392 $1,395 - $9,495 Oil and Gas Extraction 2,484 $634- $5,683 The EPA categorized the CoST results for the control technologies that comprise approximately 92 percent of the total estimated potential emissions reductions from the non-EGU sources/units in the 2023 projected inventory with 150 tpy or more of NOx emissions in the 12 linked states; the technologies and related emissions sources include: a. Layered combustion (lean burn IC engines - natural gas), b. NSCR or layered combustion (industrial natural gas IC engines, Source Classification Codes (SCCs) with technology not specified), c. SCR (glass manufacturing - container, flat & pressed, ICI boilers, IC engines (oil-fired and natural gas)), d. SNCR (cement manufacturing - dry and wet kilns, municipal waste combustors), and e. Ultra-low NOx burner and SCR (ICI boilers). The EPA incrementally included additional details in these summaries, including: a. Emissions source group (ICI boilers, IC engines, cement kilns, glass furnaces), b. State, and c. Industry sector (cement/glass manufacturing, paper manufacturing, pipeline transportation). 3 March 12, 2021 ------- In addition, we calculated a weighted average cost per ton for each technology, plotted the weighted average costs, and observed a clear breakpoint in the curve at $2,000 per ton.9 This identified two tranches of potential emissions reductions (see Figure 1 below).10 The summaries discussed above and the figure below are also available in the Excel workbook titled Control Summary - Max Reduction $10k 150 tpy cutoff 12 States Updated Modeling - No Replace - 05-18-2020. Figure 1. Cumulative NOx Emission Reduction Potential (annual tons) by Weighted Average Cost Per Ton (annual cost per ton) for Control Technologies in 2023 ฃ O 7,000 6,000 5,000 o " vv 4,000 gp id < o -a 3,000 op 'aj 2,000 1,000 0 $6,631 $5,675 $5,090 Layered Combustion NSCRor Layered Combustion Ultra-low NOx Burner and SCR $1,9)6? $1,917 SCR SNCR 10,000 20,000 30,000 40,000 50,000 Cumulative NOx Reductions (tons) 60,000 70,000 80,000 Dotted vertical line separates the two tranches. For the technologies above, we then: a. Within each technology, further organized by emissions source group, and b. Looked closer at cost per ton within these technology/source group "bins". These summaries are available in the Excel workbook with the CoST run results titled CoST Control Strategy - Max Reduction $10k 150 tpy cutoff 12 States Updated Modeling - No Replace - 07-23-2020. The first tranche of potential emissions reductions had a weighted average annual cost of approximately $2,000 per ton and a cost range from ~$64 per ton - ~$5,700 per ton and included the following technology/source groupings ii. a. SCR - glass manufacturing - container, flat & pressed, IC engines, oil-fired and natural gas (in pipeline transportation and oil & gas extraction industry sectors), and b. SNCR - cement manufacturing - dry and wet kiln, municipal waste combustor. 9 By technology, the Agency calculated a weighted average cost per ton so that some of the outlier cost per ton values did not disproportionately impact the "average" value used to plot the curve. 10 This assessment assumes annual cost per ton values. To consider whether the tranches would change using ozone season cost per ton values, we divided total annual cost by ozone season tons. The technology/source groupings stay the same, and the ozone season cost per ton values are higher. 11 For the emissions unit estimated to generate emissions reductions at $64 per ton, the emissions and cost estimates were incorrect. The 2023 projected emissions for the unit were significantly overestimated as a result of a growth factor the EPA received for these emissions from a multi-jurisdictional partner organization. Further, the equation used to estimate the cost was mis-specified in CoST, and the true annual cost is likely on the order of $800 per ton. 4 March 12, 2021 ------- See Table 3 for details - note that the potential emissions reductions are annual tons not ozone season tons. Additional details on this first tranche, including the potential emissions reductions and number of emissions units by state are shown in Table 4. To analyze potential emissions reductions in step 3 of the 4-step framework, we determined that the potential emissions reductions in tranche 1 are potentially relatively cost-effective because the $2,000 cost per ton for non-EGU emissions reductions is similar to the control stringency for EGUs represented by up to $1,800 per ton (see section below on Further Verifying and Refining Estimated Non-EGU NOx Emissions Reduction Potential for additional discussion). Table 3. Annual NOx Emission Reduction Potential and Annual Cost Per Ton Range by Technology and Source Group for Tranche 1 in 2023 Technology Source Group NOx Emission Reduction Annual Cost/Ton Potential (ANNUAL tpy) Range (2016$/ton) SCR SCR SCR Ammonia - \G-Z;red Reformers Glass Manufacturing - Container, Fiat & Pressed* 15,570 8,343 2,113 $64-54,200 $1,200-$5,700 $3,300 IC Engines - Natural Gas, Oil Iron & Steei - in-Process SCR Combustion - Bituminous Coal Cement Manufacturing - Dry and Wet 154 $4,200 S\CR S\CR Municipal Waste Combustors 3,711 145 30,5 37 $1,300 - $2,000 $1,900 Total * installing controls on glass furnaces typically involves a major update or retrofit every 8-10 years. This cycle could impact the potential emissions reduction estimates and costs. 5 March 12, 2021 ------- Table 4. Annual NOx Emission Reduction Potential by Technology, State, and Source Group for Tranche 1 in 2023 NOx Emission Reduction State Number of Units Potential (ANNUAL tpy) Technology Source Group Ammonia - NG-Fired Reformers SCR Louisiana 5 Glass Manufacturing - Container, Flat & Pressed 2,113 SCR Illinois 4 1,113 SCR Indiana 3 652 SCR Louisiana 3 535 SCR New York 3 1,162 SCR Ohio 3 973 SCR Pennsylvania 6 10,804 SCR Virginia 2 331 IC Engines - Ntitural Gas, Oil SCR Illinois 1 274 SCR Indiana 5 2,024 SCR Louisiana 7 3,850 SCR Michigan 5 1,514 SCR Ohio 1 131 SCR Virginia 2 1,040 Iron & Steel - In-Process Combustion - Bituminous Coal SCR Indiana 1 Cement Manufacturing - Dry and Wet 154 SNCR Indiana 8 2,236 SNCR Maryland 1 149 SNCR Michigan 13 1,326 Municipal Waste Combustors SNCR Maryland 1 145': The second tranche of potential emissions reductions had a weighted average annual cost range from approximately $5,000 per ton to $6,600 per ton and a cost range from ~$1,400 per ton - ~$9,700+ per ton and primarily included the following technology/source groupings: a. Layered Combustion - lean burn IC engines - natural gas (in pipeline transportation and oil & gas extraction industry sectors), b. NSCR or Layered Combustion - industrial natural gas IC engines, SCCs with technology not specified (in pipeline transportation and oil & gas extraction industry sectors), and c. Ultra-low NOx burner and SCR - ICI boilers (in paper manufacturing, petroleum and coal products manufacturing, chemical manufacturing, and primary metal manufacturing industry sectors). See Table 5 for details - note that the potential emissions reductions are annual tons, not ozone season tons. Additional details on this second tranche, including the potential emissions reductions and number of emissions units by state are shown in Table 6. To analyze potential emissions reductions in step 3 of the 4-step framework, we made no determination as to whether the potential emissions reductions in tranche 2 are cost-effective 6 March 12, 2021 ------- because we assumed the up to $1,800 per ton cost threshold for reductions from EGU sources was an equivalent cost threshold for comparison. The underlying details and summary Tables 3 through 6 are available in the Excel workbook titled CoST Control Strategy - Max Reduction $10k 150 tpy cutoff 12 States Updated Modeling - No Replace - 07-23-2020. Table 5. Annual NOx Emission Reduction Potential and Annual Cost Per Ton Range by Technology and Source Group for Tranche 2 in 2023 Technology Layered Combustion Source Group Lean Bum ICE - NG Industrial NG ICE, SCCs with technology not specified NOx Emission Reduction Potential Annual Cost/Ton (ANNUAL tpy) Range (2016$/tori) 10,963 $5,500 - $6,600 iVSCR or Layered Combustion Ultra-low NOx Burner and SCR ICI Boiiers 13,176 17,341 $1,400 - $9,700* $6,400 - $3,300 Total * Weighted average cost/ton is '-$5,100. 7 March 12, 2021 ------- Table 6. Annual NOx Emission Reduction Potential by Technology, State, and Source Group for Tranche 2 in 2023 State Numberฎ# Units NOx Emission Reduction Potential (ANNUALtpy) Technology Source Group Lean Bum ICE - NG Layered Combustion Illinois 1 1,444 Layered Combustion Indiana 10 2,376 Layered Combustion Kentucky 4 752 Layered Combustion Louisiana 3 944 Layered Combustion Michigan 2 307 Layered Combustion New York 1 324 Layered Combustion ~Mo- 8 1,521 Layered Combustion West Virginia 14 3.294 Industrial NG ICE, SCCs with technology not specified NSCR or Layered Combustion Illinois 10 1,708 NSCR or Layered Combustion Kentucky 1 417 NSCR or Layered Combustion Louisiana 31 6,731 NSCR or Layered Combustion Ohio 23 4,319 ICI Boilers Ultra-tow NOx Burner and SCR Illinois 2 387 Ultra-tow NOx Burner and SCR Indiana 9 3,810 Ultra-low NOx Burner and SCR Kentucky 3 905 Ultra-low NOx Burner and SCR Louisiana 25 7,119 Ultra-low NOx Burner and SCR New York 4 1,343 Ultra-tow NOx Burner and SCR Ohio 7 2,059 Ultra-low NOx Burner and SCR Pennsylvania 3 748 Ultra-low NOx Burner and SCR West Virginia 3 969 Background for Determining Source Size/Threshold for Non-EGU Emissions Sources In assessments of non-EGU emission reduction potential that provided supplemental data for review and comment in previous interstate transport rulemakings, we assessed units with pre-control NOx emissions > 100 tpy, which is the major source threshold for moderate ozone nonattainment areas. In addition, in the 2016 Final Technical Support Document (TSD)for the Final Cross-State Air Pollution Rule for the 2008 Ozone NAAQS, Assessment of Non-EGU NOx Emission Controls, Cost of Controls, and Time for Compliance Final TSD, EPA ran CoST for non-EGU point sources for the 37 eastern U.S. states with NOx emissions of greater than 25 tons per year in 2017. This assessment was prepared for the purpose of presenting and seeking comment on the then currently available information on emissions and control measures for emissions sources/units of NOx other than EGUs; it was not prepared for use in conducting a rigorous regulatory analysis under the step 3 multi-factor test, nor for establishing specific emissions limits. Further, this 2016 assessment relied primarily on NEI data that, for reasons explained at proposal of the CSAPR Update, was not considered to be of the quality on which EPA could base regulatory conclusions regarding (a) the need for emissions reductions, and (b) specific emissions control technologies. 8 March 12, 2021 ------- The assessment of potential emissions reductions from non-EGU sources/units included in the Revised CSAPR Update proposal was prepared with data and methods for use in making regulatory decisions (e.g., establishing NOx emissions limits on non-EGU emissions sources/units). The assessment was independent of any previous assessments. For this assessment, the EPA included units with pre-control NOx emissions > 150 tpy, which is an emissions threshold that represents a comparable size to 25 MW for EGUs used in prior interstate transport rulemakings. To derive this emissions threshold, we used emissions expected from an average 25 MW EGU unit operating at a median heat rate, emission rate, and capacity factor for a coal-fired unit. A description of this derivation is below. The CSAPR trading program is currently restricted to EGU sources greater than 25 MW electric generating capacity in the regulation. Since non-EGU sources/units are not all rated in electric generating capacity, we estimated an equivalent threshold for these sources/units on an annual NOx emissions basis. We estimated that 150 tons of NOx emissions per year is a reasonable approximation for the annual NOx emissions from a typical 25 MW EGU. As mentioned above, this estimate represents a generic 25 MW EGU and relied on assumptions of three factors: heat rate, capacity-factor, and NOx emissions rate. To develop an estimate for each of these factors, we evaluated a sample of EGUs ranging from 25 MW - 30 MW, which represents the smallest EGUs currently included in the CSAPR trading program. This sample included nine units from the following six plants (ORIS codes): 50931, 2790, 50611, 50835, 57046, 2935. We excluded one outlier unit with a NOx rate that was nearly three times higher than the next highest NOx rate. We calculated the median and average heat rate and NOx rate for the remaining eight units based on the assumptions included in NEEDS v6 rev: 3-26-2020. We calculated the median and average annual capacity factor based on Air Markets Program data reported to EPA in 2019. These values are summarized below. Median Average Heat Rate (Btu/kWh) 12,140 12,291 NOx Rate (Ibs/MMBtu) 0.18 0.23 Capacity Factor (%) 61% 61% The estimated annual emissions from a typical 25 MW unit based on the assumptions above ranges from about 141 annual tons (median values) to 188 annual tons (average values). Given the small sample size, we believe the median values are more representative than average values. Therefore, we estimated that 150 tons per year is a reasonable approximation of the annual NOx emissions at a typical 25 MW EGU. Since non-EGUs sources/units are not universally rated in MW electric generating capacity, we believe that NOx emissions of 150 tons per year is an equivalent threshold to a typical 25 MW EGU for use in this assessment. Air Quality Impacts from Potential Non-EGU Emissions Reductions Tables 7 and 8 below provide estimates of the air quality impacts at the Westport, CT receptor of the potential non-EGU emissions reductions in linked upwind states. We chose the Westport site for this assessment because it is likely the only site to remain a receptor during the time period when non-EGU controls could be implemented, assuming those controls take longer than 18 months to install. The results for Westport, CT are representative of the impacts for other coastal Connecticut receptors. In Tables 7 and 8 below, the air quality data are provided for individual upwind states and by industry sector, source category, and technology for all linked upwind states combined. Tables 7 and 8 (and the tables that follow) include potential emissions reductions in units of ozone season tons for appropriate comparison to potential EGU emissions reductions. 9 March 12, 2021 ------- The estimated air quality impacts of the potential non-EGU emissions reductions are based on multiplying the estimated emissions reductions by the parts per billion (ppb) per ton values for each linkage.12 The ppb per ton values were derived from the state-by-state contribution modeling. Since the contribution modeling included emissions from all anthropogenic sources in each state, rather than just non-EGUs, the ppb per ton values used for this analysis introduce some degree of uncertainty in the results. In addition, because the precursor emissions in the New York City portion of New York state are a large portion of the total state emissions and given the proximity of the coastal CT receptors to New York City, the contributions from the state of New York in the modeling largely reflect the contribution from emissions within New York City and adjacent areas of southern New York. As such, the ppb per ton values for New York based on the modeling are likely to overstate, by a large amount, the ppb per ton values from sources outside of New York City. In this assessment, the estimated impacts at Westport and other coastal CT receptors of the potential non-EGU emissions reductions in New York state are likely overstated because the ppb per ton values used in the calculations are dominated by the contributions from New York City, whereas the potential non-EGU emissions reductions are from emissions units in the western part of the state. Also note that there were no potential NOx emissions reductions from New Jersey because the projected 2023 emissions inventory did not include individual non-EGU point sources/emissions units in New Jersey with pre-control NOx emissions greater than 150 tpy for which CoST had applicable control measures.13 Table 7. Non-EGU Emissions in 2023 and PPB Reductions at Westport, Connecticut for Individual Linked Upwind States Linked States OS NOx Reductions PPB Reduction Pennsylvania 4,813 0.144 New York 1,179 0.107 Ohio 3,751 0.048 Indiana 4,981 0.037 West Virginia 2,117 0.029 Michgan 1,311 0.013 Illinois 2,053 0.008 Kentucky 864 0.007 Virginia 571 0.006 Maryland 123 0.003 Total 21,764 0.401 12 We applied the calibration factor for this receptor that is used in the Air Quality Assessment Tool (AQAT) for calculating the ozone impacts of EGU emissions reductions. The AQAT is discussed and documented in the Ozone Transport Policy Analysis TSD for the proposal. Calibration factors are intended to account for the non-linear response of ozone concentrations to NOx emissions reductions. 13 Note that total NOx emissions at the facility-wide level in this analysis are likely much larger than NOx emissions at the emissions source/unit level, and facilities often have several individual emissions units. In New Jersey there are facilities with total NOx emissions greater than 150 tpy. We did not, however, identify any individual emissions units at those facilities with pre-control NOx emissions greater than 150 tpy for which CoST identified applicable control measures. 10 March 12, 2021 ------- Table 8. Non-EGU Emissions in 2023 and PPB Reductions at Westport, Connecticut by Industry Sector or Source Category, Technology, and Weighted Average Cost Per Ton from Linked Upwind States14 Sector Technology OS NOx Reductions PPB Red uction Approx. $2,OO0/tDn Glass Ma nufacturing: SCR 5,780 0.189 Lean Burn IC Engs: SCR 2,710 0.025 Iron a Steel: 5CR 54 0.000 Cement: 5NCR 1,546 0.014 MWC: 5NCR 61 0.001 SubTotal 10,161 0.230 Approx. $5,000 to $6,600/ton Lean Burn ICEng: LCornb 4,040 0.052 Industrial Natural Gas: N5CR/L Comb 2,685 0.027 ICI Boilers: Ultra-low NOx Burner/SCR 3,700 0.092 SubTotal 10,425 0.172 Total 20,586 0.401 Further Verifying and Refining Estimated Non-EGU NOx Emissions Reduction Potential Because information for existing controls on non-EGU emissions sources/units is missing in the 2016 base year inventory for some states and incomplete for some sources, the EPA went through a process to further verify existing control information and refine the NOx emission reduction potential estimated by CoST, the CMDb, and the 2023 projected inventory in Tables 3 through 6 above. The steps the EPA took, discussed in more detail below, include: Considered the air quality impacts by state and focused on upwind states with the largest estimated potential air quality impacts from potential non-EGU emission reductions; Assumed that the potential reductions in tranche 1 were potentially cost-effective because tranche l's weighted average cost of $2,000 per ton (2016 dollars) is similar to the control stringency for EGUs represented by up to $1,800 per ton; Looked at potential emissions reductions in tranche 1 that were estimated to cost less than $2,000 per ton; and For those potential reductions in tranche 1 that were estimated to cost less than $2,000 per ton, reviewed online facility permits and industrial trade literature to verify and determine if the estimated emissions reductions may be actual, achievable emissions reductions or if the estimated emissions reductions were associated with emissions units that are already controlled. First, we considered the potential ppb impacts by state in Table 7 and prioritized the verification and refinement of the NOx emission reduction potential for a subset of the states with the largest estimated potential air quality impacts. We reviewed potential controls and estimated emissions reductions in Pennsylvania, New York, Ohio, Indiana, and West Virginia. The EPA identified these states using an estimate of 0.02 ppb as a threshold for air quality improvement that may be obtained from reductions from non-EGUs in each state. The Agency is not applying a 0.02 ppb impact threshold as a step in the Step 3 multi-factor test. Rather, this threshold value allowed the Agency to better target its verification efforts (i.e., online permit review) toward the potentially effective 14 After the initial assessment of non-EGU reduction potential, we further reviewed information related to applying SCR to IC engines (discussed below). CoST estimated the control cost inappropriately, as it applied a cost equation to a source much larger than the predictive range of the equation. In such cases, CoST should apply a cost per ton value, which would be above the $2,000 per ton threshold for cost-effectiveness. As a result, we removed these units from further consideration. 11 March 12, 2021 ------- states for non-EGU NOx emissions reductions. For the final rule, EPA extended its verification and refinement process for tranche 1 to additional linked states, including Maryland, Michigan, and Virginia.15 Next, to continue analyzing potential emissions reductions in step 3 of the 4-step framework, we determined that the potential reductions in tranche 1 (Table 3 above) were potentially relatively cost-effective because the $2,000 cost per ton cost for reductions from non-EGU sources/units is similar to the control stringency for EGUs represented by up to $1,800 per ton. We made no determination as to whether the potential emissions reductions in tranche 2 were cost-effective because we assumed the up to $1,800 per ton control stringency for proposed reductions from EGU sources/units was an equivalent cost threshold for comparison.16 Note that between the Revised CSAPR Update proposed and final rules, we reviewed the potential controls for emissions sources/units in tranche 2 (Table 5 above). The emissions reductions from tranche l17 are in the section of Table 8 with the weighted average cost of $2,000 per ton (2016$), and the emissions reductions from tranche 2 are in the section with the weighted average cost range of $5,000 to $6,600 per ton. Tranche 1 includes: 1. SCR: a.glass manufacturing - container, flat & pressed, b.lC engines - natural gas, oil (in pipeline transportation and oil & gas extraction industry sectors), and 2. SNCR: a.cement manufacturing - dry and wet kilns, b.municipal waste combustors. The total estimated potential emissions reductions from non-EGU sources/units in Pennsylvania, New York, Ohio, and Indiana in tranche 1 were 7,556 ozone season tons. Note that West Virginia dropped out because as indicated below CoST estimated control costs for two IC engines inappropriately, and CoST did not apply cost-effective controls to any other emissions units in the state. Below we note exceptions where in tranche 1 CoST applied cost- effective controls that were not included in the results. CoST applied controls to two IC engines in West Virginia for additional potential emissions reductions of 341 ozone season tons (in tranche 1 CoST did not apply controls to any other emissions units in the state). However, CoST estimated the control cost inappropriately, as it applied a cost equation to a source much larger than the predictive range of the equation. In such cases, CoST should apply a cost per ton value, which in this instance would be above the $2,000 per ton threshold for cost-effectiveness. As a result, it was determined that there are no actual controls available at the selected level of cost-effectiveness for these units. We reviewed the permits for these units - the permit indicates that the units currently do not have control devices installed but do require periodic tune-ups and performance tests. CoST applied a control to an IC engine in Indiana for additional potential emissions reductions of 292 ozone season tons. Like the West Virginia controls, the cost of this control was underestimated for a source of this size, and the cost per ton for this source is above the threshold for cost-effectiveness. We reviewed the permit for this unit - the permit indicates that the IC engine currently does not have a control device installed but does require performance tests and a preventive maintenance plan. 15 The verification efforts did not include Illinois because their permits were not available online. Also, EPA did not review the potential controls for Kentucky because CoST did not identify applicable control measures for any emissions sources/units in the state; as such, there were no potential NOx emission reductions to verify. 16 Details on these tranches can be found in the Summary SCR and SNCR and Summary Other Technologies worksheets in the CoST Control Strategy - Max Reduction $10k 150 tpy cutoff 12 States Updated Modeling - No Replace - 07-23-2020 Excel workbook. 17 In tranche 1 the cost per ton ranges from ~$64 per ton - ~$5,700 per ton. 12 March 12, 2021 ------- Next, we looked at the potential emissions reductions in tranche 1 that were estimated to cost <$2,000 per ton, which were 6,346 ozone season tons, or 84 percent of the estimated reductions in tranche 1 in these states; the remaining 16 percent of estimated reductions, or 1,210 ozone season tons, was above the $2,000 per ton threshold. The steps taken to verify and refine the NOx emission reduction potential information were based first on technology application and related costs (as detailed above in the section on Model and Methodology for Assessing Non-EGU Emission Reduction Potential), then on a representative sample of states, and then on likely cost-effective reductions (i.e., reductions < $2,000 per ton) in those states, which led to key industry sectors; we did not directly select or eliminate key industry sectors to review for applicability or controls. In the review of the potential controls in tranche 1 for Pennsylvania, New York, Ohio, and Indiana, we concluded that the likely cost- effective emissions reductions were from SCR applied to glass furnaces and SNCR applied to cement kilns.18 Please see the additional discussion on these estimated emissions reductions in the section below titled Conclusions on Verification and Review of Controls on Non-EGU Sources in Four States and Potential Emissions Reductions. Between the Revised CSAPR Update proposed and final rules, we reviewed the potential controls for emissions sources/units in tranche 1 for most of the remaining five states in Table 7. We reviewed the potential controls for emissions sources/units in Maryland, Michigan, and Virginia; we did not review the potential controls for emissions sources/units in Illinois because their permits were not available online, and we did not review the potential controls for sources/units in Kentucky because CoST did not identify applicable control measures for any emissions sources/units in the state. In tranche 1, we originally estimated 664 ozone season tons of likely cost- effective emissions reductions from these four states (excluding Kentucky).19 This additional review identified approximately 62 ozone season tons out of the estimated 664 ozone season tons that are from sources/units already controlled, leaving an estimated 602 ozone season tons of likely cost-effective emissions reductions from these states. Detailed Verification and Review of Controls on Non-EGU Sources in Four States After determining it was appropriate to verify the potential emissions reductions that were estimated to cost <$2,000 per ton, we took the additional step of verifying and refining the information on potential controls for emissions sources/units in tranche 1 for Pennsylvania, New York, Ohio, and Indiana. Note that West Virginia dropped out because CoST estimated control costs for two IC engines inappropriately, and CoST did not apply likely cost-effective controls to any other emissions units in the state. To verify and refine the information, we reviewed facilities' online Title V permits for likely cost-effective emissions reductions associated with SCR applied to glass furnaces and SNCR applied to cement kilns, and also reviewed industrial trade literature for these facilities and their parent companies. These permit and industrial trade literature reviews were completed as of July 31, 2020.20 By state, in Tables 9 through 12 below, we include information on 20 emissions units at glass manufacturing and cement manufacturing facilities including the facility name, NEI Unit ID, type of emissions unit, existing NOx control, NOx monitoring device, type of fuel used, and related notes. Of the 20 emissions units, 10 units either (i) 18 Note that for non-EGU emissions sources/units not all industry sectors are present in each of the 12 states. 19 Please refer to the Excel workbook with the CoST run results titled CoST Control Strategy - Max Reduction $10k 150 tpy cutoff 12 States Updated Modeling - No Replace - 07-23-2020 for more details on the estimated emissions reductions. 20 As noted above, between the Revised CSAPR Update proposed and final rules, we also reviewed the potential controls for emissions sources/units in tranche 1 for additional linked states in Table 7 - Maryland, Michigan, and Virginia. We did not review the potential controls for emissions sources/units in Illinois because their permits were not available online, and we did not review the potential controls for sources/units in Kentucky because CoST did not identify applicable control measures for any emissions sources/units in the state. 13 March 12, 2021 ------- have controls and monitors (primarily CEMS) already, (ii) are installing controls and CEMS or consolidating operations in the next few years as a result of recent consent decrees issued as part of the EPA's New Source Review Air Enforcement Initiative, (iii) have shut down, or (iv) are planning to shut down by 2023. In addition, we find that most of the emissions units are natural gas-fired, though a few of the cement kilns can fire either coal or oil. Based on information collected through the permit review, we believe the units in categories (i) and (iii) don't present an opportunity to generate emissions reductions as part of this analysis and should be removed from further consideration. With respect to categories (ii) and (iv), for purposes of a focused analysis of potential cost- effective non-EGU emissions reductions, we excluded these units from further consideration. Reviewing online facility permits does not always resolve outstanding questions. Permits can be 100 pages or more in length with detailed information about a facility and the units at the facility, and the accuracy and extent of information can vary by state. Matching NEI information to information in the permit is not always straight forward. For example, the NEI Unit IDs don't always match the unit ID information in the permit and even more research or refinement is needed. 14 March 12, 2021 ------- Table 9. Pennsylvania Glass Manufacturing Facilities Facility Name/NEI Unit ID21 Ultimate Parent Company Type of Emissions Unit County 2023 Projected NOx Emissions Estimated Reductions (OS Tons) from SCR Existing NOx Control NOx Monitoring Device/ Technique Fuel Used by Furnace Other Notes Status of Estimated Reductions22 Ardagh Glass Inc/Port Allegany Pit (NEI Unit ID 19110913) Ardagh Group S.A. Container Glass: Melting Furnace McKean 152 47.43 LNB + OEAS CEMS Natural Gas 194.73 tons annual emissions limit Remove from consideration (Already controlled) Vitro Flat Glass LLC/Carlisle (NEI Unit ID 18725313)23 Vitro, Inc. Flat Glass: Melting Furnace Cumberland 10,514 3,285.65 No Control CEMS Natural Gas/Oil #2 (permitted for both fuels; natural gas is the typical fuel used) Emissions limit of 26.75 lb/ton glass produced Uncertain - see notes below (NEI discrepancy) Vitro Flat Glass LLC/Carlisle (NEI Unit ID 18725413) Vitro, Inc. Flat Glass: Melting Furnace Cumberland 1,236 386.27 SCR CEMS Natural Gas/Oil #2 (permitted for both fuels; natural gas is the typical fuel used) Emissions limit of 7.0 lb/ton glass produced Remove from consideration (Already controlled) 21 Pennsylvania's online permits are available at the following link: http://cedatareporting.pa.gov/Reportserver/Pages/ReportViewer.aspx7/Public/DEP/AQ/SSRS/AQ Permit Docs. 22 The category indicated in italics and parentheses is associated with the categories in Table 13 below. 23 The cost per ton and potential emissions reductions for this emissions unit reflect a high degree of uncertainty. The uncertainty comes from the following two sources: (i) discrepancies between the underlying information for this unit in the 2023 projected inventory and other emissions data, and (ii) the equation in CoST that is used to estimate the emissions reductions and cost per ton value. In the 2023 projected inventory, the reported pre-control emissions are much larger than what appears in the PA Air Emissions Report (http://www.depgreenport.state.pa.us/powerbiproxv/powerbi/Public/DEP/AQ/PBI/Air Emissions Report) for this facility and significantly larger than any other glass furnace in this analysis, and the projected inventory does not show a control on any unit at this facility, even though a review of the permit indicates that one unit does have a control. Lastly, the equation used to estimate the costs is misspecified and yields artificially low cost per ton estimates for a source this large. The default cost per ton value from CoST for this source is roughly $800/ton (2016$) and is still within the range of costs in tranche 1. 15 March 12, 2021 ------- Facility Name/NEI Unit ID21 Ultimate Parent Company Type of Emissions Unit County 2023 Projected NOx Emissions Estimated Reductions (OS Tons) from SCR Existing NOx Control NOx Monitoring Device/ Technique Fuel Used by Furnace Other Notes Status of Estimated Reductions22 Pittsburgh Glass Works/Meadville Works 824'25 (NEI Unit ID 19025613) Vitro, Inc. Flat Glass: Melting Furnace Crawford 1,739 543.49 No Control CEMS Natural Gas 766.5 tons annual emissions limit Uncertain - closed a line on June 10, 2020 (Shutdown) Guardian Ind Corporation/Jefferson Hills (NEI Facility ID 2989611) Allegheny 512 159.93 Facility closed at end of 2015. Remove from consideration (Shutdown) Subtotal 4,422.77 24 Vitro acquired this facility in 2017 - https://www.post-gazette.com/business/career-workplace/2020/04/13/Meadville-Vitro-glass-COVID-19-lavoffs-pennsvlvania/stories/202004130Q94. 25 This facility shut down one of its two production lines effective June 10, 2020. The company stated that it will be too expensive to rebuild the production line. https://www.glassmagazine.com/news/vitro-shut-down-float-line-automotive-glass https://www.post-gazette.com/business/career-workplace/2020/04/13/Meadville-Vitro-glass-COVID-19-lavoffs-pennsvlvania/stories/202004130Q94 26 https://www.post-gazette.com/business/pittsburgh-companv-news/2015/06/24/Guardian-lndustries-to-close-Jefferson-Hills-plant-more-than-100-face-lavoffs- pittsburgh/stories/201506240183 https://www.wtae.com/article/guardian-industries-closing-iefferson-hills-plant-idling-114/7472247 16 March 12, 2021 ------- Table 10. New York Glass Manufacturing Facilities Facility Name/NEI Ultimate Type of County 2023 Estimated Existing NOx Fuel Used Other Status of Unit ID27 Parent Emissions Projected Reductions NOx Monitoring by Furnace Notes Estimated Company Unit NOx Emissions (OS Tons) from SCR Control Device/ Technique Reductions28 Furnace #1 Possible has an (Possible annual emissions emissions reductions) limit of 1.2 Two lb NOx/ton Anchor Glass Container Corp (NEI Unit ID 2854113) Anchor Glass Container Corp Container Glass: Melting Furnace Chemung 450 140.63 furnaces - Furnace #1 - SCR; Furnace #2 - no control CEMS Natural Gas of glass produced. Furnace #2 has an annual emissions limit of 4.5 lb NOx/ton of glass produced. Furnace A Possible has an (Possible annual emissions emissions reductions) Two furnaces - No controls indicated limit of 4.0 Owens Brockway Glass Container Inc 0-1 Glass, Inc. Container Glass: Melting Cayuga 309 96.69 CEMS Natural Gas lb NOx/ton of glass (NEI Unit ID 2863113) Furnace produced. Furnace B has an annual emissions limit of ? 27 New York's online permits are available at the following link: http://www.dec.nv.gov/dardata/boss/afs/issued atv.html. 28 The category indicated in italics and parentheses is associated with the categories in Table 13 below. 17 March 12, 2021 ------- Guardian Geneva Float Glass Facility29 (NEI Unit ID 18725413) Koch Industries, Inc. Flat Glass: Melting Furnace Ontario 790 246.83 SCR CEMS Natural Gas Annual emissions limit of 770 tons Remove from consideration (Already controlled) Subtotal 484.15 Table 11. Ohio Glass Manufacturing Facility Facility Name/NEI Ultimate Type of County 2023 Estimated Existing NOx Fuel Used Other Notes Status of Unit ID30 Parent Emissions Projected Reductions NOx Monitoring by Furnace Estimated Company Unit NOx Emissions (OS Tons) from SCR Control Device/ Technique Reductions31 Furnace #1 Uncertain - has annual recent stack emissions test shows limit of 364.7 emissions well Two tons - a below permit furnaces - recent stack limit None Natural Gas or Oil (permitted for both; natural gas the typical fuel used) test show (Already indicated for emissions at controlled) Pilkington North America Inc. (NEI Unit ID 55204113) Flat Glass: Melting Furnace Wood 755 236 furnace #1; 3R technology32 for furnace #2 (technology is proprietary) CEMS the furnace are 41.64 tons NOx. Furnace #2 has an annual emissions limit of 945 tons -- CEMS data show recent emissions of 792.98 tons. Subtotal 236 29 This facility is subject to a consent decree with the U.S. requiring that SCR be installed on its furnace to be shutdown with compliance actions to be taken between December 31, 2017 and December 31, 2024. A NOx CEMS is already in place. Consent decree is at https://elr.info/sites/default/files/doi-consent-decrees/united states v. guardian industries corp.pdf. 30 Ohio's online permits are available at the following link: https://www.epa.ohio.gov/dapc/permits/permits. 31 The category indicated in italics and parentheses is associated with the categories in Table 13 below. 32 3R is a NOx control technology that involves combustion modification using excess natural gas to create reducing conditions within a glass furnace in order to reduce NOx emissions. A BACT permit by Cardinal Glass in Portage, Wl, filed with the Wisconsin Department of Natural Resources (WIDNR) (December 8, 2017) indicates that this technology may lead to long-term furnace and refractory damage based on their experience with the use of 3R at 3 other plants of theirs in the U.S. The CMDb does not include the 3R process as a NOx control technology. 18 March 12, 2021 ------- Table 12. Indiana Glass Manufacturing and Cement Manufacturing Facilities Facility Name/NEI Ultimate Type of County 2023 Estimated Existing NOx Fuel Used Other Status of Unit ID33 Parent Emissions Projected Reductions NOx Monitoring by Furnace Notes Estimated Company Unit NOx Emissions (OS Tons) from SCR and SNCR Control Device/ Technique Reductions34 Furnace #2 Possible has an (Possible annual emissions emissions reductions) limit of Ardagh Glass Inc. (NEI Unit ID 65375713) Ardagh Group S.A. Container Glass: Melting Furnace Randolph 312 97.63 No Control No monitors Natural Gas 506.9 tons. This furnace may be emitting under its permit limit. Furnace #1 Possible has an (Possible annual emissions emissions reductions) limit of Ardagh Glass Inc. (NEI Unit ID 65375813) Ardagh Group S.A. Container Glass: Melting Furnace Randolph 280 87.65 No Control No monitors Natural Gas 389.24 tons. This furnace may be emitting under its permit limit. 33 Indiana's online permits are available at the following link: https://www.in.gov/apps/idem/caats/. 34 The category indicated in italics and parentheses is associated with the categories in Table 13 below. 19 March 12, 2021 ------- Facility Name/NEI Ultimate Type of County 2023 Estimated Existing NOx Fuel Used Other Status of Unit ID33 Parent Emissions Projected Reductions NOx Monitoring by Furnace Notes Estimated Company Unit NOx Emissions (OS Tons) from SCR and SNCR Control Device/ Technique Reductions34 Facility- Possible wide (Possible annual emissions emissions reductions) Anchor Glass Container Anchor Glass Container limit of 396 Corporation Container Glass: Melting Dearborn 276 86.28 No control No monitors Natural Gas tons, which (NEI Unit ID 28314513) Corp. Furnace likely includes additional emissions sources. NOx Remove from control & consideration monitoring (Shutdown) required Lehigh Cement Company (NEI Unit ID 5813813) Heidelberg Cement Long Kiln Clark 187 38.89 SNCR CEMS Natural Gas (coal or oil as backup fuels) under consent decree (Essroc). Plant to cease operations during 2022. NOx Remove from control & consideration monitoring (Shutdown) Lehigh Cement Company (NEI Unit ID 5813313) Heidelberg Cement Preheater Kiln Clark 394 82.08 SNCR CEMS Natural Gas (coal or oil as backup fuels) required under consent decree (Essroc). Plant to cease operations 20 March 12, 2021 ------- Facility Name/NEI Unit ID33 Ultimate Parent Company Type of Emissions Unit County 2023 Projected NOx Emissions Estimated Reductions (OS Tons) from SCR and SNCR Existing NOx Control NOx Monitoring Device/ Technique Fuel Used by Furnace Other Notes Status of Estimated Reductions34 during 2022. Lehigh Cement Company (NEI Unit ID 4232613) Heidelberg Cement Preheater Kiln Lawrence 552 115.09 No control No monitoring Natural gas Plant is subject to NOx requireme nts in consent decree; a single kiln will replace all 3 preheater kilns in 2023. Permit indicates MKFor LNBas controls for ozone season, but no evidence of installation. Remove from consideration (Lehigh Cement - kiln replacements) Lehigh Cement Company (NEI Unit ID 4232813) Heidelberg Cement Preheater Kiln Lawrence 495 103.21 No control No monitoring Natural gas Plant is subject to NOx requireme nts in consent decree; a single kiln will replace all 3 Remove from consideration (Lehigh Cement - kiln replacements) 21 March 12, 2021 ------- Facility Name/NEI Unit ID33 Ultimate Parent Company Type of Emissions Unit County 2023 Projected NOx Emissions Estimated Reductions (OS Tons) from SCR and SNCR Existing NOx Control NOx Monitoring Device/ Technique Fuel Used by Furnace Other Notes Status of Estimated Reductions34 preheater kilns in 2023. Permit indicates MKFor LNBas controls for ozone season, but no evidence of installation. Lehigh Cement Company (NEI Unit ID 4233913) Heidelberg Cement Preheater Kiln Lawrence 711 148.10 No control No monitoring Natural gas Plant is subject to NOx requireme nts in consent decree; a single kiln will replace all 3 kilns by 2023. Plant is subject to NOx control by MKFor LNBin ozone season, but no evidence of installation. Remove from consideration (Lehigh Cement - kiln replacements) 22 March 12, 2021 ------- Facility Name/NEI Unit ID33 Ultimate Parent Company Type of Emissions Unit County 2023 Projected NOx Emissions Estimated Reductions (OS Tons) from SCR and SNCR Existing NOx Control NOx Monitoring Device/ Technique Fuel Used by Furnace Other Notes Status of Estimated Reductions34 Lehigh Cement Company (NEI Unit ID 65392513) Heidelberg Cement Wet Kiln Cass 314 65.49 Wl (water injection) CEMS Coal or oil Kiln #2 has an emissions limit of 4.75 lb N Ox/ton clinker produced Possible (Possible emissions reductions) Lehigh Cement Company (NEI Unit ID 65392613) Heidelberg Cement Wet Kiln Cass 242 50.33 SNCR+Wl CEMS Coal or oil Kiln #1 does not have an emissions limit indicated in the permit Remove from Consideration (Already controlled) Lone Star Industries Inc. (NEI Unit ID 9180513) Buzzi Unicem Semi-Dry Kiln Putnam 1,578 328.66 Low NOx calciner + good combustion practice (GCP) CEMS Coal or Oil Kiln has an emissions limit of 5.5141b NOx/ton of clinker produced Possible (Possible emissions reductions) Subtotal 1,203.41 23 March 12, 2021 ------- Conclusions of Verification and Review of Controls on Non-EGU Sources in Four States and Potential Emissions Reductions CoST identified likely cost-effective (i.e., $2,000 per ton or less) control technologies for 20 emissions units at glass manufacturing and cement manufacturing facilities in Pennsylvania, New York, Ohio, and Indiana. None of these units are owned by small businesses as defined by the Small Business Administration's (SBA) small business size standards for these two industry sectors.35 The total potential emissions reductions in Pennsylvania, New York, Ohio, and Indiana in tranche 1 were 7,556 ozone season tons. We looked at potential emissions reductions in tranche 1 that were estimated to cost <$2,000 per ton (likely cost-effective), which were 6,346 ozone season tons. We reviewed online permits for these 20 units and as indicated in Tables 9 through 12, 10 of these units either (i) have controls and monitors (primarily CEMS) already, (ii) are installing controls and CEMS or consolidating operations in the next few years as a result of recent consent decrees issued as part of the EPA's New Source Review Air Enforcement Initiative, (iii) have shutdown, or (iv) are planning to shut down by 2023.36 Table 13 below summarizes the status of the potential NOx emissions reductions. Table 13. Status of Estimated Potential Emissions Reductions # of OS Tons (% of Total) Emissions Units Shutdowns 4 824 13 Lehigh Cement - Kiln Replacements 3 366 6 NEI Discrepancy/Uncertain 1 3,286 51 Already Controlled/Uncertain 5 967 15 Possible Emissions Reductions 7 903 14 TOTAL 20 6,346 Based on the 2023 projected inventory, the emissions reductions from the plant shutdowns and consolidated operations (between 2015 and 2023) are estimated to be approximately 824 tons, or 13 percent of the potentially cost-effective ozone season emissions reductions in tranche 1. These emissions reductions are not currently reflected in the estimated air quality impacts shown above in Tables 7 and 8. In addition, for the Lehigh Cement manufacturing facility in Lawrence County, Indiana (emissions reductions estimated to be 366.40 tons, or 6 percent of the potentially cost-effective ozone season emissions reductions in tranche 1) that is subject to a consent decree, the 2023 projected inventory emissions are 1,758 tons and we currently do not know what the expected emissions reductions may be. We have found that the three older kilns currently in operation will shut down by 2023 and be replaced with a single new kiln whose production capacity will be almost 3 times as large (2.8 million tons of clinker compared to 1 million tons of clinker currently) and whose NOx emissions are unknown. Ten facilities, summarized again below in Table 14, were estimated to have the potential to generate some emissions reductions. However, results from the review of online permit review and industrial trade literature suggest that some of those potential reductions may not be true potential reductions. The status of the potential reductions at the ten facilities is summarized below, along with an assessment of the likelihood that 35 U.S. Small Business Administration (SBA). Table of Small Business Size Standards as of August 19, 2019. Available at https://www.sba.gov/sites/default/files/2019- 08/SBA%20Table%20of%20Size%20Standards_Effective%20Aug%2019%2C%202019_Rev.pdf. 36 The status of three of these 10 facilities reflects some uncertainty. Those facilities include Vitro Flat Glass LLC/Carlisle, PA, Pittsburgh Glass Works/Meadville Works 8, PA, and Pilkington North America Inc., OH. The uncertainty associated with the potential emissions reductions from these three facilities is discussed in this section. 24 March 12, 2021 ------- recommended controls could generate emissions reductions. The assessment for each facility concludes with either "uncertain" or "possible" depending on the likelihood of potential emissions reductions. Vitro Flat Glass LLC/Carlisle. PA (NEI Unit ID 18725313). 3.285.65 OS tons - The cost per ton and estimated emissions reductions for this emissions unit reflect a high degree of uncertainty. The uncertainty comes from the following two sources: (i) discrepancies between the underlying information for this unit in the 2023 projected inventory and other more recent emissions data reported to the state, and (ii) the equation in CoST that is used to estimate the emissions reductions and cost per ton value. In the 2023 projected inventory, the pre-control 2023 emissions for one of the emissions units (10,514 tons) are much larger than what appears in the 2018 PA Air Emissions Report for the entire facility (1,770 tons) and six times larger than any other glass furnace in this analysis.37 This discrepancy in emissions (roughly 8,700 tons) likely leads to an overestimate of potential emissions reductions (3,285.65 ozone season tons, or 51 percent of the likely cost-effective ozone season emissions reductions in tranche 1) that are not currently reflected in the estimated air quality impacts shown above in Tables 7 and 8. If total facility emissions are approximately 1,770 annual tons (or 737.5 ozone season tons), it is not possible to achieve 3,285 tons of ozone season reductions from only one unit at the facility. In addition, the projected inventory does not show a control on any unit at this facility, even though a review of the permit indicates that one unit does have a control. Emission Reduction Potential: Uncertain, 2023 projected inventory discrepancy Pittsburgh Glass Works/Meadville Works 8. PA (NEI Unit ID 19025613). 543.49 OS tons -- This facility shut down one of its two production lines effective June 10, 2020. The company stated that it is too expensive to rebuild the production line. Emission Reduction Potential: Uncertain, potentially shutdown Anchor Glass Container Corp. NY (NEI Unit ID 2854113). 140.63 OS tons -- Furnace #2 has an annual emissions limit of 4.5 lb NOx/ton of glass produced and no current control. Emission Reduction Potential: Possible Owens Brockwav Glass Container Inc.. NY (NEI Unit ID 2863113). 96.69 OS tons-The permit shows two furnaces with no controls. Emission Reduction Potential: Possible Pilkington North America Inc., OH (NEI Unit ID 55204113), 236 OS tons - In the permit, Furnace #1 was listed with an annual emissions limit of 364.7 tons, but a recent stack test indicates emissions at the furnace are 41.64 tons of NOx. Emission Reduction Potential: Uncertain, potentially already controlled Ardagh Glass Inc., IN (NEI Unit ID 65375713), 97.63 OS tons - In the permit, Furnace #2 has an annual emissions limit of 506.9 tons and the 2023 projected emissions are 312 tons. It is possible the source is currently operating under its permit limit. Emission Reduction Potential: Possible Ardagh Glass Inc.. IN (NEI Unit ID 65375813). 87.65 OS tons - In the permit, Furnace #1 has an annual emissions limit of 389.24 tons and the 2023 projected emissions are 280 tons. It is possible the source is currently operating under its permit limit. Emission Reduction Potential: Possible 37 In the 2017 NEI, the NOx emissions for the larger furnace are approximately 2,076 tons. 25 March 12, 2021 ------- Anchor Glass Container Corporation. IN (NEI Unit ID 28314513). 86.28 OS tons - Facility-wide annual emissions limit of 396 tons, which likely includes additional emissions sources. Emission Reduction Potential: Possible Lehigh Cement Company, IN (NEI Unit ID 65392513), 65.49 OS tons - Currently uses water injection as control technology. Emission Reduction Potential: Possible Lone Star Industries Inc.. IN (NEI Unit ID 9180513). 328.66 OS tons - Currently uses low NOx calciner + good combustion practice (GCP) as control technology. Emission Reduction Potential: Possible 26 March 12, 2021 ------- Table 14. Potential Emissions Reductions from Glass Manufacturing Facilities in Pennsylvania, New York, Ohio, and Indiana Facility Name/NEI Unit ID Type of Emissions Unit County (State) 2023 Projected NOx Emissions Estimated Reductions (OS Tons) Existing NOx Control NOx Monitoring Device/ Technique Status of Estimated Reductions Vitro Flat Glass LLC/Carlisle (NEI Unit ID 18725313) Flat Glass: Melting Furnace Cumberland (PA) 10,514 3,285.65 No Control CEMS Uncertain, NEI discrepancy Pittsburgh Glass Works/Meadville Works 8 (NEI Unit ID 19025613) Flat Glass: Melting Furnace Crawford (PA) 1,739 543.49 No Control CEMS Uncertain, potentially shutdown Anchor Glass Container Corp (NEI Unit ID 2854113) Container Glass: Melting Furnace Chemung (NY) 450 140.63 Two furnaces - Furnace #1-SCR; Furnace #2 - no control CEMS Possible Owens Brockway Glass Container Inc (NEI Unit ID 2863113) Container Glass: Melting Furnace Cayuga (NY) 309 96.69 Two furnaces - No controls indicated CEMS Possible Pilkington North America Inc. (NEI Unit ID 55204113) Flat Glass: Melting Furnace Wood (OH) 755 236 Two furnaces - None indicated for furnace #1; 3R technology for furnace #2 (technology is proprietary) CEMS Uncertain, potentially already controlled Ardagh Glass Inc. (NEI Unit ID 65375713) Container Glass: Melting Furnace Randolph (IN) 312 97.63 No Control No monitors Possible Ardagh Glass Inc. (NEI Unit ID 65375813) Container Glass: Melting Furnace Randolph (IN) 280 87.65 No Control No monitors Possible Anchor Glass Container Corporation (NEI Unit ID 28314513) Container Glass: Melting Furnace Dearborn (IN) 276 86.28 No control No monitors Possible Lehigh Cement Company (NEI Unit ID 65392513) Wet Kiln Cass (IN) 314 65.49 Wl (water injection) CEMS Possible Lone Star Industries Inc. (NEI Unit ID 9180513) Semi-Dry Kiln Putnam (IN) 1,578 328.66 Low NOx calciner + good combustion practice (GCP) CEMS Possible 27 March 12, 2021 ------- In summary, the total potential emissions reductions in Pennsylvania, New York, Ohio, and Indiana in tranche 1 were 7,556 ozone season tons. We looked at potential emissions reductions in tranche 1 that were estimated to cost <$2,000 per ton, which were 6,346 ozone season tons. Between unit shutdowns and potentially incorrect emissions data in the 2023 projected inventory (and the resulting infeasible estimate of potential emissions reductions), of the 6,346 tons approximately 4,110 tons, or 64 percent, of the likely cost-effective emissions reductions are not or may not be true, achievable emissions reductions. The potential emissions reductions associated with applying CoST-recommended controls that are considered possible are 903 ozone season tons, or 14 percent of the likely cost-effective emissions reductions. Also, as noted above in the section Further Verifying and Refining Estimated Non-EGU NOx Emissions Reduction Potential, between the Revised CSAPR Update proposed and final rules, we reviewed the potential controls for emissions sources/units in tranche 1 for additional linked states in Table 7 - Maryland, Michigan, and Virginia. We did not review the potential controls for emissions sources/units in Illinois because their permits were not available online, and we did not review the potential controls in Kentucky because CoST did not identify applicable control measures for any emissions sources/units in the state. In tranche 1, we originally estimated 664 ozone season tons of likely cost-effective emissions reductions from these four states (excluding Kentucky). This additional review identified approximately 62 ozone season tons out of the estimated 664 ozone season tons that are from sources/units already controlled, leaving an estimated 602 ozone season tons of likely cost-effective emissions reductions from these states. Finally, between the proposed and final rules, we also reviewed the potential controls for emissions sources/units in tranche 2 (Table 5 above). Of the approximately 11,119 ozone season tons of estimated emissions reductions, ten percent of those reductions are from sources/units already controlled.38 Caveats and Limitations of the Cost Analysis The EPA acknowledges several important caveats and limitations of the non-EGU cost assessment included in this memorandum, which include the following: Boundary of the cost analysis: In this cost analysis we include only the impacts to the sectors and facilities that are the focus of this analysis. We include the costs for purchase, installation, operation, and maintenance of control equipment over the lifetime of the equipment. Recordkeeping, reporting, testing and monitoring costs are not included.39 Additional revenue may be generated by vendors that would build, install, and test new control technologies for use at sources in the directly affected sectors, especially for control equipment manufacturers, distributors, or service providers. These revenue and employment impacts are not included in this cost analysis. Cost and effectiveness of control technologies: The application of control technologies reflect average retrofit factors nationally and average estimates of equipment life. We do not account for regional or local variation in capital and annual cost items such as energy, labor, and materials. The estimates of control technology costs may over- or under-estimate the costs depending on how the difficulty of actual retrofitting and equipment life compares with the control and cost assumptions. In addition, the estimates of control efficiencies for control technologies included in the assessment assume that the control devices are properly installed and maintained. 38 Please refer to the Excel workbook titled CoST Control Strategy - Max Reduction $10k 150 tpy cutoff 12 States Updated Modeling - No Replace - 07-23-2020 for more details on the estimated emissions reductions in tranche 2. 39 Many of the sources included in this cost analysis already have NOx monitors (primarily CEMS) installed, as shown in Tables 9 through 14, which partially offsets this limitation. 28 March 12, 2021 ------- Interest rate: We apply an interest rate of 7 percent to annualize capital costs in the analysis. In addition, while this interest rate may potentially be consistent with guidance as found in the EPA Air Pollution Control Cost Manual,40 (hereafter called the "Control Cost Manual") the actual interest rate may vary for control cost estimation at each facility included in this analysis. Accuracy of control costs: We estimate that there is an accuracy range of +/- 30 percent for non-EGU point source control cost estimates. This level of accuracy is described in the Control Cost Manual, which is a basis for the estimation of non-EGU control cost estimates included in this memorandum. This level of accuracy is consistent with either the budget or bid/tender level of cost estimation (or Class 4) as defined by the American Association for Cost Engineering International (AACEI) and explained in Section 1, Chapter 2 of the Control Cost Manual. In addition, the accuracy of costs is also influenced by the availability and extent of data underlying the cost estimates for individual control technologies. Control Installation Timing We previously examined the time necessary to install the controls listed above for different industries. The 2016 Final Technical Support Document (TSD)for the Final Cross-State Air Pollution Rule for the 2008 Ozone NAAQS, Assessment of Non-EGU NOx Emission Controls, Cost of Controls, and Time for Compliance Final TSD (CSAPR Update non-EGU TSD) provided preliminary estimates of installation times for a variety of NOx control technologies applied to a large number of sources in non-EGU industry sectors.41 For virtually all NOx controls applied to cement manufacturing and glass manufacturing units, information on installation times was not available to provide an estimate, and we concluded that the installation time for these controls was "uncertain." There was an exception for SNCR applied to cement kilns, and the installation time estimate of 42-51 weeks listed in the CSAPR Update non-EGU TSD does not account for implementation across multiple sources, the need to have NOx monitors installed, and other steps in the permitting and construction processes. To improve upon information from the CSAPR Update Non-EGU TSD on installation times for SCR on glass furnaces and SNCR on cement kilns, EPA reviewed information from recent permitting actions and a consent decree. For two glass manufacturing facilities that installed SCR on glass furnaces, from the time of permit application to the time of SCR operation was approximately 19 months for one facility and is currently at least 20 months for another facility.42 These installation times do not reflect time needed for pre-construction design and engineering, financing, and factors associated with scaling up construction services for multiple installations at several emissions units. With respect to cement kilns, an April 2013 consent decree between EPA and CEMEX, Inc. required installation of SNCR at a kiln within 450 days, or approximately 15 months, of the effective date of the consent decree.43 Similarly, this installation time does not reflect time associated with scaling up construction services for multiple control installations at several emissions units. 40 U.S. EPA, Office of Air Quality Planning and Standards. EPA Air Pollution Control Cost Manual. Section 1, Chapter 2, pp. 15- 17. Available on the Internet at https://www.epa.gov/sites/production/files/2017- 12/documents/epaccmcostestimationmethodchapter 7thedition 2017.pdf. 41 The CSAPR Update non-EGU TSD is available on the EPA's website at the following link: https://www.epa.gov/airmarkets/assessment-non-egu-nox-emission-controls-cost-controls-and-time-compliance-final-tsd. 42 Cardinal FG Company submitted a permit application to the Wisconsin Department of Natural Resources (WIDNR) to construct an SCR in December 2017 at a facility in Portage, Wisconsin. The SCR was expected to be ready for testing in mid- July 2019. In addition, Cardinal FG Company submitted a permit application to the WIDNR to construct an SCR in January 2019 at a facility in Menomonie, Wisconsin. The SCR is currently not operational. 43 The consent decree can be located at the following link: https://www.epa.gov/sites/production/files/documents/cemex- lvons-cd.pdf. 29 March 12, 2021 ------- Request for Comment and Additional Information To develop a more complete record, at proposal the EPA requested comment on several questions related to specific control strategies the Agency evaluated, and in particular sought feedback and data from stakeholders with relevant expertise or knowledge. For a general discussion of comments received and Agency responses, please see the Revised Cross-State Air Pollution Rule Update for the 2008 Ozone NAAQS final rule preamble. For the detailed comments and responses, please see and the Non-EGUs section in the Revised Cross-State Air Pollution Rule Update for the 2008 Ozone Season NAAQS - Response to Comment document available in the docket. As indicated above, information about existing controls on non-EGU emissions sources/units in the inventory was missing for some states and incomplete for some sources/units. The approach the EPA used was to assess emission reduction potential using CoST and the projected 2023 inventory to identify emissions units that were uncontrolled. Given that the EPA's assessment of any other NOx control strategies would also rely on CoST, the CMDb, and the inventory to identify emissions units that were uncontrolled and to assess emission reduction potential from non-EGU sources/units, the Agency believed such an assessment would likely lead to a similar conclusion that estimated emission reduction potential is uncertain. As such, for this and future regulatory efforts, to improve the underlying data used in an assessment of emission reduction potential from non-EGU sources, we requested comments on: (i) the existing assessment of emission reduction potential from glass furnaces and cement kilns; (ii) emission reduction potential from other control strategies or measures on a variety of emissions sources/units in several industry sectors; and (iii) the feasibility of further controlling NOx from IC engines and large ICI boilers, including optimizing combustion and installing ultra- low NOx burners. The three sections below introduce the areas for comment and describe workbooks generated by CoST, the CMDb, and the 2023 projected inventory with the underlying data to review. First, the EPA requested comment on the aspects of the assessment presented above of emission reduction potential from the glass and cement manufacturing sectors. To help inform review and comments, the Agency referred commenters to the following Excel workbooks available in the docket: (i) for a summary of the CoST run results CoST Control Strategy - Max Reduction $10k 150 tpy cutoff 12 States Updated Modeling - No Replace - 07- 23-2020, and (ii) for summaries of emissions reductions by control technologies, Control Summary - Max Reduction $10k 150 tpy cutoff 12 States Updated Modeling - No Replace - 05-18-2020. Note that the CoST Control Strategy - Max Reduction $10k 150 tpy cutoff 12 States Updated Modeling - No Replace - 07-23-2020 Excel workbook includes a READ ME worksheet that provides details on the parameters used for the CoST run. Specifically, the EPA solicited comment on the following: Are applying SCR to uncontrolled or under-controlled glass furnaces and SNCR to uncontrolled or under- controlled cement kilns in the linked states feasible approaches to achieve cost-effective emissions reductions? If not, what types of cost-effective controls can be applied to these sources? Does the EPA have the right and most up to date information on emissions and existing control technologies for the units included in this assessment? If not, what is the correct and more up to date information? After looking at the underlying CoST run results, are the cost estimates accurate and reasonable? If not, what are more accurate cost estimates? What is the earliest possible installation time for SCR on glass furnaces? What is the earliest possible installation time for SNCR on cement kilns? For the non-EGU facilities without any emissions monitors, what would CEMS cost to install and operate? How long would CEMS take to program and install? 30 March 12, 2021 ------- In addition to the assessment of emission reduction potential from the glass and cement manufacturing sectors, for the 12 linked states the EPA attempted to summarize all potential control measures for emissions units with 150 tpy or more pre-control NOx emissions in 2023 in several industry sectors. This information illustrated that there are many potential approaches to assessing emissions reductions from non-EGU emissions sources or units. We used the Least Cost Control Measure worksheet from a CoST run.44 By state for the 12 linked states and then by facility, this information was summarized in the Excel workbook titled CoST Control Possibilities $10k 150 tpy cutoff 12 States Updated Modeling - 06-30-2020, also available in the docket. Second, specifically the EPA requested comment on the following: Other than glass and cement manufacturing, are there other sectors or sources that could achieve potentially cost-effective emissions reductions? What are those sectors or sources? What control technologies achieve the reductions? What are cost estimates and installation times for those control technologies? Are there other sectors where cost effective emission reductions could be obtained by, in lieu of installing controls, replacing older, higher emitting equipment with newer equipment? Are there sectors or sources where cost effective emission reductions could be obtained by switching from coal-fired units to natural gas-fired units? For non-EGU sources/units without emissions monitors, what would CEMS cost to install and operate? How long would CEMS take to program and install? Are monitoring techniques other than CEMS, such as predictive emissions monitoring systems (PEMS), sufficient for certain non-EGU facilities that would not be brought into a trading program? If so, for what types of non-EGU facilities, and under what circumstances, would PEMS be sufficient? What would be the cost to install and operate monitoring techniques other than CEMS? Third, in the workbook titled CoST Control Possibilities $10k 150 tpy cutoff 12 States Updated Modeling - 06-30- 2020 the EPA included two worksheets with information on controls for ICI boilers and IC engines: (i) Boilers - ULNB and (ii) IC Engines - LEC. For the 12 linked states, the EPA summarized CoST's application of ultra-low NOx burners (ULNB) on ICI boilers and low emission combustion (LEC) on IC engines. Assuming that the estimated emissions reductions from CoST's application of these controls are real and cost-effective in the context of this ozone transport rule, there could be approximately 5,000 ozone season tons of emissions reductions from 52 ICI boilers and 8,000 ozone season tons of emissions reductions from 69 IC engines. This information is summarized in Table 15 below. Table 15. Summary of Potential Emissions Reductions from ULNB on ICI Boilers and LEC on IC Engines ICI Boilers IC Engines Number of Emissions Units in the 12 Linked States (>150 tpy NOx emissions) 52 69 2023 Projected Total NOx Emissions in the 12 Linked States (ozone season tons, reflects any existing control before ULNB or LEC were applied) 6,779 9,260 2023 Projected Total NOx Emissions in the 12 Linked States after Applying ULNB to Boilers (ozone season tons) 1,695 - 44 The Least Cost Control Measure worksheet is a table of all possible emissions source-control measure pairings (for sources and measures that meet the respective criteria specified for a control strategy), each of which contains information about the cost and emissions reductions achieved if the control measure were to be applied to the emissions source. 31 March 12, 2021 ------- ICI Boilers IC Engines 2023 Projected Total NOx Emissions in the 12 Linked States after Applying LEC to IC Engines (ozone season tons) - 1,231 Number of Units with No Known Existing Control 51 57 The EPA requested comments on the feasibility of further controlling NOx from IC engines and large ICI boilers, including optimizing combustion and installing low NOx burners. The Agency understands that it is generally possible to install low NOx burners on EGU boilers fairly quickly and that these burners can significantly reduce NOx emissions. We note that in the original interstate transport rule, the NOx SIP call, the Agency concluded that controls on large, non-EGU boilers and turbines were cost effective and allowed states to include those emissions sources in their budgets as a means of providing additional opportunities to reduce state-wide NOx emissions in a cost-effective manner.45 Therefore, we solicited comment on whether the EPA should require that large non-EGU boilers and turbines - as defined in the NOx SIP call as boilers and turbines with heat inputs greater than 250 mmBTU per hour or with NOx emissions greater than 1 ton per ozone season day46 - within the 12 states employ controls that achieve emissions reductions greater than or equal to what can be achieved through the installation of low NOx burners. In their comment on the Revised CSAPR Update proposal, the Council of Industrial Boiler Owners (CIBO) indicated that many of their members' industrial boilers already have low NOx burners installed, and that they are installed for the sole purpose of reducing NOx emissions and are thus an add-on controls.47 Also, five of the 12 states that are subject to this rulemaking are also within the Ozone Transport Region (OTR) - Maryland, New Jersey, New York, Pennsylvania, and Virginia. As member states of the OTR, these five states are required under the Clean Air Act to implement reasonably available control technology (RACT) state-wide on major sources of emissions.48 It is likely that NOx controls, such as low NOx burners, are already in wide-spread use within these five states, which is consistent with the statement above from CIBO's comment on NOx controls installed on industrial boilers. However, such controls may not be as widely used in states outside of the OTR. Therefore, we also solicited comment on the (i) magnitude of the emissions reductions that could be achieved by requiring that large non-EGU boilers and turbines install controls that achieve emissions reductions greater than or equal to what could be achieved through the installation of low NOx burners, (ii) prevalence of these or better NOx controls already in place on this equipment in these 12 states, and (iii) time it typically takes to install such controls. In addition to the above, the EPA requested comments on the following: How effective are ultra-low NOx burners or low NOx burners in controlling NOx emissions from ICI boilers? Are they generally considered part of the process or add-on controls? If they are part of a process, how could the EPA estimate the cost associated with changing the process to accommodate ultra-low NOx burners and low NOx burners? What are the costs (capital and annual) for these as add-on control technologies on ICI boilers? What are the earliest possible installation times for these control technologies on ICI boilers? The EPA 45 See 63 FR 57402. 46 Note that the 250 mmBTU/hr for ICI boilers and turbines is equivalent to 25 MW heat input for an EGU. Also, the tonnage per large source was 1 ton per ozone season day. Because controls on non-EGUs operate year-round, the emissions would be 365 tons per year. 47 Comment filed by the Council of Industrial Boiler Owners (CIBO) on the Revised Cross-State Air Pollution Rule Update for the 2008 Ozone National Ambient Air Quality Standards. EPA-OAR-HQ-2020-0272-DRAFT-0122. p. 11. 48 One exception to the requirement of state-wide RACT within the OTR is for Virginia. Only the Northeast portion of the state is included within the OTR and only facilities within that portion of the state are subject to RACT. 32 March 12, 2021 ------- believes it is generally possible to install low NOx burners on EGU boilers relatively quickly and that low NOx burners can significantly reduce NOx emissions. The EPA solicits comment on whether this is also true for large non-EGU ICI boilers. Do some of the emissions units included in the summary already have either add-on controls or controls that are part of a process? If so, what control is on the unit and what is the control device (or removal) efficiency? Natural gas compressor stations are the largest NOx-emitting non-EGU sector49 affecting the 12 states that are the subject of the proposal, and many of these facilities are powered by decades-old, uncontrolled IC engines. Should emissions reductions be sought from the IC engines at these stations, either through installing controls, upgrading equipment, or other means? How effective is low emission combustion in controlling NOx from IC engines? What is the cost (capital and annual) for low emission combustion on IC engines? What is the earliest possible installation time for low emission combustion on IC engines? In lieu of installing controls, is replacing older, higher emitting equipment with newer equipment a cost-effective way to reduce emissions from IC engines? Do some of the emissions units included in the summary already have either add-on controls or controls that are part of a process? If so, what control is on the unit and what is the control device (or removal) efficiency? In a comment on the Revised CSAPR Update proposal from the American Forest and Paper Association (AF&PA) and the American Wood Council (AWC), the organizations asserted that up to 4 years are required for implementation of NOx controls at industrial boilers at their facilities when considering all aspects of installation such as design, engineering, permitting, procurement, and installation. These associations also stated that project timelines would increase with implementation of a NOx regional rule, since many facilities would be competing for the same vendor expertise.50 Attachments 1. CoST Control Strategy - Max Reduction $10k 150 tpy cutoff 12 States Updated Modeling - No Replace - 07- 23-2020.xlsx 2. Control Summary - Max Reduction $10k 150 tpy cutoff 12 States Updated Modeling - No Replace - 05-18- 2020.xlsx 3. CoST Control Possibilities $10k 150 tpy cutoff 12 States Updated Modeling - 06-30-2020.xlsx 4. 2017 NEI Data_Twelve States_Merged_Greater than 100 Tons.xlsx 49 Based on data from the 2017 National Emissions Inventory (NEI) database. For additional details on the 2017 NEI data summaries, please see the Excel workbook titled 2017 NEI Data_Twelve States_Merged_Greater than 100 Tons in the docket. 50 Comment filed by the American Forest and Paper Association and American Wood Council on the Revised Cross-State Air Pollution Rule Update for the 2008 Ozone National Ambient Air Quality Standards. EPA-OAR-HQ-2020-0272-DRAFT-0113. p. 9. 33 March 12, 2021 ------- |