Cross-State Air Pollution Rule (CSAPR)
Frequently Asked Questions
The Cross-State Air Pollution Rule (CSAPR) requires 28 states to significantly improve air quality by reducing power plant emissions that cross state lines and contribute to ozone and fine particle pollution in other states. To speed implementation, EPA is adopting Federal Implementation Plans, or FIPs, for each of the states covered by this rule. EPA is encouraging states to submit State Implementation Plans (SIPs) starting as early as 2013.
NOX SIP Call Transition for Large Non-EGUs
My State is a NOX SIP Call state, and, as part of its compliance strategy, large non-EGUs (i.e., non-EGU boilers and combustion turbines with a maximum design heat input greater than 250 MMBTU/hr and, in New York, certain cement kilns) were brought into the CAIR NOX Ozone Season trading program. These units cannot be brought into the Transport Rule trading programs. Are these "large non-EGU boilers and combustion turbines" (which phrase should be read hereinafter to include, for New York, the relevant cement kilns) still required to comply with the NOX SIP Call?
- CSAPR does not preempt or replace the requirements of the NOX SIP Call. There are several options available to NOX SIP Call states to show continued compliance with NOX SIP Call requirements.
What options does my State have for meeting NOX SIP Call requirements with regard to large non-EGUs?
- There are a number of acceptable approaches to address NOX SIP Call requirements where large non-EGUs were included in the CAIR NOX Ozone Season Trading Program but will not be included in the Transport Rule NOX Ozone Season Trading Program. The following provides information on some acceptable options for showing that NOX SIP Call requirements are being met, but states may submit other approaches, which EPA will evaluate on a case-by-case basis.
- Acceptable options for a state include the following demonstrations (provided to EPA in a submission supporting the State's SIP):
- Option 1: Streamlined demonstration. Demonstrate that total ozone-season NOX emissions from large non-EGU boilers and combustion turbines in the State that were included in the NOX Budget Trading Program but will not be included in the TR ozone-season trading program could not exceed the large non-EGU budget imposed by the NOX SIP Call even if these units were to operate every hour of the ozone season. This demonstration should include a determination -- for each of these large non-EGUs -- of the average actual hourly ozone season NOX emission rate (i.e., total actual NOX emissions divided by actual operating hours) for the most recent ozone season of representative operation of the large non-EGU sector in the State, multiplied by the total number of hours in the ozone season (3,672). If the sum of the resulting NOX mass emissions for all of these large non-EGUs is less than the large non-EGU portion of the NOX SIP Call budget, then the NOX SIP Call requirements are satisfied for these sources.
- Option 2: Demonstrate that the NOX SIP Call reduction obligations for these large non-EGU boilers and combustion turbines are being met through alternative limits on these non-EGUs. As explained in 40 CFR 51.121(f)(2)(i), these alternatives include:
- Imposing a NOX mass emissions cap on each source;
- Imposing a NOX emissions rate limit on each source and assuming maximum operating capacity for every such source for purposes of estimating NOX mass emissions; or
- Imposing other regulatory requirements that the State has demonstrated to EPA provide equivalent or greater assurance that the State will comply with its ozone season NOX budget for large non-EGU boilers and combustion turbines.
- Option 3: Demonstrate that additional ozone season NOX emission reductions from other sources covered by the NOX SIP Call have achieved extra reductions, over and above any required for those other sources by the NOX SIP Call, to the degree that overall reduction requirements of the NOX SIP Call have been achieved without any reductions from large non-EGUs.
Demonstrations of emissions or reductions by large non-EGU boilers and combustion turbines must take into account both existing and new large non-EGUs. What approach should a state take to ensure that new large non-EGU boilers and combustion turbines would not lead to the non-EGU budget being exceeded in the future?
- When a new large non-EGU is permitted in the State, the State should revise the demonstration to take the new unit into account. That is, the State should confirm that emissions remain below the budget, taking emissions from the new large non-EGU into account in the calculation.
Must my State retain for large non-EGUs the 40 CFR Part 75 monitoring, record keeping, and reporting requirements?
- Yes. If the State chooses option 1 or 2 as described above the State must also retain Part 75 monitoring, record keeping, and reporting requirements for large non-EGUs that were included in the NOX Budget Trading Program but will not be included in the TR ozone-season trading program. Further, even if the State chooses an option, such as option 3 above, that demonstrates that the NOX SIP Call requirements have been achieved without any reductions from large non-EGUs, EPA recommends that the requirements for monitoring, record keeping, and reporting using Part 75 be retained for all existing and new large non-EGUs. This monitoring and reporting provides useful information on on-going large non-EGU operations.
What is my State's NOX SIP Call budget for large non-EGUs?
1The District of Columbia, Delaware, Illinois, Maryland, New Jersey, and Pennsylvania did not choose to include large non-EGUs in the CAIR NOX Ozone Season Trading Program. Remaining NOX SIP Call requirements in those states have been addressed separately.
Does the Cross-State Air Pollution Rule (CSAPR) only cover Power Plants?
- Yes. EPA is continuing to collect information to determine whether additional upwind state reductions, including from other source categories, are necessary for potential future rulemakings.
How does the Cross-State Air Pollution Rule (CSAPR) interact with Title IV, the Acid Rain Program?
- Title IV allowances can not be used to comply with the CSAPR. This new rule creates a separate allowance system for SO2 emissions. Sources covered by the Acid Rain Program must still use Title IV allowances to comply with the program. The Acid Rain Program requirements will not be affected by the CSAPR.
What happens to CAIR after the Cross-State Air Pollution Rule (CSAPR) is implemented?
- The CSAPR replaces CAIR, the CAIR FIPs, and the associated SO2, annual NOX, and ozone season NOX trading programs. The Cross-State Air Pollution Rule takes effect January 1, 2012; CAIR will be implemented through the 2011 compliance periods, and then replaced by the CSAPR.
Is EPA finalizing FIPs for the Cross-State Air Pollution Rule (CSAPR)?
- Like CAIR, EPA is finalizing federal implementation plans, or FIPs, for each state covered by this rule, but states can replace the FIPs with SIPs to implement any or all CSAPR programs at any time. A state may choose to develop a SIP to achieve the required reductions, replacing its FIP, and may choose which types of sources to control. States also can choose to allocate allowances for any or all programs through the use of SIPs, starting as early as 2013.
Why are the NOX emission reductions in the final rule less than in the proposal for the Cross-State Air Pollution Rule?
- Due to a combination of modeling updates (including lower natural gas prices, reduced demand, newly-modeled consent decrees and state rules, and updated NOX rates to reflect 2009 emissions data), EPA revised the NOX emissions inventory for the final rule. The updated inventory significantly lowered NOX emission levels in the base case (without the CSAPR) from approximately 3 million tons in the proposal to 2.1 million tons in the final. This affected the total NOX emission reduction numbers for the final rule.
SIP Process for 2013 Allowance Allocations
What is the first possible year for which a state can submit state-determined allowance allocations to replace the allowance allocations determined by EPA in one or more of the Transport Rule (TR) trading programs applicable to the state under the CSAPR FIPs?
- A state may submit state-determined allocations for existing units to replace the EPA-determined allowance allocations for existing units for the 2013 control period.
If a state wants to submit state-determined existing unit allocations to replace the EPA-determined, existing-unit allocations for 2013 in one or more of the TR trading programs, are there any notification requirements?
- Yes, by the date 70 days after publication of the final rule in the Federal Register, a state must provide notification to EPA if the state intends to submit state-determined, existing-unit allocations for 2013. The notification must be in a format prescribed by EPA and submitted electronically.
If a state is subject to multiple TR trading programs, may a state choose to submit 2013 state-determined, existing-unit allocations for some, but not all, the trading programs applicable to the state?
- Yes, states may choose to submit 2013 state-determined allocations for one or more of the applicable trading programs while leaving unchanged the EPA-determined allocations for 2013 in the remaining applicable trading programs.
If a state chooses not to submit a SIP revision for 2013 allocations in an applicable TR trading program, when will EPA record 2013 existing-unit allocations in that trading program?
- If EPA does not receive the necessary notification -- by the date 70 days after publication of the final rule in the Federal Register -- of the state's intent to submit a SIP revision modifying 2013 existing-unit allocations in a trading program, EPA will record the EPA-determined, existing-unit allocations for 2012 and 2013 in the trading program by the date 90 days after publication of the final rule.
When must a state submit to EPA a SIP revision to replace 2013 EPA-determined, existing-unit allocations with state-determined allocations?
- By April 1, 2012, a state must submit to EPA the 2013 SIP revision, which must meet certain requirements.
What requirements must the 2013 SIP revision meet?
- The 2013 SIP revision must meet the following requirements:
- Allocates to existing units only. An existing unit is a unit that commenced commercial operation (i.e., began producing electricity for sale) before January 1, 2010.
- Provides a list of the existing units and their 2013 state-determined allocations. The list must be provided electronically to EPA by April 1, 2012 and in a format prescribed by EPA.
- May not contain provisions that allow for any change in the units and state-determined allocations on the list and in any allocation previously determined and recorded by EPA in the trading program.
- Allocates a total amount of allowances for 2013 for the trading program involved that does not exceed the state trading budget minus the new unit set-aside and the Indian country new unit set-aside (if any) for the trading program and for the state. This amount is set forth in Tables X-1 through X-3 in the CSAPR preamble at pages 524-526 in the prepublication version located on the CSAPR website.
- Does not provide for any other distribution of allowances. For example, the SIP revision cannot provide for set-asides or auctions and cannot alter the new unit set-asides, the Indian country new unit set-asides, and any aspect of allowance allocation in the trading programs involved other than the 2013 existing-unit allocations.
When will EPA record 2013 state-determined, existing-unit allocations, assuming all requirements are met?
- If, not later than April 1, 2012, the state submits to EPA a SIP revision meeting all the above-described requirements and EPA approves the SIP revision by October 1, 2012, EPA will record state-determined, existing-unit allocations for 2013 by October 1, 2012. Otherwise, EPA will record the EPA-determined, existing-unit allocations for 2013 by October 1, 2012.
What are the assurance provisions?
- The Transport Rule (TR) trading programs under CSAPR contain assurance provisions that apply beginning in 2014 and ensure that the necessary emissions reductions will occur within each TR-covered state. For each state for each TR trading program, the state's budget plus variability limit constitutes that state's assurance level for that TR trading program. Each state's assurance levels for its TR trading programs take into account the inherent variability in the state's baseline emissions from year to year. Note, however, that allowances are only allocated up to the level of a state's budget for that state's specific TR trading program and not to the level of the state's budget plus the variability limit.
When are the assurance provisions triggered?
- If a state's total emissions from all units covered by a specific TR program in a specific year are greater than the sum of the state's budget plus variability limit for that program and year, the assurance provisions are triggered for that state, program, and year.
Which owners and operators must surrender additional allowances under the assurance provisions if the provisions are triggered?
- To identify which owners and operators must surrender additional allowances under assurance provisions that are triggered, EPA calculates, for each common designated representative (common DR), the common designated representative's assurance level and common designated representative's share of emissions. If, for any common DR, his or her share of emissions is greater than his or her assurance level, the owners and operators of the group of units and sources represented by that common DR must surrender additional allowances under the assurance provisions.
What is a common designated representative?
- A common designated representative for a control period in a specific year is the individual who is designated, as of April 1 immediately following that year, through a certificate of representation, as the designated representative (not the alternate designated representative) for a group of one or more covered units and sources in a state.
How is the common DR's assurance level calculated?
- To determine a common DR's assurance level, EPA calculates the total amount of allowance allocations to the units at sources located in a specific state and whose owners and operators are represented by that common DR and multiplies that sum by the quotient of the state's budget plus variability divided by the state's budget. The product of that calculation is the common DR's assurance level.
- For example, assume that a state has a budget of 10,000 tons and a variability limit of 1,000 tons for the 2012 ozone season. Also assume that a common DR represents the owners and operators of units covered by the TR NOX Ozone Season Trading Program in that state and allocated for 2012 a total amount of 500 allowances (including allowances allocated from the new unit set-aside). The total amount of 500 allowances is multiplied by 1.1 because 11,000 tons (the state's budget plus the state's variability limit) divided by 10,000 tons (the state's budget) equals 1.1. The resulting product is 550 allowances, which is the common DR's assurance level.
How is the common DR's share of emissions calculated?
- The common DR's share of emissions is simply the sum of the emissions -- for a specific state, TR program, and year -- of the TR-covered units at the TR sources for which that person is the common DR .
If the assurance provisions are triggered in a specific state for a specific TR program and year and a common DR's assurance level is less than his or her share of emissions, how does EPA calculate how many additional allowances the owners and operators must surrender?
- To calculate the surrender amount for the owners and operators of a group of units and sources with a common DR when the assurance provisions are triggered, EPA calculates, for all common DRs whose assurance levels are exceeded by their respective shares of emissions, the sum of those exceedances. The exceedance of a specific common DR is then divided by the sum of the exceedances, and that quotient is then multiplied by the amount in tons that the total emissions for the state exceeded that state's budget plus variability limit. The product of that calculation is then multiplied by two, yielding the number of additional allowances that the owners and operators of the group of units and sources must surrender under the assurance provisions.
- Using numbers from the earlier example, assume that a state's TR NOX Ozone Season Program budget plus variability limit is 11,000 tons (budget of 10,000 tons plus variability limit of 1,000 tons). Also assume that the total state emissions for the compliance year in question were 11,200 tons, 200 tons above the budget plus variability limit (11,200 minus 11,000).
- Further assume that the owners and operators of a group of units and sources in the state have a common DR whose share of NOX ozone season emissions (i.e., the sum of the NOX ozone season emissions from the units at the sources) is 600 tons and whose assurance level (i.e., the sum of the allocations plus share of the variability limit) is 550 tons. In this case, the common DR's share of emissions exceeds the common DR's assurance level by 50 tons (600 minus 550).
- Finally assume that the sum of the exceedances, for the owners and operators of all groups of units and sources with a common DR in the state for that ozone season, totaled 200 tons. The specific group of owners' and operators' exceedance (50 tons) is then divided by the sum of total exceedances (200 tons), yielding a quotient of 0.25. That quotient is then multiplied by the amount of tons (200 tons) by which the state's total emissions exceeded the budget plus variability, yielding a product of 50 tons (200 multiplied by .25). That figure is then multiplied by two, with the result that this specific group of owners and operators must surrender, through transfer into their assurance account, an additional amount of 100 allowances under the assurance provisions.
What is an assurance account?
- If the assurance provisions are triggered for a state with regard to a TR program and a year, EPA establishes an assurance account for each group of owners and operators of a group of units and sources in the state whose common DR has an assurance level lower than his or her share of emissions with regard to the program and year. The owners and operators must use their assurance account for the surrender of additional allowances under the assurance provisions.
What is the deadline by which a group of owners and operators must transfer enough allowances into their assurance account to cover deductions to be made by EPA under the assurance provisions?
- If a group of owners and operators are required to surrender allowances under the assurance provisions, they must transfer enough allowances into their assurance account no later than November 1 of the year following the control period for which the allowance surrender is being made.
What vintage year TR allowances may be used for an allowance surrender under the assurance provisions?
- The group of owners and operators must surrender allowances of the vintage year for which the assurance provisions were triggered, any prior year, or the year immediately following the year for which the assurance provisions were triggered.
- For example, assume that a group of owners and operators must surrender allowances under the assurance provisions for emissions reported in the 2016 TR NOX Annual control period. The owners and operators must transfer sufficient allowances into their assurance account by November 1, 2017, and those allowances can have vintages of 2017 or of any prior year.
When an allowance surrender is required under the assurance provisions, does it matter to which compliance accounts the allowances to be surrendered were originally allocated? For instance, must the surrendered allowances have originally been allocated to compliance accounts in the same state whose emissions caused the surrender requirement?
- No. All that is required is that the owners and operators transfer into their assurance account the proper amount of allowances with the appropriate vintage years (as described in the immediately preceding Q & A) by the November 1 deadline. It doesn't matter to which accounts the allowances were originally allocated.
Can EPA or the state take enforcement actions seeking discretionary penalties against the owners and operators who must surrender additional allowances under the assurance provisions?
- It is not a violation of the Clean Air Act (CAA) to be required to surrender additional allowances under the assurance provisions. Since such a surrender is not a violation of the Act, discretionary penalties under CAA section 113 do not apply. However, failure to hold the required amount of allowances in the appropriate assurance account by the November 1 deadline is a violation of the CAA.