Current through Reg. 50, No. 13; March 28, 2025
(a) Emission specifications for the Mass Emission Cap and Trade Program. The owner or operator of each utility boiler, auxiliary steam boiler, or stationary gas turbine shall ensure that emissions of nitrogen oxides (NOX) do not exceed the lower of any applicable permit limit in a permit issued before January 2, 2001; any permit issued on or after January 2, 2001, that the owner or operator submitted an application determined to be administratively complete by the executive director before January 2, 2001; any limit in a permit by rule under which construction commenced by January 2, 2001; or the following rates, in pounds per million British thermal units (lb/MMBtu) heat input, on the basis of daily and 30-day averaging periods as specified in §
117.1220 of this title (relating to System Cap), and as specified in the mass emissions cap and trade program of Chapter 101, Subchapter H, Division 3 of this title (relating to Mass Emissions Cap and Trade Program):
(1) utility boilers:
(A) gas-fired, 0.030; and
(B) coal-fired or oil-fired:
(i) wall-fired, 0.050; and
(ii) tangential-fired, 0.045;
(2) auxiliary steam boilers, 0.030; and
(3) stationary gas turbines (including duct burners used in turbine exhaust ducts), 0.032.
(b) Related emissions. No person shall allow the discharge into the atmosphere from any unit subject to subsection (a) of this section:
(1) carbon monoxide (CO) emissions in excess of 400 parts per million by volume (ppmv) at 3.0% oxygen (O2), dry (or alternatively, 0.30 lb/MMBtu heat input for gas-fired units, 0.31 lb/MMBtu heat input for oil-fired units, and 0.33 lb/MMBtu heat input for coal-fired units), based on:
(A) a one-hour average for units not equipped with a continuous emissions monitoring system (CEMS) or predictive emissions monitoring system (PEMS) for CO; or
(B) a rolling 24-hour averaging period for units equipped with CEMS or PEMS for CO; and
(2) for units that inject urea or ammonia into the exhaust stream for NOX control, ammonia emissions in excess of 10 ppmv, at 3.0% O2, dry, for boilers and 15% O2, dry, for stationary gas turbines (including duct burners used in turbine exhaust ducts), based on:
(A) a block one-hour averaging period for units not equipped with a CEMS or PEMS for ammonia; or
(B) a rolling 24-hour averaging period for units equipped with CEMS or PEMS for ammonia.
(c) Compliance flexibility.
(1) An owner or operator may petition the executive director for an alternative to the CO or ammonia specifications of this section in accordance with §
117.1225 of this title (relating to Alternative Case Specific Specifications).
(2) Section 117.1215 of this title (relating to Alternative System-Wide Emission Specifications) and §
117.1225 of this title are not alternative methods of compliance with the NOX emission specifications of this section.
(3) For units that meet the definition of electric generating facility (EGF), the owner or operator shall use both the methods specified in §
117.1220 of this title and the mass emissions cap and trade program in Chapter 101, Subchapter H, Division 3 of this title to comply with the NOX emission specifications of this section. An owner or operator may use the alternative methods specified in §
117.9800 of this title (relating to Use of Emission Credits for Compliance) for purposes of complying with §
117.1220 of this title.
(4) For units that do not meet the definition of EGF, the owner or operator shall use the mass emissions cap and trade program in Chapter 101, Subchapter H, Division 3 of this title to comply with the NO X emission specifications of this section.
