| (i) use the methods specified in 40 CFR Part 75, Subpart D; or (ii) use calculations in accordance with §117.8110(b) of this title (relating to Emission Monitoring System Requirements for Utility Electric Generation Sources); or (D) use the maximum block one-hour emission rate as measured during the initial demonstration of compliance required in §117.335(f) of this title (relating to Initial Demonstration of Compliance); or (E) use the following procedures: (i) for NOX monitor downtime periods less than 24 consecutive hours, use the maximum block one-hour NOX emission rate, in lb/MMBtu, from the previous 24 operational hours of the unit; (ii) for NOX monitor downtime periods equal to or greater than 24 consecutive hours, use the maximum block one-hour NOX emission rate, in lb/MMBtu, from the previous 720 operational hours of the unit; and (iii) if the fuel flow or stack exhaust flow monitor required by subsection (a) of this section is off-line simultaneous with the NOX monitor downtime, the owner or operator shall use the maximum block one-hour NO X pound per hour emission rate for the substitute data under clause (i) or (ii) of this subparagraph in lieu of the lb/MMBtu emission rate. (d) Ammonia monitoring requirements. The owner or operator of units that are subject to the ammonia emission specifications of §117.310(c)(2) of this title shall comply with the ammonia monitoring requirements of §117.8130 of this title (relating to Ammonia Monitoring). (e) CO monitoring. The owner or operator shall monitor CO exhaust emissions from each unit listed in subsection (c)(1) of this section using one or more of the methods specified in §117.8120 of this title (relating to Carbon Monoxide (CO) Monitoring). (f) CEMS requirements. The owner or operator of any CEMS used to meet a pollutant monitoring requirement of this section shall comply with the following. (1) The CEMS must meet the requirements of §117.8100(a) of this title (relating to Emission Monitoring System Requirements for Industrial, Commercial, and Institutional Sources). (2) For units subject to §117.310 of this title: (A) all bypass stacks must be monitored, in order to quantify emissions directed through the bypass stack: (i) if the CEMS is located upstream of the bypass stack, then: (I) no effluent streams from other potential sources of NOX emissions may be introduced between the CEMS and the bypass stack; and (II) the owner or operator shall install, operate, and maintain a continuous monitoring system to automatically record the date, time, and duration of each event when the bypass stack is open; and (ii) process knowledge and engineering calculations may be used to determine volumetric flow rate for purposes of calculating mass emissions for each event when the bypass stack is open, provided that: (I) the maximum potential calculated flow rate is used for emission calculations; and (II) the owner or operator maintains, and makes available upon request by the executive director, records of all process information and calculations used for this determination; and (B) exhaust streams of units that vent to a common stack do not need to be analyzed separately. (g) PEMS requirements. The owner or operator of any PEMS used to meet a pollutant monitoring requirement of this section shall comply with the following. (1) The PEMS must predict the pollutant emissions in the units of the applicable emission specifications of this division (relating to Houston-Galveston-Brazoria Ozone Nonattainment Area Major Sources). (2) The PEMS must meet the requirements of §117.8100(b) of this title. (h) Engine monitoring. The owner or operator of any stationary gas engine subject to §117.305 of this title that is not equipped with NOX CEMS or PEMS shall stack test engine NOX and CO emissions as specified in §117.8140(a) of this title (relating to Emission Monitoring for Engines). The owner or operator of any stationary internal combustion engine subject to §117.310 of this title that is not equipped with NOX CEMS or PEMS shall stack test engine NOX and CO emissions as specified in §117.8140(a) and (b) of this title. (i) Monitoring for stationary gas turbines less than 30 MW. The owner or operator of any stationary gas turbine rated less than 30 MW using steam or water injection to comply with the emission specifications of §117.305 or §117.315 of this title (relating to Emission Specifications for Reasonably Available Control Technology (RACT) and Alternative Plant-Wide Emission Specifications) shall either: (1) install, calibrate, maintain, and operate a NOX CEMS or PEMS in compliance with this section and monitor CO in compliance with subsection (e) of this section; or (2) install, calibrate, maintain, and operate a continuous monitoring system to monitor and record the average hourly fuel and steam or water consumption: (A) the system must be accurate to within ± 5.0%; (B) the steam-to-fuel or water-to-fuel ratio monitoring data must constitute the method for demonstrating continuous compliance with the applicable emission specification of §117.305 or §117.315 of this title; and (C) steam or water injection control algorithms are subject to executive director approval. (j) Run time meters. The owner or operator of any stationary gas turbine or stationary internal combustion engine claimed exempt using the exemption of §117.303(a)(6)(D), (a)(10), (a)(11), (b)(2) or (b)(9) of this title shall record the operating time with an elapsed run time meter. Any run time meter installed on or after October 1, 2001, must be non-resettable. (k) Hydrogen (H2) monitoring. The owner or operator claiming the H2 multiplier of §117.305(b)(6) or §117.315(g)(4) or (h) of this title shall sample, analyze, and record every three hours the fuel gas composition to determine the volume percent H2. (1) The total H2 volume flow in all gaseous fuel streams to the unit must be divided by the total gaseous volume flow to determine the volume percent of H2 in the fuel supply to the unit. (2) Fuel gas analysis must be tested according to American Society for Testing and Materials (ASTM) Method D1945-81 or ASTM Method D2650-83, or other methods that are demonstrated to the satisfaction of the executive director and the United States Environmental Protection Agency to be equivalent. (3) A gaseous fuel stream containing 99% H2 by volume or greater may use the following procedure to be exempted from the sampling and analysis requirements of this subsection. (A) A fuel gas analysis must be performed initially using one of the test methods in this subsection to demonstrate that the gaseous fuel stream is 99% H2 by volume or greater. (B) The process flow diagram of the process unit that is the source of the H2 must be supplied to the executive director to illustrate the source and supply of the hydrogen stream. (C) The owner or operator shall certify that the gaseous fuel stream containing H2 will continuously remain, as a minimum, at 99% H2 by volume or greater during its use as a fuel to the combustion unit. (l) Data used for compliance. (1) After the initial demonstration of compliance required by §117.335 of this title, the methods required in this section must be used to determine compliance with the emission specifications of §117.305 of this title. For enforcement purposes, the executive director may also use other commission compliance methods to determine whether the source is in compliance with applicable emission limitations. (2) For units subject to §117.310(a) of this title, the methods required in this section must be used in conjunction with the requirements of Chapter 101, Subchapter H, Division 3 of this title (relating to Mass Emissions Cap and Trade Program) to determine compliance. For enforcement purposes, the executive director may also use other commission compliance methods to determine whether the source is in compliance with applicable emission limitations. (m) Enforcement of NOX RACT limits. If compliance with §117.305 of this title is selected, no unit subject to §117.305 of this title may be operated at an emission rate higher than that allowed by the emission specifications of §117.305 of this title. If compliance with §117.315 of this title is selected, no unit subject to §117.315 of this title may be operated at an emission rate higher than that approved by the executive director under §117.352(b) of this title (relating to Final Control Plan Procedures for Cont'd... |
