Statutes, codes, and regulations
Texas Administrative Code
Title 30 - ENVIRONMENTAL QUALITYPart 1 - TEXAS COMMISSION ON ENVIRONMENTAL QUALITYChapter 112 - CONTROL OF AIR POLLUTION FROM SULFUR COMPOUNDSSubchapter E - REQUIREMENTS IN THE HOWARD COUNTY NONATTAINMENT AREA
Division 1 - REQUIREMENTS FOR THE ALON USA BIG SPRING REFINERY
Section 112.103 - Monitoring Requirements

30 Tex. Admin. Code § 112.103

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Current through Reg. 49, No. 44; November 1, 2024
Section 112.103 - Monitoring Requirements

The owner or operator shall continuously monitor equipment subject to sulfur dioxide (SO2) emission limits or standards in § 112.102 of this title (relating to Control Requirements) as follows:

(1) install, operate, calibrate, and maintain a continuous emissions monitoring system (CEMS) as specified in 40 Code of Federal Regulations (CFR) §60.105a(g)(1), (2) and (5) regardless of whether these provisions otherwise apply; use an analyzer with a minimum analyzer accuracy of plus or minus (±) 2.5%, a dedicated totalizing gas flow measurement system with a minimum measurement accuracy of ±5%, and a temperature monitor with a minimum accuracy of ±1%; convert data from all monitoring devices to a common concentration, flow, pressure, and temperature basis, and calculate and record 15-minute and subsequent block one-hour average SO2 emissions from FCCU ESP Stack (EPN 06ESPPCV);
(2) for the North East Flare (EPN 14NEASTFLR), Crude Flare (EPN 02CRUDEFLR), Reformer Flare (EPN 05REFMFLR), and South Flare (EPN 16SOUTHFLR), install, operate, calibrate, and maintain designated instrumentation according to the manufacturers' specifications to continuously monitor the gas stream flare inlet temperature, the total inlet gas flow rate, and the total sulfur concentration as specified in 40 CFR § 60.107a(e) and (f)(1), regardless of whether these provisions otherwise apply or exempt flare activities, as follows:
(A) monitor the total volumetric flow rate of gases routed to each flare using a separate dedicated totalizing gas flow meter with an accuracy of ±5%;
(B) monitor the temperature of gases routed to each flare using a separate temperature measurement device with an accuracy of ±1%; and
(C) monitor the sulfur content of the combined inlet flare gas stream as follows:
(i) using a separate dedicated analyzer capable of accurately measuring and recording total sulfur (including sulfur dioxide (SO2), hydrogen sulfide (H2S), and organic sulfur compounds levels) with an accuracy of ±5% on a continuous basis, the sulfur concentration must be determined in accordance 40 CFR § 60.107a(e)(1) regardless of whether these requirements are otherwise applicable or exempt the flare, and hourly SO2 emissions must be determined using the following equation; or

Attached Graphic

(ii) using a separate dedicated analyzer capable of accurately measuring and recording H2S to an accuracy of ±5% on a continuous basis, determine the H2S concentration in the flared gas stream, derive an inlet flare gas total sulfur concentration for each monitored hourly H2S concentration in accordance with 40 CFR § 60.107a(e)(2) methodology regardless of whether these requirements are otherwise applicable or exempt the flare, and calculate the SO2 emissions for each operating hour using the following equation:

Attached Graphic

(3) separately for SRU1 Incinerator Stack (EPN 69TGINC) and SRU2 Incinerator Stack (EPN 71TGINC), install, operate, calibrate, and maintain a CEMS as specified in 40 CFR § 60.106a(a), regardless of whether these provisions otherwise apply; use an analyzer with a minimum accuracy of ±2.5%, a dedicated totalizing gas flow measurement system with an accuracy of ±5%, and temperature indicator with an accuracy of ±1% convert data from all monitoring devices to a common concentration, flow, pressure, and temperature basis and calculate and record 15-minute and subsequent block one-hour average SO2 emissions;
(4) continuous monitoring data collected in accordance with requirements in this subsection must undergo an appropriate quality assurance and quality control process and be validated for at least 95% of the time that the monitored emission point has emissions; an owner or operator must utilize the most accurate data substitution methodology available that is at least equivalent to engineering judgement and replace all missing or invalidated monitoring data for the entire period the monitored emission point has emissions; and
(5) minor modifications to monitoring methods may be approved by the executive director. Monitoring methods other than those specified in this section may be used if approved by the executive director and validated by 40 CFR Part 63 , Appendix A, Test Method 301. For the purposes of this subsection, substitute "executive director" in each place that Test Method 301 references "administrator." These validation procedures may be waived by the executive director or a different protocol may be granted for site-specific applications. Minor modifications that may be approved under this subsection include increases in the frequency of monitoring and the replacement of parametric monitoring with direct emissions monitoring with a CEMS provided appropriate quality assurance control, accuracy specifications, and data validation requirements are specified and no less stringent than monitoring requirements for a comparable EPN in this division.

30 Tex. Admin. Code § 112.103

Adopted by Texas Register, Volume 47, Number 42, October 21, 2022, TexReg 7038, eff. 10/27/2022