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HomeMy WebLinkAboutDAQ-2024-007590 1 DAQC-384-24 Site ID 10119 (B5) MEMORANDUM TO: FILE – CHEVRON PRODUCTS COMPANY THROUGH: Harold Burge, Major Source Compliance Section Manager FROM: Rob Leishman, Environmental Scientist DATE: April 25, 2024 SUBJECT: Chevron Products Company (Chevron), Major, NSPS, Title V, MACT, Davis County – FRS #UT00000049001100003 INSPECTION TYPE: State Electronic Data Report (SEDR) Review REVIEW DATE: April 25, 2024 SOURCE LOCATION: North Salt Lake/Davis County SOURCE CONTACT: Tony Pollock – 801-539-7162 APPLICABLE REGULATIONS: Approval Order (AO) dated 8/24/2022 – DAQE-AN101190106-22 SOURCE REVIEW EVALUATION: With the exception of sources that only monitor for opacity, quarterly report memoranda will only address the findings of the quarterly report. Approval Order and Title V permit conditions addressing continuous emission monitoring requirements will be addressed in Chevron’s relative accuracy performance specification test review memorandum. SEDR REVIEW: First Quarter 2024 % Monitor Availability (MA) Performance Test Dates (N/A to Opacity) Summary of Excess Emissions During Point Source Operation Point Source Op. hrs. Channel MA CGA Lin RATA Point Source Channel Hrs. Limitation Boiler #7 2184 NOx 99% 02/12/24 08/16/23 FCC Regenerator Vent Opacity 21.90 30 % - 6min Boiler #7 2184 O2 98% 02/12/24 08/16/23 FCC Regenerator Vent Opacity 23.00 20 % - 3hrRA FCC Regenerator Vent 2184 Opacity 100% FCC Regenerator Vent SO2 0.00 50 ppm - 7dRA 1 8 2 2 First Quarter 2024 % Monitor Availability (MA) Performance Test Dates (N/A to Opacity) Summary of Excess Emissions During Point Source Operation Point Source Op. hrs. Channel MA CGA Lin RATA Point Source Channel Hrs. Limitation FCC Regenerator Vent 2184 CO 98% 02/12/24 08/14/23 FCC Regenerator Vent SO2 0.00 25 ppm - 365dRA FCC Regenerator Vent 2184 NOx 98% 02/12/24 08/14/23 FCC Regenerator Vent NOx 0.00 106 ppm - 7dRA FCC Regenerator Vent 2184 SO2 98% 02/12/24 08/14/23 FCC Regenerator Vent NOx 0.00 80 ppm - 7dRA FCC Regenerator Vent 2184 CO2 98% 02/12/24 08/14/23 FCC Regenerator Vent CO 20.00 500 ppm - hour FCC Regenerator Vent 2184 O2 98% 02/12/24 08/14/23 Flare #1 H2S 3.00 162 ppm - 3hrRA Flare #1 2184 H2S 95% 02/26/24 09/21/20 Flare #2 H2S 4.00 162 ppm - 3hrRA Flare #1 2184 TRS 98% 02/26/24 Flare #3 H2S 2.00 162 ppm - 3hrRA Flare #2 2184 H2S 95% 02/15/24 09/22/20 Fuel Gas Mix Point H2S 0.00 162 ppm - 3hrRA Flare #2 2184 TRS 96% 02/15/24 Fuel Gas Mix Point H2S 0.00 60 ppm - 365dRA Flare #3 2184 H2S 89% 01/31/24 08/24/23 SRU Tailgas Incinerator 1 SO2 0.00 250 ppm - 12hrRA Flare #3 2184 TRS 96% 01/31/24 SRU Tailgas Incinerator 2 SO2 0.00 250 ppm - 12hrRA Fuel Gas Mix Point 2184 H2S 98% 02/12/24 08/25/23 SRU Tailgas Incinerator 1 2184 SO2 98% 01/30/24 08/15/23 SRU Tailgas Incinerator 1 2184 O2 92% 01/30/24 08/15/23 SRU Tailgas Incinerator 2 2184 SO2 100% 01/30/24 08/21/23 SRU Tailgas Incinerator 2 2184 O2 99% 01/30/24 08/21/23 Excess Emission Report - Hourly Summary Point Source Channel Startup & Shutdown Control Equipment Problems Process Problems Other Known Causes Unknown Causes Emission Limit FCC Regenerator Vent Opacity 0 0 21.9 0 0 30 % - 6min FCC Regenerator Vent Opacity 0 0 23 0 0 20 % - 3hrRA FCC Regenerator Vent SO2 0 0 0 0 0 50 ppm - 7dRA FCC Regenerator Vent SO2 0 0 0 0 0 25 ppm - 365dRA 3 Excess Emission Report - Hourly Summary Point Source Channel Startup & Shutdown Control Equipment Problems Process Problems Other Known Causes Unknown Causes Emission Limit FCC Regenerator Vent NOx 0 0 0 0 0 106 ppm - 7dRA FCC Regenerator Vent NOx 0 0 0 0 0 80 ppm - 7dRA FCC Regenerator Vent CO 0 0 20 0 0 500 ppm - hour Flare #1 H2S 0 3 0 0 0 162 ppm - 3hrRA Flare #2 H2S 0 4 0 0 0 162 ppm - 3hrRA Flare #3 H2S 0 2 0 0 0 162 ppm - 3hrRA Fuel Gas Mix Point H2S 0 0 0 0 0 162 ppm - 3hrRA Fuel Gas Mix Point H2S 0 0 0 0 0 60 ppm - 365dRA SRU Tailgas Incinerator 1 SO2 0 0 0 0 0 250 ppm - 12hrRA SRU Tailgas Incinerator 2 SO2 0 0 0 0 0 250 ppm - 12hrRA CMS Performance Summary - Hourly Summary Point Source Channel Monitor Malfunction Non-monitor Malfunction QA Calibrations Other Known Causes Unknown Causes Boiler #7 NOx 0 1 0 14 0 Boiler #7 O2 29 1 0 14 0 FCC Regenerator Vent Opacity 1 0 0 2 0 FCC Regenerator Vent CO 0 0 46 5 0 FCC Regenerator Vent NOx 0 0 46 5 0 FCC Regenerator Vent SO2 0 0 46 5 0 FCC Regenerator Vent CO2 0 0 46 5 0 FCC Regenerator Vent O2 0 0 46 5 0 Flare #1 H2S 78 0 22 4 0 Flare #1 TRS 43 0 0 4 0 Flare #2 H2S 65 0 38 5 0 Flare #2 TRS 89 0 7 1 0 Flare #3 H2S 216 0 21 8 0 Flare #3 TRS 34 0 0 62 0 Fuel Gas Mix Point H2S 0 0 34 1 0 SRU Tailgas Incinerator 1 SO2 1 51 0 1 0 SRU Tailgas Incinerator 1 O2 75 99 0 1 0 SRU Tailgas Incinerator 2 SO2 0 0 2 3 0 SRU Tailgas Incinerator 2 O2 25 0 2 1 0 4 Type Code 280 (COMS Attenuator Filters) Procedure 3 Point Source & Location Attenuator I.D. Attenuator Certification Date Certified Attenuator Opacity OPLR, SECR, or PLCF, Corrected Opacity Value Range Low, Mid, & High Certification 1-year or 5- year FCC Regenerator Vent Flue Gas Duct DHT200 /14108330 2/21/23 12.90 0.90 22 Low 1 Year FCC Regenerator Vent Flue Gas Duct DHT200 /14108330 2/21/23 24.60 0.90 39.83 Mid 1 Year FCC Regenerator Vent Flue Gas Duct DHT200 /14108330 2/21/23 36.80 0.90 56.33 High 1 Year Type Code 281 (Procedure 3 - COMS Filter Audit Calibration Error) Point Source Location Audit Date Opacity Monitor Response (Average of 5) Mean Difference Calibration Error (≤ 3%) Low Mid High FCC Regenerator Vent Flue Gas Duct 2/6/24 7 0.040 0.224 FCC Regenerator Vent Flue Gas Duct 2/6/24 7 0.600 0.736 FCC Regenerator Vent Flue Gas Duct 2/6/24 7 -0.010 0.236 Pollutant Concentration Exceeded Span of CEM Monitor Outage During Point Source Operation Alternate Sampling CEM Modifications 19 Hours 1299 Hours 0 Hours 0 Events SOURCE INSPECTION SUMMARY EVALUATION: Chevron maintains its CEMS as required in R307-170 and 40 CFR 60.13. CURRENT RECOMMENDATIONS: All deviations appear to be a result of breakdown or process related problems that do not warrant issuing a violation. Chevron was in compliance during this reporting period. No further enforcement actions should be taken. Chevron’s NSPS monitoring system meets the performance standards of 40 CFR 60, Appendix B Performance Specifications. HIGH PRIORITY VIOLATOR (HPV): No RECOMMENDATION FOR NEXT INSPECTION: Check DAS for daily zero and span drift. Check the QC program to ensure that monitor drift is being tracked and that the source can identify excessive drift. ATTACHMENTS: Excel spreadsheet review Chevron Troy Tortorich Chevron Products Company Refinery Manager Salt Lake Refinery 685 South Chevron Way North Salt Lake, Utah 84054 Tel 801 539 7200 April 23, 2024 CERTIFIED MAIL RETURN RECEIPT #7018 0680 0001 4890 0352 Mr. Bryce Bird, Director Division of Air Quality Utah Department of Environmental Quality 1' QUARTER 2024 CEM REPORT State Electronic Data Report (SEDR) Dear Mr. Bird, Chevron Products Company Salt Lake Refinery submits the Quarterly Report in ASCII Electronic Format for the 1St quarter of 2024. This is in accordance with UACR 307-170 and applicable 40 CFR 60 subparts A, J, and Ja requirements. This report contains data on the following monitoring systems: " Boiler 7 N0x,O2CEM " FCC regenerator opacity COMS " FCC regenerator CO, C02 NOx, SO2, and 02 CEM " Fuel Gas H25 CEM " Flare I H25, TRS CEM " Flare 2 H2S, TRS CEM " Flare 3 H25, TRS CEM " SRU 1SO2and02CEM " SRU2S02and02CEM As per the EPA response letter attached, the approved alternative test method to the relative accuracy test for H2S CEMS has been used at Flare 1 and Flare 2. If you have any questions regarding the CEM Report, please contact Tony Pollock at 801-539-7162 or dlff(chevron.com. I certi' under penalty of law that all information contained in the report is truthful and accurate and is a complete record of all monitoring related events which occurred during the 151 quarter of 2024. Sincerely, Troy Tortorich Chevron Refinery EER 1Q2024 Point Source Information Late Expired Cal. Gas Valid Cal. Gas Days Yes No 1 Type Code 100 (Company Information)Type Code Company Manager Company Name AIRS # Phone Number Environmental Contact 1 100 Troy Tortorich 01100003 (801) 539-7162 Tony Pollock 1 100 0 0 0 0 1 Type Code 110 (Point Source Identification)Type Code Point Source Quarter 1 - 4 Year Point Source Operating Hrs. in Quarter 1 110 1 2024 2184 1 110 1 2024 2184 1 110 1 2024 2184 1 110 1 2024 2184 1 110 1 2024 2184 1 110 1 2024 2184 1 110 1 2024 2184 1 110 1 2024 2184 1 110 0 0 0 1 Type Code 200 (Monitor Identification)Type Code Point Source Channel Manufacturer Model No. Monitor SN Low Span High Span Installation Date Monitor Location 1 200 NOx Ametek Western Research9900 ZE-9900-10941-1 0 500 8/17/2018 F11007 1 200 O2 Ametek Western Research9900 ZE-9900-10941-1 0 21 8/17/2018 F11007 1 200 CO Siemens Ultramat 6 J6-783 0 1000 4/16/2020 K3223 1 200 CO2 Siemens Ultramat 6/Oxymat 6J7-447 0 25 4/16/2020 K3223 1 200 NOx Ametek Western Research9900 ZW-9900-S1334-10 200 4/16/2020 K3223 1 200 O2 Siemens Ultramat 6/Oxymat 6J7-447 0 10 4/16/2020 K3223 1 200 Opacity Sick/Maihak DHT200 0 100 10/5/2013 K3223 1 200 SO2 Siemens Ultramat 6E J6-783 0 200 4/16/2020 K3223 1 200 H2S Siemens Maxum Edition II #300194969000100 300 2/3/2010 V75220 1 200 TRS Atom FGA-100 140011 0 250000 11/5/2015 V75220 1 200 H2S Siemens Maxum Edition II #300194969000200 300 11/5/2010 V75120 1 200 TRS Atom FGA-100 140012 0 250000 11/4/2015 V75120 1 200 H2S Siemens Maxum Edition II #3001946900020 0 300 11/6/2019 D35014 1 200 TRS Atom FGA-100 18002 0 250000 11/6/2019 D35014 1 200 H2S Siemens Maxum Edition II #30019536380010ump 300 12/6/2009 V-113 1 200 O2 Ametek Ametek 9900 ZW-9900-S1332-10 21 9/1/2021 F-6550 1 200 SO2 Ametek Ametek 9900 ZW-9900-S1332-10 500 9/1/2021 F-6550 1 200 O2 Ametek Ametek 9000 AV9000WM-10235-1A0 21 12/16/2010 F-68250 1 200 SO2 Ametek Ametek 9000 AV9000WM-10235-1A0 500 12/16/2010 F-68250 1 200 0 0 0 0 0 0 1/0/1900 0 1 Type Code310 (Excess Emissions) SUMMARY REPORT Type Code Channel Total Hours of Excess Emissions Excess Emissions - % of Total Operating Hours RC 701 Hours - start up/Shutdown RC 702 Hours- Control Equipment Problems RC 703 Hours - Process Problems RC 704, 706, 707 Hours -Other Known Causes RC 705 Hours - Unknown Causes Emission Limitation Emission Limitation Units Emission Limitation Averaging Period 1 TRUE 310 Opacity 21.9 1.00% 0 0 21.9 0 0 30 % 6min 1 TRUE 310 Opacity 23 1.05% 0 0 23 0 0 20 % 3hrRA 1 TRUE 310 SO2 0 0.00% 0 0 0 0 0 50 ppm 7dRA 1 TRUE 310 SO2 0 0.00% 0 0 0 0 0 25 ppm 365dRA 1 TRUE 310 NOx 0 0.00% 0 0 0 0 0 106 ppm 7dRA 1 TRUE 310 NOx 0 0.00% 0 0 0 0 0 80 ppm 7dRA 1 TRUE 310 CO 20 0.92% 0 0 20 0 0 500 ppm hour 1 TRUE 310 H2S 3 0.14% 0 3 0 0 0 162 ppm 3hrRA 1 TRUE 310 H2S 4 0.18% 0 4 0 0 0 162 ppm 3hrRA 1 TRUE 310 H2S 2 0.09% 0 2 0 0 0 162 ppm 3hrRA 1 TRUE 310 H2S 0 0.00% 0 0 0 0 0 162 ppm 3hrRA 1 TRUE 310 H2S 0 0.00% 0 0 0 0 0 60 ppm 365dRA 1 TRUE 310 SO2 0 0.00% 0 0 0 0 0 250 ppm 12hrRA 1 TRUE 310 SO2 0 0.00% 0 0 0 0 0 250 ppm 12hrRA 1 310 0 0 0 0 0 0 0 0 0 1 Type Code 300 (CMS Performance Summary) Type Code Channel Point Source Operating Hours Downtime - % of Total Operating Hours Total CMS Downtime RC 721 Hours - Monitor Malfunction RC 722 Hours - Non-monitor Malfunction RC 723 Hours - QA Calibrations RC 724 Hours - Other Known Causes RC 725 Hours - Unknown Causes 1 TRUE 300 NOx 2184 0.68% 14.75 0 0.5 0 14.25 0 1 TRUE 300 O2 2184 1.99% 43.5 29.25 0.5 0 13.75 0 1 TRUE 300 Opacity 2184 0.11% 2.4 0.8 0 0 1.6 0 1 TRUE 300 CO 2184 2.29% 50 0 0 45.5 4.5 0 1 TRUE 300 NOx 2184 2.29% 50 0 0 45.5 4.5 0 1 TRUE 300 SO2 2184 2.29% 50 0 0 45.5 4.5 0 1 TRUE 300 CO2 2184 2.29% 50 0 0 45.5 4.5 0 1 TRUE 300 O2 2184 2.29% 50 0 0 45.5 4.5 0 1 TRUE 300 H2S 2184 4.75% 103.75 78 0 22.25 3.5 0 1 TRUE 300 TRS 2184 2.16% 47.25 43 0 0 4.25 0 1 TRUE 300 H2S 2184 4.92% 107.5 64.75 0 37.75 5 0 1 TRUE 300 TRS 2184 4.40% 96 88.5 0 7 0.5 0 1 TRUE 300 H2S 2184 11.17% 244 216 0 20.5 7.5 0 1 TRUE 300 TRS 2184 4.38% 95.75 33.5 0 0 62.25 0 1 TRUE 300 H2S 2184 1.59% 34.75 0 0 34.25 0.5 0 1 TRUE 300 SO2 2184 2.42% 52.75 0.75 51.25 0 0.75 0 1 TRUE 300 O2 2184 7.99% 174.5 74.75 99.25 0 0.5 0 1 TRUE 300 SO2 2184 0.21% 4.5 0 0 1.5 3 0 1 TRUE 300 O2 2184 1.26% 27.5 25 0 1.5 1 0 1 300 0 0 0 0 0 0 SRU Tailgas Incinerator 1 SRU Tailgas Incinerator 2 0 Flare #3 Flare #1 Flare #1 Flare #2 Flare #2 Flare #3 Fuel Gas Mix Point SRU Tailgas Incinerator 1 SRU Tailgas Incinerator 1 SRU Tailgas Incinerator 2 SRU Tailgas Incinerator 2 0 Chevron Products Co. 0 Boiler #7 Boiler #7 FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent Flare #1 Flare #1 Flare #2 FCC Regenerator Vent FCC Regenerator Vent Flare #1 Flare #2 Flare #3 FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent Fuel Gas Mix Point Fuel Gas Mix Point Boiler #7 Boiler #7 FCC Regenerator Vent SRU Tailgas Incinerator 2 0 SRU Tailgas Incinerator 2 Boiler #7 FCC Regenerator Vent Flare #1 Flare #2 Flare #3 Fuel Gas Mix Point SRU Tailgas Incinerator 1 SRU Tailgas Incinerator 2 0 SRU Tailgas Incinerator 1 Flare #2 Flare #3 Flare #3 Fuel Gas Mix Point SRU Tailgas Incinerator 1 Point Source Point Source Chevron Refinery EER 1Q2024 1 Type Code 250 (Performance Specification RATA Results) Type Code Channel Date of Most Current RATA Date of Preceding RATA Months Between RATA's Units of Measurement CEM Value Reference Method Value Relative accuracy Pass/ Fail 1 365 Days 250 NOx 08/16/23 08/16/22 12 ppm 0.074 0.075 2.25% P 1 365 Days 250 O2 08/16/23 08/16/22 12 0 4.826 4.828 0.33% P 1 325 Days 250 SO2 08/14/23 09/23/22 12 ppm 16.9 15.667 9.07% P 1 326 Days 250 NOx 08/14/23 09/22/22 12 ppm 41.532 42.389 3.51% P 1 326 Days 250 CO 08/14/23 09/22/22 12 ppm 26.918 26.433 2.06% P 1 326 Days 250 CO2 08/14/23 09/22/22 12 ppm 17.28 16.978 1.93% P 1 326 Days 250 O2 08/14/23 09/22/22 12 0 2.12 2.12 1.31% P 1 0 Days 250 H2S 09/21/20 09/21/20 12 ppm 8.9 5.81 3.30% P 1 0 Days 250 H2S 09/22/20 09/22/20 12 ppm 8.29 5.39 2.93% P 1 373 Days 250 H2S 08/24/23 08/16/22 12 ppm 0 2.26 1.60% P 1 374 Days 250 H2S 08/25/23 08/16/22 12 ppm 0.04 1.95 1.25% P 1 364 Days 250 SO2 08/15/23 08/16/22 12 ppm 107.369 114.978 7.91% P 1 364 Days 250 SO2 08/15/23 08/16/22 12 lb./hr. 1.743 1.992 3.10% P 1 364 Days 250 O2 08/15/23 08/16/22 12 0 4.084 4.133 5.00% P 1 334 Days 250 SO2 08/21/23 09/21/22 12 ppm 132.091 135.895 5.82% P 1 334 Days 250 SO2 08/21/23 09/21/22 12 lb./hr. 3.251 3.407 10.41% P 1 334 Days 250 O2 08/21/23 09/21/22 12 0 7.17 7.844 3.00% P 1 0 Days 250 0 01/00/00 01/00/00 0 0 0 0 0.00% 0 1 Type Code 260 (CGA Results)Type Code Channel Date Audit Point No. Cylinder ID Cylinder Expiration Date Type of Certification Units of Measurement CEM Value Cylinder Value Precision %Pass/ Fail Range - High or Low 1 Valid Cal. Gas 260 NOx 02/12/24 1 CC63048 06/02/31 EPA Traceability Protocol (Sept. 1997)ppm 134.4 135.4 -74.00% P Low 1 Valid Cal. Gas 260 NOx 02/12/24 2 CC3688 06/02/31 EPA Traceability Protocol (Sept. 1997)ppm 277.4 276.1 48.00% P High 1 Valid Cal. Gas 260 O2 02/12/24 1 EB0027762 06/02/31 EPA Traceability Protocol (Sept. 1997)ppm 4.9 5 -317.00% P High 1 Valid Cal. Gas 260 O2 02/12/24 2 CC316355 05/01/26 EPA Traceability Protocol (Sept. 1997)ppm 8.1 8 50.00% P High 1 Valid Cal. Gas 260 CO 02/12/24 1 CC96320 06/02/31 EPA Traceability Protocol (Sept. 1997)ppm 247.3 249.9 -105.00% P Low 1 Valid Cal. Gas 260 CO 02/12/24 2 EB0157339 08/02/31 EPA Traceability Protocol (Sept. 1997)ppm 541.7 552.2 -190.00% P High 1 Valid Cal. Gas 260 CO2 02/12/24 1 CC200802 03/20/31 EPA Traceability Protocol (Sept. 1997)ppm 6.3 6.5 -353.00% P Low 1 Valid Cal. Gas 260 CO2 02/12/24 2 CC487479 03/02/31 EPA Traceability Protocol (Sept. 1997)ppm 13.9 14 -64.00% P High 1 Valid Cal. Gas 260 NOx 02/12/24 1 CC320573 01/03/31 EPA Traceability Protocol (Sept. 1997)ppm 56.8 55.5 241.00% P Low 1 Valid Cal. Gas 260 NOx 02/12/24 2 CC262317 05/23/30 EPA Traceability Protocol (Sept. 1997)ppm 110.6 111.1 -45.00% P High 1 Valid Cal. Gas 260 O2 02/12/24 1 EB0109000 08/17/26 EPA Traceability Protocol (Sept. 1997)% 5.1 5 100.00% P Low 1 Valid Cal. Gas 260 O2 02/12/24 2 EB0141908 05/31/31 EPA Traceability Protocol (Sept. 1997)% 8.1 8.1 50.00% P High 1 Valid Cal. Gas 260 SO2 02/12/24 1 CC733445 08/22/30 EPA Traceability Protocol (Sept. 1997)ppm 55.7 55.08 109.00% P Low 1 Valid Cal. Gas 260 SO2 02/12/24 2 SG912146BAL 08/29/30 EPA Traceability Protocol (Sept. 1997)ppm 110.8 110.3 45.00% P High 1 Valid Cal. Gas 260 H2S 02/26/24 1 CC102694 10/12/24 EPA PROTOCOL II GASppm 64.1 68.99 -704.00% P Low 1 Valid Cal. Gas 260 H2S 2/26/24 2 ALM035540 10/14/24 EPA PROTOCOL II GASppm 149 157 -5 P High 1 Valid Cal. Gas 260 TRS 2/26/24 1 CC97784 12/16/24 EPA PROTOCOL II GASppm 12,147 12,526 -3 P Low 1 Valid Cal. Gas 260 TRS 2/26/24 2 EB0140133 9/21/25 EPA PROTOCOL II GASppm 23,891 27,571 -13 P High 1 Valid Cal. Gas 260 H2S 2/15/24 1 ALM040013 6/30/24 EPA PROTOCOL II GASppm 69 70 -2 P Low 1 Valid Cal. Gas 260 H2S 2/15/24 2 CC90612 6/9/26 EPA PROTOCOL II GASppm 158 159 -1 P High 1 Valid Cal. Gas 260 TRS 2/15/24 1 CC341983 12/4/26 EPA PROTOCOL II GASppm 13,066 12,657 3 P Low 1 Valid Cal. Gas 260 TRS 2/15/24 2 EB0155296 4/13/26 EPA PROTOCOL II GASppm 26,559 27,525 -4 P High 1 Valid Cal. Gas 260 H2S 1/31/24 1 CC148981 5/28/26 EPA PROTOCOL II GASppm 70 70 -1 P Low 1 Valid Cal. Gas 260 H2S 1/31/24 2 D946638 5/18/26 EPA PROTOCOL II GASppm 146 157 -7 P High 1 Valid Cal. Gas 260 TRS 1/31/24 1 CC231302 4/26/25 EPA PROTOCOL II GASppm 2,338 2,491 -6 P Low 1 Valid Cal. Gas 260 TRS 1/31/24 2 CC260070 12/17/24 EPA PROTOCOL II GASppm 5,196 5,553 -6 P High 1 Valid Cal. Gas 260 H2S 2/12/24 1 ALM032841 3/8/24 EPA Traceability Protocol (Sept. 1997)ppm 68 70 -3 P Low 1 Valid Cal. Gas 260 H2S 2/12/24 2 CC47722 3/9/24 EPA Traceability Protocol (Sept. 1997)ppm 160 162 -1 P High 1 Valid Cal. Gas 260 O2 1/30/24 1 ALM054666 4/26/27 EPA Traceability Protocol (Sept. 1997)ppm 5 5 -3 P Low 1 Valid Cal. Gas 260 O2 1/30/24 2 EB0089076 8/7/28 EPA Traceability Protocol (Sept. 1997)ppm 8 8 -3 P High 1 Valid Cal. Gas 260 SO2 1/30/24 1 CC107467 8/29/30 EPA Traceability Protocol (Sept. 1997)ppm 127 126 1 P Low 1 Valid Cal. Gas 260 SO2 1/30/24 2 EB0134129 11/22/29 EPA Traceability Protocol (Sept. 1997)ppm 249 252 -1 P High 1 Valid Cal. Gas 260 O2 1/30/24 1 EB0105270 5/31/30 EPA Traceability Protocol (Sept. 1997)ppm 5 5 -1 P Low 1 Valid Cal. Gas 260 O2 1/30/24 2 CC741651 8/23/29 EPA Traceability Protocol (Sept. 1997)ppm 8 8 -1 P High 1 Valid Cal. Gas 260 SO2 1/30/24 1 CC356043 11/1/27 EPA Traceability Protocol (Sept. 1997)ppm 119 123 -3 P Low 1 Valid Cal. Gas 260 SO2 1/30/24 2 ALM047181 2/1/27 EPA Traceability Protocol (Sept. 1997)ppm 244 250 -2 P High 1 260 0 1/0/00 0 0 1/0/00 0 0 0 0 0 0 0 1 Type Code 270 (Linearity Test Results)Type Code Channel Date Audit Point No. Cylinder ID Cylinder Expiration Date Type of Certification Units of Measurement CEM Value Cylinder Value Precision %Pass/ Fail Range - High or Low 1 270 0 01/00/00 0 0 01/00/00 0 0 0 0 0.00% 0 0 1 Type Code 210 (Pollutant Concentration Exceeded Span of CEM) Type Code Channel Start Date Start Time End Date End Time Hours 1 19 210 H2S 1/31/24 14:17 1/31/24 14:34 0.28 1 19 210 H2S 1/31/24 15:00 1/31/24 15:04 0.07 1 38 210 H2S 3/19/24 11:49 3/19/24 12:11 0.37 1 TRUE 210 H2S 1/17/24 1:49 1/17/24 1:53 0.07 1 210 H2S 1/17/24 2:00 1/17/24 2:27 0.45 1 210 H2S 1/17/24 22:32 1/17/24 22:35 0.05 1 210 H2S 1/17/24 22:40 1/17/24 22:47 0.12 1 210 H2S 1/17/24 22:51 1/17/24 22:58 0.12 1 210 H2S 1/17/24 23:06 1/17/24 23:09 0.05 1 210 H2S 1/17/24 23:13 1/17/24 23:21 0.13 1 210 H2S 1/17/24 23:24 1/17/24 23:32 0.13 1 210 H2S 1/17/24 23:36 1/17/24 23:39 0.05 1 210 H2S 2/12/24 10:47 2/12/24 10:51 0.07 1 210 H2S 2/12/24 10:54 2/12/24 10:58 0.07 Flare #2 Flare #2 Flare #2 Flare #2 Flare #2 Flare #1 Flare #1 Flare #1 Flare #2 Flare #2 Flare #2 0 Flare #2 Boiler #7 Boiler #7 Flare #3 Flare #3 FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent Flare #2 Flare #2 Flare #2 Flare #1 SRU Tailgas Incinerator 1 SRU Tailgas Incinerator 2 SRU Tailgas Incinerator 2 SRU Tailgas Incinerator 2 SRU Tailgas Incinerator 2 0 Flare #3 Flare #3 Fuel Gas Mix Point Fuel Gas Mix Point SRU Tailgas Incinerator 1 SRU Tailgas Incinerator 1 SRU Tailgas Incinerator 1 Boiler #7 FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent Boiler #7 Boiler #7 SRU Tailgas Incinerator 2 Boiler #7 0 SRU Tailgas Incinerator 1 SRU Tailgas Incinerator 1 SRU Tailgas Incinerator 1 SRU Tailgas Incinerator 2 Point Source Point Source Point Source Point Source FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent Flare #1 Flare #1 Flare #1 Flare #2 Flare #2 Flare #2 SRU Tailgas Incinerator 2 FCC Regenerator Vent Flare #1 Flare #2 Flare #3 Fuel Gas Mix Point Chevron Refinery EER 1Q2024 1 210 H2S 2/12/24 11:02 2/12/24 11:06 0.07 1 210 H2S 2/12/24 11:09 2/12/24 11:12 0.05 1 210 H2S 2/12/24 11:28 2/12/24 11:32 0.07 1 210 H2S 2/12/24 11:39 2/12/24 11:43 0.07 1 210 H2S 2/12/24 11:47 2/12/24 11:54 0.12 1 210 H2S 2/12/24 12:01 2/12/24 12:06 0.08 1 210 H2S 2/12/24 12:09 2/12/24 12:17 0.13 1 210 H2S 2/12/24 12:21 2/12/24 12:25 0.07 1 210 H2S 2/12/24 12:27 2/12/24 12:43 0.27 1 210 H2S 2/15/24 13:01 2/15/24 13:04 0.05 1 210 H2S 3/19/24 18:23 3/19/24 18:43 0.33 1 210 H2S 3/19/24 19:01 3/19/24 19:05 0.07 1 210 H2S 1/16/24 14:04 1/16/24 15:22 1.30 1 210 H2S 1/31/24 14:17 1/31/24 14:34 0.28 1 210 H2S 1/31/24 15:00 1/31/24 15:04 0.07 1 210 H2S 3/19/24 11:49 3/19/24 12:11 0.37 1 210 SO2 2/12/24 10:16 2/12/24 10:22 0.10 1 210 SO2 2/12/24 10:27 2/12/24 10:32 0.08 1 210 SO2 2/12/24 10:38 2/12/24 10:43 0.08 1 210 CO 3/18/24 19:25 3/18/24 19:34 0.15 1 210 CO 3/18/24 23:56 3/19/24 0:00 0.07 1 210 CO 3/19/24 0:39 3/19/24 0:44 0.08 1 210 CO 3/19/24 1:29 3/19/24 1:34 0.08 1 210 CO 3/19/24 1:36 3/19/24 1:40 0.07 1 210 CO 3/19/24 1:43 3/19/24 1:52 0.15 1 210 CO 3/19/24 1:54 3/19/24 1:58 0.07 1 210 CO 3/19/24 2:00 3/19/24 2:04 0.07 1 210 CO 3/19/24 2:06 3/19/24 2:10 0.07 1 210 CO 3/19/24 2:12 3/19/24 2:17 0.08 1 210 CO 3/19/24 2:19 3/19/24 2:23 0.07 1 210 CO 3/19/24 2:26 3/19/24 2:31 0.08 1 210 CO 3/19/24 2:33 3/19/24 2:38 0.08 1 210 CO 3/19/24 2:40 3/19/24 2:46 0.10 1 210 CO 3/19/24 2:50 3/19/24 2:54 0.07 1 210 CO 3/19/24 3:10 3/19/24 3:14 0.07 1 210 CO 3/19/24 3:15 3/19/24 3:20 0.08 1 210 CO 3/19/24 3:22 3/19/24 3:26 0.07 1 210 CO 3/19/24 3:27 3/19/24 3:31 0.07 1 210 CO 3/19/24 3:32 3/19/24 3:36 0.07 1 210 CO 3/19/24 3:37 3/19/24 3:41 0.07 1 210 CO 3/19/24 3:45 3/19/24 3:52 0.12 1 210 CO 3/19/24 3:53 3/19/24 4:03 0.17 1 210 CO 3/19/24 4:06 3/19/24 4:09 0.05 1 210 CO 3/19/24 4:11 3/19/24 4:16 0.08 1 210 CO 3/19/24 4:26 3/19/24 4:31 0.08 1 210 CO 3/19/24 4:35 3/19/24 4:39 0.07 1 210 CO 3/19/24 4:42 3/19/24 4:47 0.08 1 210 CO 3/19/24 6:15 3/19/24 6:19 0.07 1 210 CO 3/19/24 6:21 3/19/24 6:26 0.08 1 210 CO 3/19/24 6:27 3/19/24 7:09 0.70 1 210 CO 3/19/24 7:10 3/19/24 8:38 1.47 1 210 CO 3/19/24 9:09 3/19/24 9:13 0.07 1 210 CO 3/19/24 10:17 3/19/24 10:21 0.07 1 210 CO 3/19/24 10:38 3/19/24 10:41 0.05 1 210 CO 3/19/24 10:49 3/19/24 10:53 0.07 1 210 CO 3/19/24 10:55 3/19/24 10:59 0.07 1 210 CO 3/19/24 11:01 3/19/24 11:05 0.07 1 210 CO 3/19/24 11:07 3/19/24 11:11 0.07 1 210 CO 3/19/24 11:14 3/19/24 11:18 0.07 1 210 CO 3/19/24 11:20 3/19/24 11:25 0.08 1 210 CO 3/19/24 11:27 3/19/24 11:32 0.08 1 210 CO 3/19/24 11:34 3/19/24 11:39 0.08 1 210 CO 3/19/24 11:41 3/19/24 14:54 3.22 1 210 CO 3/19/24 15:00 3/19/24 15:37 0.62 1 210 CO 3/19/24 16:05 3/19/24 16:14 0.15 1 210 CO 3/19/24 16:34 3/19/24 17:05 0.52 1 210 CO 3/19/24 17:15 3/19/24 17:32 0.28 1 210 CO 3/19/24 17:34 3/19/24 17:52 0.30 1 210 CO 3/19/24 18:11 3/19/24 19:05 0.90 1 210 CO 3/19/24 19:13 3/19/24 19:19 0.10 1 210 SO2 3/11/24 6:18 3/11/24 6:29 0.18 1 210 SO2 1/16/24 23:08 1/16/24 23:12 0.07 1 210 SO2 2/17/24 21:00 2/17/24 21:05 0.08 1 210 0 1/0/00 0:00 1/0/00 0:00 1 1 Yes 1 18.82 TC 220 Hours 1298.90 TC 220 Hours 0.00 TC 230 Hours 0.00 Events 0.00 Hours 0.00 Events 0.00 0.00 1 1298.90 TC 300 Hours 0.00 TRUE SRU Tailgas Incinerator 2 SRU Tailgas Incinerator 2 0 FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent SRU Tailgas Incinerator 1 FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent Flare #2 Flare #2 Flare #2 Flare #2 Flare #3 Flare #3 Flare #3 Flare #3 FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent FCC Regenerator Vent Flare #2 Flare #2 Flare #2 Flare #2 Flare #2 Flare #2 Flare #2 Flare #2 Type Code 210 (Pollutant Concentration Exceeded Span of CEM) Type Code 220 (Monitor Outage During Point Source Operation) Type Code 230 (Manual Sample - Alternate Sampling During Monitor Outage) Type Code 240 (CEM Modifications) Type Code 530 (Excess Emissions During Emergency Conditions) Type Code 550 (Changes in Operation in Control Equipment When CEM Data Not Available) Type Code 500 (Boiler Operating Days w/o 18 Hours of Data) Type Code 450 (Data Excluded) Yes None Reported None Reported None Reported None Reported None Reported None Reported Chevron Refinery EER 1Q2024 Relative Accuracy Overview Point Source Channel Date of Most Current RATA Date of Preceding RATA Months Between RATA's Units Measured CEM Value Reference Method Value Relative Accuracy Pass/ Fail Boiler #7 NOx 08/16/23 08/16/22 12 ppm 0.074 0.08 2.25% P Boiler #7 O2 08/16/23 08/16/22 12 4.826 4.83 0.33% P FCC Regenerator Vent SO2 08/14/23 09/23/22 12 ppm 16.9 15.67 9.07% P FCC Regenerator Vent NOx 08/14/23 09/22/22 12 ppm 41.532 42.39 3.51% P FCC Regenerator Vent CO 08/14/23 09/22/22 12 ppm 26.918 26.43 2.06% P FCC Regenerator Vent CO2 08/14/23 09/22/22 12 ppm 17.28 16.98 1.93% P FCC Regenerator Vent O2 08/14/23 09/22/22 12 2.12 2.12 1.31% P Flare #1 H2S 09/21/20 09/21/20 12 ppm 8.9 5.81 3.30% P Flare #2 H2S 09/22/20 09/22/20 12 ppm 8.29 5.39 2.93% P Flare #3 H2S 08/24/23 08/16/22 12 ppm 0 2.26 1.60% P Fuel Gas Mix Point H2S 08/25/23 08/16/22 12 ppm 0.04 1.95 1.25% P SRU Tailgas Incinerator 1 SO2 08/15/23 08/16/22 12 ppm 107.369 114.98 7.91% P SRU Tailgas Incinerator 1 SO2 08/15/23 08/16/22 12 lb./hr. 1.743 1.99 3.10% P SRU Tailgas Incinerator 1 O2 08/15/23 08/16/22 12 4.084 4.13 5.00% P SRU Tailgas Incinerator 2 SO2 08/21/23 09/21/22 12 ppm 132.091 135.90 5.82% P SRU Tailgas Incinerator 2 SO2 08/21/23 09/21/22 12 lb./hr. 3.251 3.41 10.41% P SRU Tailgas Incinerator 2 O2 08/21/23 09/21/22 12 7.17 7.84 3.00% P * NSPS CGA First 2024 Audit Gas Ranges Audit Gas Ranges AP1 Low AP2 Low AP1 High AP2 High Boiler #7 NOx 2/12/24 500 135.4 100 to 150 Boiler #7 NOx 2/12/24 500 276.1 250 to 300 Boiler #7 O2 2/12/24 21 5 4 to 6 Boiler #7 O2 2/12/24 21 8 8 to 12 FCC Regenerator Vent CO 2/12/24 1000 249.9 200 to 300 FCC Regenerator Vent CO 2/12/24 1000 552.2 500 to 600 FCC Regenerator Vent CO2 2/12/24 25 6.5 5 to 8 FCC Regenerator Vent CO2 2/12/24 25 14 10 to 14 FCC Regenerator Vent NOx 2/12/24 200 55.5 40 to 60 FCC Regenerator Vent NOx 2/12/24 200 111.1 100 to 120 FCC Regenerator Vent O2 2/12/24 10 5 4 to 6 FCC Regenerator Vent O2 2/12/24 10 8.1 8 to 12 FCC Regenerator Vent SO2 2/12/24 200 55.08 40 to 60 FCC Regenerator Vent SO2 2/12/24 200 110.3 100 to 120 Flare #1 H2S 2/26/24 300 68.99 60 to 90 Flare #1 H2S 2/26/24 300 156.9 150 to 180 Flare #1 TRS 2/26/24 250000 12526 50000 to 75000 Flare #1 TRS 2/26/24 250000 27571 125000 to 150000 Flare #2 H2S 2/15/24 300 69.7 60 to 90 Flare #2 H2S 2/15/24 300 158.8 150 to 180 Flare #2 TRS 2/15/24 250000 12657 50000 to 75000 Flare #2 TRS 2/15/24 250000 27525 125000 to 150000 Flare #3 H2S 1/31/24 300 70.46 60 to 90 Flare #3 H2S 1/31/24 300 157.1 150 to 180 Flare #3 TRS 1/31/24 250000 2491 50000 to 75000 Flare #3 TRS 1/31/24 250000 5553 125000 to 150000 Fuel Gas Mix Point H2S 2/12/24 300 70.36 60 to 90 Fuel Gas Mix Point H2S 2/12/24 300 161.6 150 to 180 SRU Tailgas Incinerator 1 O2 1/30/24 21 5.09 4 to 6 SRU Tailgas Incinerator 1 O2 1/30/24 21 8.05 8 to 12 SRU Tailgas Incinerator 1 SO2 1/30/24 500 125.7 100 to 150 SRU Tailgas Incinerator 1 SO2 1/30/24 500 251.6 250 to 300 SRU Tailgas Incinerator 2 O2 1/30/24 21 5.04 4 to 6 SRU Tailgas Incinerator 2 O2 1/30/24 21 7.97 8 to 12 SRU Tailgas Incinerator 2 SO2 1/30/24 500 123.2 100 to 150 SRU Tailgas Incinerator 2 SO2 1/30/24 500 249.5 250 to 300 * Type Code 280 (COMS Attenuator Filters) Procedure 3 Point Source Location Attenuator I.D. Attenuator Certification Date Certified Attenuator Opacity OPLR, SECR, or PLCF, Corrected Opacity Value Range Low, Mid, & High Certification 1-year or 5-year FCC Regenerator Vent Flue Gas Duct DHT200 /14108330 2/21/23 13 0.8996 22 Low 1 Year FCC Regenerator Vent Flue Gas Duct DHT200 /14108330 2/21/23 25 0.8996 39.83 Mid 1 Year FCC Regenerator Vent Flue Gas Duct DHT200 /14108330 2/21/23 37 0.8996 56.33 High 1 Year * Opacity Monitor Response (Average of 5) Low Range Mid Range High Range FCC Regenerator Vent Flue Gas Duct 2/6/24 7 0.040 0.001 0.002 0.224 FCC Regenerator Vent Flue Gas Duct 2/6/24 7 0.600 0.002 0.001 0.736 FCC Regenerator Vent Flue Gas Duct 2/6/24 7 -0.010 0.002 0.002 0.236 Confidence Coefficient Calibration Error (≤ 3%) Type Code 281 (Procedure 3 - COMS Filter Audit Calibration Error) Point Source Channel Audit Date Low Span Audit Gas Used High Span Audit Gas Used Point Source Location Audit Date Mean Difference Standard Deviation Chevron Refinery EER 1Q2024 Monitoring Information TC 210, 230, & 240 Type Code 210 (Pollutant Concentration Exceeded Span of CEM) - 500 (All) * Sum of Hours Column Labels Row Labels H2S SO2 CO Grand Total Flare #1 2.02 2.02 Flare #2 2.67 2.67 Flare #3 2.02 2.02 FCC Regenerator Vent 0.27 11.52 11.78 SRU Tailgas Incinerator 1 0.18 0.18 SRU Tailgas Incinerator 2 0.15 0.15 Grand Total 6.70 0.60 11.52 18.82 * Type Code 230 (Manual Sample - Alternate Sampling During Monitor Outage) - 500 (All) * Sum of Hours Column Labels Row Labels (blank) Grand Total (blank)0 0 Grand Total 0 0 * Type Code 240 (CEM Modifications) - 100 (All) * Count of Channel Column Labels Row Labels (blank) Grand Total (blank) (blank) Grand Total Chevron Refinery EER 1Q2024 Type Code 220 (Monitor Outage During Point Source Operation) - 600 (All) * Sum of Hours Column Labels Row Labels 724 721 723 722 Grand Total FCC Regenerator Vent Opacity Performed quarterly audit.1.60 1.60 Had recent high process opacity which led to calibration drift. Performed a mechanical recentering and function check. 0.80 0.80 CO Performed quarterly audit.3.25 3.25 Daily Validations 45.50 45.50 Replaced old sources on nox analyzer, replaced ammomia scrubber media and cleaned sample sytem.1.00 1.00 Replaced ammonia scrubber media and rebuilt sample pump. 0.25 0.25 CO2 Performed quarterly audit.3.25 3.25 Daily Validations 45.50 45.50 Replaced old sources on nox analyzer, replaced ammomia scrubber media and cleaned sample sytem.1.00 1.00 Replaced ammonia scrubber media and rebuilt sample pump. 0.25 0.25 NOx Performed quarterly audit.3.25 3.25 Daily Validations 45.50 45.50 Replaced old sources on nox analyzer, replaced ammomia scrubber media and cleaned sample sytem.1.00 1.00 Replaced ammonia scrubber media and rebuilt sample pump. 0.25 0.25 SO2 Performed quarterly audit.3.25 3.25 Daily Validations 45.50 45.50 Replaced old sources on nox analyzer, replaced ammomia scrubber media and cleaned sample sytem.1.00 1.00 Replaced ammonia scrubber media and rebuilt sample pump. 0.25 0.25 O2 Performed quarterly audit.3.25 3.25 Daily Validations 45.50 45.50 Replaced old sources on nox analyzer, replaced ammomia scrubber media and cleaned sample sytem.1.00 1.00 Replaced ammonia scrubber media and rebuilt sample pump. 0.25 0.25 Flare #1 H2S Performed quarterly audit.0.75 0.75 Daily Validations 22.25 22.25 Performed PM on sample system. Pressure checked for leaks and verified temperature setpoints were being met. 2.75 2.75 Calibration drift due to leaking emergency relief valve. Replaced regulator and revalidated. 35.00 35.00 Calibration drift due to valve air running out which disabled sampling ability. Replaced valve air bottle, revalidated and placed system back in service. 43.00 43.00 TRS Performed quarterly audit.1.75 1.75 Performed PM on sample system. Pressure checked for leaks and verified temperature setpoints were being met. 2.50 2.50 Calibration drift due to valve air running out which disabled sampling ability. Replaced valve air bottle, revalidated and placed system back in service. 43.00 43.00 Flare #2 H2S Performed quarterly audit.5.00 5.00 Daily Validations 33.75 33.75 Calibration drift due to loss of air to analyzer building. Got air system issue resolved and revalidated analyzer. 30.50 30.50 Calibration drift due to dirty filters. Replaced the filters and calibrated and revalidated. 34.25 34.25 Checked analyzer after slight cal drift. Verified sample system. Found loose fitting in sample drier. Calibrated and revalidated. 4.00 4.00 Chevron Refinery EER 1Q2024 Sum of Hours Column Labels Row Labels 724 721 723 722 Grand Total TRS Performed quarterly audit.0.50 0.50 Calibration drift due to loss of air to analyzer building. Got air system issue resolved and revalidated analyzer. 30.50 30.50 Calibration drift due to dirty filters. Replaced the filters and calibrated and revalidated. 34.25 34.25 During routine rounds, discovered detector was not reading correctly. Reset the Motherboard and tested. No further issues. 7.00 7.00 Calibration drift. Injection valve failed. Replaced the inject valve and revalidated analyzer. 23.75 23.75 Flare #3 H2S Performed quarterly audit.4.75 4.75 Daily Validations 20.25 20.25 Calibration Drift.Checked sample system, no issues. Recalibrated and Revalidated.0.25 0.25 Calibration Drift. Across the span of time Analyzer team trouble shot both the analyzer and sample system. They replaced multiple samples system filters, H2S detectors and rebuilt vacuum pumps for the sample system. Analyzer team was able to get the analyzer to pass validatation at certain points daily through this period. However, a build up of process in the sample system would cause the analyzer to fail validation the following day. We have not had this issue in the past. We believe this was due to a contaminated sample line. We have our lab analyzing a sample. It was resolved on March 14th. 216.00 216.00 Contaminated sample line was previously removed from service. Attempted to decontaminate and test to analyzer. Test showed contamination still present. Placed good sample line back in service. This testing required the H2S and Total sulfur analyzers to be placed offline. 2.75 2.75 TRS Performed quarterly audit.4.50 4.50 Contaminated sample line was previously removed from service. Attempted to decontaminate and test to analyzer. Test showed contamination still present. Placed good sample line back in service. This testing required the H2S and Total sulfur analyzers to be placed offline. 2.75 2.75 Total Sulfur analyzer placed offline during trouble shooting H2S analyzer. 55.00 55.00 Calibration drift. High H2S calibration bottle ran out of calibration gas. Replaced calibration bottle and revalidated analyzer. 33.50 33.50 Fuel Gas Mix Point H2S Performed quarterly audit.0.50 0.50 Daily Validations 34.25 34.25 SRU Tailgas Incinerator 1 SO2 Performed quarterly audit.0.50 0.50 Analyzer had low flow fault. Rebuilt sample pump, and established better flow. Performed calibration and reran validation. 0.75 0.75 CEMS SO2 Analyzer had to be taken off-line for trouble shooting and revalidating CEMS O2. 0.25 0.25 Main breaker to analyzer shack tripped due to an HVAC issue. Isolated the HVAC unit and restored power to building. This broke the analyzer signal until power was restored. CEMS Unit validated the next morning. 3.25 3.25 Building temperature had gone too low. The sample drier was unable to dry the sample. Excess moisture caused the analyzer to drift on validation. Stabilized temperature. Dried out the sample system then revalidated and brought back to service. 48.00 48.00 O2 Performed quarterly audit.0.50 0.50 Analyzer had low flow fault. Rebuilt sample pump, and established better flow. Performed calibration and reran validation. 0.75 0.75 Main breaker to analyzer shack tripped due to an HVAC issue. Isolated the HVAC unit and restored power to building. This broke the analyzer signal until power was restored. CEMS Unit validated the next morning. 3.25 3.25 Chevron Refinery EER 1Q2024 Sum of Hours Column Labels Row Labels 724 721 723 722 Grand Total Building temperature had gone too low. The sample drier was unable to dry the sample. Excess moisture caused the analyzer to drift on validation. Stabilized temperature. Dried out the sample system then revalidated and brought back to service. 96.00 96.00 Had several days of O2 4X out calibration drifts before technicians performed a calibration to bring them back in. No issues have come since then. Operations has gone through and reminded Unit Operators of what to do in case of a 4X out drift alarm, which is call out analyzer team. Technicians Performed manual calibration, adjusted the O2 and revalidated. 74.00 74.00 SRU Tailgas Incinerator 2 SO2 Performed quarterly audit.1.00 1.00 CEMS SO2 Analyzer had to be taken off-line for trouble shooting and revalidating CEMS O2. 2.00 2.00 Performed quarterly stack and system PM. Manually calibrated O2 and SO2 CEMS analyzer. 0.50 0.50 Performed stack test and confirmed probe had no plugging. Performed calibration of SO2 and O2. Reran validation. 1.00 1.00 O2 Performed quarterly audit.1.00 1.00 Performed quarterly stack and system PM. Manually calibrated O2 and SO2 CEMS analyzer. 0.50 0.50 Performed stack test and confirmed probe had no plugging. Performed calibration of SO2 and O2. Reran validation. 1.00 1.00 O2 calibration drift due to Sulfur build up on sample probe. Cleaned filter and better flow was achieved. Calibrated and revalidated. 25.00 25.00 Boiler #7 NOx Performed quarterly audit.13.25 13.25 CEMS NOx analyzer had to be taken off-line for trouble shooting and revalidating CEMS O2. 0.50 0.50 Sample bundle heat trace tripped and shut off the sample pump. Found loose connection in heat trace controller and repaired. 0.50 0.50 Sources were worn out and alarm on analyzer was present. Replaced sources, calibrated and revalidated analyzer. O2 was offline during work on Nox. 0.50 0.50 O2 Performed quarterly audit.13.25 13.25 Sample bundle heat trace tripped and shut off the sample pump. Found loose connection in heat trace controller and repaired. 0.50 0.50 Sources were worn out and alarm on analyzer was present. Replaced sources, calibrated and revalidated analyzer. O2 was offline during work on Nox. 0.50 0.50 Calibration drift O2. Calibrated and revalidated . No further issues. 29.25 29.25 Grand Total 140.85 654.30 352.25 151.50 1298.90 Chevron Refinery EER 1Q2024 Opy * Opy Count of Magnitude of Emissions Column Labels Opy Row Labels 703 Grand Total Opy FCC Regenerator Vent 242 242 Opy The FCC had a planned shutdown to remove a coke ball from a reaction mix lineat the fractionator. The Electrostatic Precipitator was kept de-energized throughout the event as a safety precaution to combat any high levels of CO. This caused high Opacity. The reason we had high CO during and shortly after the FCC coke ball event was due to the use of torch oil in the regenerator for temperature control while we were postured in the safe park scenario. While we have plenty of excess O2 in the regenerator, the torch oil in the regenerator resulted in some afterburn and elevated CO. Operations reestablished catalyst circulation and feed, to come out of this afterburn. They were able to remove the torch oil which brought unit CO levels to below ecxeedance levels. Once feed was reintroduced and the unit was stable, operations safely brought the Electrostatic Precipitator back on line which stabilized the Opacity to below exceedance levels. The refinery does not have a history of emissions associated with this cause 242 242 Opy Grand Total 242 242 Chevron Refinery EER 1Q2024 H2S/TRS * H2S/TRS Type Code 430 (H2S) - 6000 (All) H2S/TRS * H2S/TRS Count of Magnitude of Emissions Column Labels H2S/TRS Row Labels 702 Grand Total H2S/TRS Flare #1 H2S/TRS K66101 compressor tripped while Operators were working on V104 Knockout levels. Compressor Bypass was not enabled causing compressor safety interlock system to engage on high level shutting down the compressor. During this time the Flare gas water seals were temporarily breached. Operations swept flares 1 and 2 with sweet gas to reduce the H2S gas. Then safely restarted the compressor in the VGO. The refinery does not have a history of emissions associated with this cause. 3 3 H2S/TRS Flare #2 H2S/TRS K66101 compressor tripped while Operators were working on V104 Knockout levels. Compressor Bypass was not enabled causing compressor safety interlock system to engage on high level shutting down the compressor. During this time the Flare gas water seals were temporarily breached. Operations swept flares 1 and 2 with sweet gas to reduce the H2S gas. Then safely restarted the compressor in the VGO. The refinery does not have a history of emissions associated with this cause. 2 2 H2S/TRS HDN RV started lifting shortly after introducing feed to unit. This caused a surge of gas to fuel vapor recovery briefly breaching both seals. High flow did not stop which caused the HDN Operator to find the RV lifted. The decision was made to pull feed and Hot strip the unit to eliminate excess emissions and pull the RV for maintenance. The RV was pulled and rebuilt. Once the RV was reinstalled, the unit was safely started back up. The refinery does not have a history of emissions associated with this cause. 2 2 H2S/TRS Flare #3 H2S/TRS The level indicator in the reformer unit V3 froze. This caused high liquid level in the liquid knockout for the compressor in the reformer unit. Safety interlock systems shut down the compressor which shut down the plant. During start-up excess liquid was being purged out of the reformer unit which caused a temporary water seal breach at the Flare 3. Once excess liquid was fully purged during startup, the H2S at flare 3 dropped below exceedance levels. The refinery does not have a history of emissions associated with this cause. 2 2 H2S/TRS Grand Total 9 9 Chevron Refinery EER 1Q2024 CO * CO Type Code 440 (CO) - 6000 (All) CO * CO Count of Magnitude of Emissions Column Labels CO Row Labels 703 Grand Total CO FCC Regenerator Vent CO The FCC had a planned shutdown to remove a coke ball from a reaction mix lineat the fractionator. The Electrostatic Precipitator was kept de-energized throughout the event as a safety precaution to combat any high levels of CO. This caused high Opacity. The reason we had high CO during and shortly after the FCC coke ball event was due to the use of torch oil in the regenerator for temperature control while we were postured in the safe park scenario. While we have plenty of excess O2 in the regenerator, the torch oil in the regenerator resulted in some afterburn and elevated CO. Operations reestablished catalyst circulation and feed, to come out of this afterburn. They were able to remove the torch oil which brought unit CO levels to below ecxeedance levels. Once feed was reintroduced and the unit was stable, operations safely brought the Electrostatic Precipitator back on line which stabilized the Opacity to below exceedance levels. The refinery does not have a history of emissions associated with this cause 20 20 CO Grand Total 20 20 Chevron Refinery EER 1Q2024 Type Code 500 Before February 28, 2005 (Boiler Operating Days w/o 18 Hours of Data) After February 28, 2005 (90% Operating Hours For each 30 BOD) - 500 (All) * Count of Channel Column Labels Row Labels Grand Total Grand Total * Type Code 510 (F-factor, Equations & Conversion Factors) - 500 (All) Count of F-factor Column Labels Row Labels Grand Total Grand Total * Type Code 520 (Minimum Data Not Obtained <22/30 BODs) - 500 (All) Count of Channel Column Labels Row Labels Grand Total Grand Total * Type Code 530 (Excess Emissions During Emergency Conditions) - 500 (All) Count of Date Column Labels Row Labels Grand Total Grand Total * Type Code 540 (Fuel Pre-treatment Credit SO2) - 500 (All) Count of Date Column Labels Row Labels Grand Total Grand Total * TypeCode 550 (Changes in Operation in Control Equipment When CEM Data Not Available) - 500 (All) Column Labels Row Labels Grand Total Grand Total Ms. Serena Yau Chevron Salt Lake Refinery 685 South Chevron Way North Salt Lake, Utah 84054 Dear Ms. Yau: I am writing in response to your letter to EPA Region 8, dated October 27, 2020, in which you seek an alternative test method for use on Flare1 and Flare 2 at Chevron’s Salt Lake Refinery (Salt Lake) located in Salt Lake City, Davis County, Utah. It is our understanding that this facility is subject to 40 CFR part 60, Subpart Ja, Standards of Performance for Petroleum Refineries for Which Construction, Reconstruction, or Modification Commenced After May 14, 2007 (Subpart Ja). The Office of Air Quality Planning and Standards (OAQPS), as the delegated authority, must make the determination on any major alternatives to test methods and procedures required under 40 CFR parts 59, 60, 61, 63 and 65. Your proposed test method alternatives and our approval decisions are discussed below. According to the information provided, Flare 1 and Flare 2 at Salt Lake are subject to section 60.107a(a)(2) of Subpart Ja, which requires that a hydrogen sulfide (H2S) continuous monitoring system (CEMS) be used to comply with the emission limits found in section 60.103a(h) of Subpart Ja. Section 60.107a(a)(2) of Subpart Ja also requires an H2S CEMS be installed, operated and maintained according to 40 CFR part 60, appendix B, Performance Specification 7 (PS-7), and the use of Method 11, 15, or 15A of Appendix A-5 to 40 CFR part 60 or Method 16 of Appendix A-6 to 40 CFR part 60 for conducting the relative accuracy test. Following section 60.107a(a)(2), you are required to comply with the applicable quality assurance procedures in Appendix F to 40 CFR part 60, specifically Procedure 1 (40 CFR 60, Appendix F), which requires the annual relative accuracy test of each H2S CEMS. Based on the information you provided, Flare 1 and Flare 2 are both equipped with a flare vapor recovery (FVR) system. These FVR systems employ a water seal to prevent flaring, unless there is sufficient pressure on the seal for flare gas to break through. The vapors that do not break through the water seal are compressed and recovered. The FVR system prevents flaring the vast majority of the time. The H2S CEMS are located downstream of these water seals which means that when these water seals are intact, which is typical, there is no flare gas being sampled by the H2S CEMS. This intermittent flaring makes conducting a relative accuracy test on an H2S CEMS on Flare 1 and Flare 2 difficult. As a result of the difficulty associated with conducting a relative 1/12/2021 2 accuracy test on these H2S CEMSs, you seek to use the alternative relative accuracy procedure provided in section 16.2 of 40 CFR part 60, Appendix B, Performance Specification 2 (PS-2) and referenced as an alternative to the relative accuracy test in sections 60.107a(e)(1)(ii) and (2)(ii) of Subpart Ja. The alternative procedure requested allows for the completion of the alternative relative accuracy procedures found in section 16.0 of PS-2 in lieu of the relative accuracy test procedures for an H2S CEMS specified in PS-7. We have reviewed your request and the associated rule language and recognize that it can be difficult to perform relative accuracy tests of the H2S CEMSs installed on these units that do not consistently combust flare gas. Based on the information contained in your request on the intermittent flare gas flows, we approve the use of the alternative testing approach found in section 16.0 of PS-2, which allows cylinder gases to be used as an alternative to the relative accuracy test for H2S CEMSs, with the following caveats for each test: • This alternative test method is only approved for use on the two H2S CEMSs installed on Flare 1 and Flare 2 at Chevron’s Salt Lake Refinery. • The alternative relative accuracy procedures approved herein are an alternative to the relative accuracy test required by PS-7 and Procedure 1. • When conducting the alternative relative accuracy test, you must follow the procedures for performing the alternative relative accuracy test described in section 16.2 of PS-2 and meet the criteria specified in section 16.3 of PS-2. • The gas quality for the cylinder gases used to conduct the alternative relative accuracy tests must meet the Protocol Gas requirements defined in section 16.2.4 of PS-2, to an accuracy of at least 3 percent, or the cylinder gas material must be vendor certified as traceable to a NIST standard at 3 percent accuracy if Protocol Gases are not available at the concentration necessary for the alternative relative accuracy test. • The alternative relative accuracy procedures must be performed periodically as defined in section 60.107a(a)(1)(v) of Subpart Ja. • A copy of this approval letter must be included in the report detailing the results of the alternative relative accuracy procedures. If you have any questions regarding this determination, please contact Kim Garnett at 919-541- 1158 or garnett.kim@epa.go v. Sincerely, Steffan M. Johnson, Leader Measurement Technology Group STEFFAN JOHNSON Digitally signed by STEFFAN JOHNSON Date: 2021.01.12 08:43:07 -05'00' 3 cc: Rachel Agnew, Chevron (rachelagnew@chevron.com) Kim Garnett, EPA/OAQPS/AQAD (garnett.kim@epa.gov) Jeremy Marsigli, Utah DEQ (jmarsigli@utah.gov) Laurie Ostrand, EPA R8 (ostrand.laurie@epa.gov) Brenda Shine, EPA/OAQPS/SPPD (shine.brenda@epa.gov)