83 FR 18034 - Notice of Requests for Approval of Alternative Means of Emission Limitation
ENVIRONMENTAL PROTECTION AGENCY Federal Register Volume 83, Issue 80 (April 25, 2018)
Federal Register Volume 83, Issue 80 (April 25, 2018)
| Page Range | 18034-18042 | |
| FR Document | 2018-08575 |
[Federal Register Volume 83, Number 80 (Wednesday, April 25, 2018)] [Notices] [Pages 18034-18042] From the Federal Register Online [www.thefederalregister.org] [FR Doc No: 2018-08575] ======================================================================= ----------------------------------------------------------------------- ENVIRONMENTAL PROTECTION AGENCY [EPA-HQ-OAR-2014-0738 and EPA-HQ-OAR-2010-0682; FRL-9976-29-OAR] Notice of Requests for Approval of Alternative Means of Emission Limitation AGENCY: Environmental Protection Agency (EPA). ACTION: Notice; request for comments. ----------------------------------------------------------------------- SUMMARY: This action provides public notice and solicits comment on the alternative means of emission limitation (AMEL) requests from ExxonMobil Corporation; Marathon Petroleum Company, LP (for itself and on behalf of its subsidiary, Blanchard Refining, LLC); and Chalmette Refining, LLC, under the Clean Air Act (CAA), to operate flares at several refineries in Texas and Louisiana, as well as the AMEL request from LACC, LLC to operate flares at a chemical plant in Louisiana. DATES: Comments. Comments must be received on or before June 11, 2018. Public Hearing. If a public hearing is requested by April 30, 2018, then we will hold a public hearing on May 10, 2018 at the location described in the ADDRESSES section. The last day to pre-register in advance to speak at the public hearing will be May 8, 2018. ADDRESSES: Comments. Submit your comments, identified by Docket ID No. EPA-HQ-OAR-2014-0738, at http://www.regulations.gov. Follow the online instructions for submitting comments. Once submitted, comments cannot be edited or removed from Regulations.gov, Regulations.gov is our preferred method of receiving comments. However, other submission methods are accepted. To ship or send mail via the United States Postal Service, use the following address: U.S. Environmental Protection Agency, EPA Docket Center, Docket ID No. EPA-HQ-OAR-2014-0738, Mail Code 28221T, 1200 Pennsylvania Avenue NW, Washington, DC 20460. Use the following Docket Center address if you are using express mail, commercial delivery, hand delivery, or courier: EPA Docket Center, EPA WJC West Building, Room 3334, 1301 Constitution Avenue NW, Washington, DC 20004. Delivery verification signatures will be available only during regular business hours. Do not submit electronically any information you consider to be Confidential Business Information (CBI) or other information whose disclosure is restricted by statue. See the SUPPLEMENTARY INFORMATION section of this preamble for instructions on submitting CBI. The EPA may publish any comment received to its public docket. Multimedia submissions (audio, video, etc.) must be accompanied by a written comment. The written comment is considered the official comment and should include discussion of all points you wish to make. The EPA will generally not consider comments or comment contents located outside of the primary submission (i.e., on the Web, cloud, or other file sharing system). For additional submission methods, the full EPA public comment policy, information about CBI or multimedia submissions, and general guidance on making effective comments, please visit http://www2.epa.gov/dockets/commenting-epa-dockets. Public Hearing. If a public hearing is requested, it will be held at EPA Headquarters, EPA WJC East Building, 1201 Constitution Avenue NW, Washington, DC 20004. If a public hearing is requested, then we will provide details about the public hearing on our website at: https://www3.epa.gov/ttn/atw/groundflares/groundflarespg.html. The EPA does not intend to publish another document in the Federal Register announcing any updates on the request for a public hearing. Please contact Ms. Virginia Hunt of the Sector Policies and Programs Division (E143-01), Office of Air Quality Planning and Standards, Environmental Protection Agency, Research Triangle Park, NC 27711; telephone number: (919) 541-0832; email address: [email protected]; to request a public hearing, to register to speak at the public hearing, or to inquire as to whether or not a public hearing will be held. The EPA will make every effort to accommodate all speakers who arrive and register. If a hearing is held at a U.S. government facility, individuals planning to attend should be prepared to show a current, valid state- or federal-approved picture identification to the [[Page 18035]] security staff in order to gain access to the meeting room. An expired form of identification will not be permitted. Please note that the Real ID Act, passed by Congress in 2005, established new requirements for entering federal facilities. If your driver's license is issued by a noncompliant state, you must present an additional form of identification to enter a federal facility. Acceptable alternative forms of identification include: Federal employee badge, passports, enhanced driver's licenses, and military identification cards. Additional information on the Real ID Act is available at https://www.dhs.gov/real-id-frequently-asked-questions. In addition, you will need to obtain a property pass for any personal belongings you bring with you. Upon leaving the building, you will be required to return this property pass to the security desk. No large signs will be allowed in the building, cameras may only be used outside of the building, and demonstrations will not be allowed on federal property for security reasons. FOR FURTHER INFORMATION CONTACT: For questions about this action, contact Ms. Angie Carey, Sector Policies and Programs Division (E143- 01), Office of Air Quality Planning and Standards (OAQPS), U.S. Environmental Protection Agency, Research Triangle Park, North Carolina 27711; telephone number: (919) 541-2187; fax number: (919) 541-0516; and email address: [email protected]. SUPPLEMENTARY INFORMATION: Docket. The EPA has established a docket for this rulemaking under Docket ID No. EPA-HQ-OAR-2014-0738. All documents in the docket are listed in the Regulations.gov index. Although listed in the index, some information is not publicly available, e.g., CBI or other information whose disclosure is restricted by statute. Certain other material, such as copyrighted material, is not placed on the internet and will be publicly available only in hard copy. Publicly available docket materials are available either electronically in Regulations.gov or in hard copy at the EPA Docket Center, Room 3334, EPA WJC West Building, 1301 Constitution Avenue NW, Washington, DC. The Public Reading Room is open from 8:30 a.m. to 4:30 p.m., Monday through Friday, excluding legal holidays. The telephone number for the Public Reading Room is (202) 566-1744, and the telephone number for the EPA Docket Center is (202) 566-1742. Instructions. Direct your comments to Docket ID No. EPA-HQ-OAR- 2014-0738. The EPA's policy is that all comments received will be included in the public docket without change and may be made available online at http://www.regulations.gov, including any personal information provided, unless the comment includes information claimed to be CBI or other information whose disclosure is restricted by statute. Do not submit information that you consider to be CBI or otherwise protected through http://www.regulations.gov or email. This type of information should be submitted by mail as discussed below. The http://www.regulations.gov website site is an ``anonymous access'' system, which means the EPA will not know your identity or contact information unless you provide it in the body of your comment. If you send an email comment directly to the EPA without going through http://www.regulations.gov, your email address will be automatically captured and included as part of the comment that is placed in the public docket and made available on the internet. If you submit an electronic comment, the EPA recommends that you include your name and other contact information in the body of your comment and with any disk or CD-ROM you submit. If the EPA cannot read your comment due to technical difficulties and cannot contact you for clarification, the EPA may not be able to consider your comment. Electronic files should not include special characters or any form of encryption and be free of any defects or viruses. For additional information about the EPA's public docket, visit the EPA Docket Center homepage at http://www.epa.gov/dockets. Submitting CBI. Do not submit information containing CBI to the EPA through http://www.regulations.gov or email. Clearly mark the part or all of the information that you claim to be CBI. For CBI information on a disk or CD-ROM that you mail to the EPA, mark the outside of the disk or CD-ROM as CBI and then identify electronically within the disk or CD-ROM the specific information that is claimed as CBI. In addition to one complete version of the comments that includes information claimed as CBI, you must submit a copy of the comments that does not contain the information claimed as CBI for inclusion in the public docket. If you submit a CD-ROM or disk that does not contain CBI, mark the outside of the disk or CD-ROM clearly that it does not contain CBI. Information not marked as CBI will be included in the public docket and the EPA's electronic public docket without prior notice. Information marked as CBI will not be disclosed except in accordance with procedures set forth in 40 CFR part 2. Send or deliver information identified as CBI only to the following address: OAQPS Document Control Officer (C404- 02), OAQPS, U.S. Environmental Protection Agency, Research Triangle Park, North Carolina 27711, Attention Docket ID No. EPA-HQ-OAR-2014- 0738. Acronyms and Abbreviations. We use multiple acronyms and terms in this notice. While this list may not be exhaustive, to ease the reading of this notice and for reference purposes, the EPA defines the following terms and acronyms here: AMEL alternative means of emission limitation BTU/scf British thermal units per standard cubic foot CAA Clean Air Act CBI Confidential Business Information CFR Code of Federal Regulations EPA Environmental Protection Agency Eqn equation HAP hazardous air pollutants LFL lower flammability limit LFLcz lower flammability limit of combustion zone gas LFLvg lower flammability limit of flare vent gas LRGO linear relief gas oxidizer MPGF multi-point ground flares NESHAP national emission standards for hazardous air pollutants NHV net heating value NHVcz net heating value of combustion zone gas NHVvg net heating value of flare vent gas NSPS new source performance standards OAQPS Office of Air Quality Planning and Standards scf standard cubic feet SKEC steam-assisted kinetic energy combustor VOC volatile organic compounds Organization of This Document. The information in this notice is organized as follows: I. Background A. Regulatory Flare Requirements and AMEL Requests II. Requests for AMEL A. ExxonMobil Corporation Baytown Refinery Flexicoker Flare B. Marathon Petroleum Company Garyville, Louisiana, and Blanchard Refining's Galveston Bay Refinery MPGFs C. Chalmette Refinery Request D. LACC, LLC Request E. Information Supporting Flare AMEL Requests III. AMEL for the Flares IV. Request for Comments I. Background A. Regulatory Flare Requirements and AMEL Requests In this action, the U.S. Environmental Protection Agency (EPA) is soliciting comment on all aspects of these AMEL [[Page 18036]] requests and the corresponding operating conditions that would demonstrate that the requested AMEL would achieve a reduction in emissions of volatile organic compounds (VOC) and hazardous air pollutants (HAP) at least equivalent to the reduction in emissions required by various standards in 40 Code of Federal Regulations (CFR) parts 60, 61, and 63 that apply to emission sources controlled by these flares. These standards incorporate the flare design and operating requirements in the parts 60 and 63 General Provisions (i.e., 40 CFR 60.18(b) and 63.11(b)) into the individual new source performance standards (NSPS) and maximum achievable control technology (MACT) subparts, except for the Petroleum Refinery MACT, 40 CFR part 63, subpart CC, which specifies its flare requirements within the subpart (i.e., 40 CFR 63.670). Four of the requests are for flares located at petroleum refineries, while the request from LACC, LLC is for a flare design at a chemical manufacturing facility. None of the flares located at petroleum refineries can meet the flare tip velocity limits in the Petroleum Refinery MACT, 40 CFR part 63, subpart CC. In addition, flares at these refineries and at LACC's chemical plant that are subject to other part 60 and 63 standards cannot meet the flare tip velocity limits contained in the applicable General Provisions to part 60 and 63. Based on our review of these requests and their supporting information, we conclude that, by following the conditions specified in this notice, the proposed flares will achieve at least equivalent emissions reductions as flares complying with the requirements of 40 CFR 60.18(b), 63.11(b) and/or 63.670(d), whichever is applicable.\1\ --------------------------------------------------------------------------- \1\ Per 40 CFR 63.640(s), flares that are subject to the provisions of 40 CFR 63.670 are required only to comply with 40 CFR 63.670 and not the General Provisions at 40 CFR 60.18 and 63.11. --------------------------------------------------------------------------- Alternative Means of Emission Limitation requests were submitted to the EPA for flares that cannot comply with the applicable flare tip velocity requirements in the Petroleum Refinery MACT, 40 CFR part 63, subpart CC and General Provisions to parts 60 and 63. These maximum flare tip velocity requirements ensure that the flame does not ``lift off'' or separate from the flare tip, which could cause flame instability and/or potentially result in a portion of the flare gas being released without proper combustion. Proper combustion for flares is considered to be 98-percent destruction efficiency or greater for organic HAP and VOC. The flares in these requests are designed to operate with tip exit velocities greater than those allowed in 40 CFR 60.18, 63.11, and 63.670 while achieving >=96.5-percent combustion efficiency and 98-percent destruction efficiency. Requests from ExxonMobil Corporation, Marathon Petroleum Company, LP, Blanchard Refining, LLC, and Chalmette Refining, LLC were submitted to the EPA on November 7, 2017; October 7, 2016; September 20, 2017; and August 10, 2017, respectively. These requests, which seek AMEL for flares to be used at certain refineries subject to the Petroleum Refinery MACT, 40 CFR part 63, subpart CC, followed the AMEL framework specified in 40 CFR part 63, subpart CC at 40 CFR 63.670(r).\2\ On May 7, 2017, LACC, LLC submitted an AMEL request for flares to be used at a chemical plant in Louisiana according to the framework for pressure assisted multi- point ground flares (MPGFs) that was published in the Federal Register on April 21, 2016 (see 81 FR 23486). The flare designs in these requests vary from a single tip design that is gas-assisted to multi- point tip designs which employ large numbers of tips at varying heights from close to ground level (these are termed multi-point ground flares [MPGF]) to an elevated multi-point design. The EPA has reviewed these requests and deemed them to be complete. --------------------------------------------------------------------------- \2\ Although the Marathon, Blanchard, and Chalmette refineries are subject to other national emission standards for hazardous air pollutants (NESHAP) and NSPS (and, therefore, the General Provisions at 40 CFR 60.18 and 63.11) in addition to NESHAP subpart CC, 40 CFR 63.640(s) of subpart CC allows flares that are subject to flare requirements in both subpart CC and General Provisions to elect to comply only with the subpart CC flare requirements at 40 CFR 63.670. --------------------------------------------------------------------------- The ExxonMobil Corporation Baytown Refinery in Baytown, Texas, is seeking an AMEL to operate a gas-assisted flare during periods of startup, shutdown, upsets, and emergency events, as well as during fuel gas imbalance events. Marathon Petroleum Company, LP's Garyville, Louisiana Refinery, and Blanchard Refining, LLC's Galveston Bay Refinery (GBR) in Texas City, Texas, are seeking AMELs to operate their flares only during periods of startup, shutdown, upsets, and emergency events. Chalmette Refining, LLC in Chalmette, Louisiana, is seeking an AMEL to operate its flare during periods of upset and emergency events. LACC, LLC is seeking an AMEL to operate flares at its chemical plant in Lake Charles, Louisiana, during startups, shutdowns, upsets, and emergency events. See Table 1 for a list of regulations, by subparts, that each refinery and chemical plant has identified as applicable to the flares described above. Table 1--Summary of Applicable Rules That May Apply to Streams Controlled by Flares -------------------------------------------------------------------------------------------------------------------------------------------------------- Exxon Mobil Marathon Blanchard Rule citation from Provisions for Applicable rules with vent streams Baytown, Garyville, LA Refining Chalmette No. LACC Title 40 CFR that alternative means of going to control device(s) Texas MPGF GBR MPGF 1 Flare allow for use of a emission limitation Flare 26 flare -------------------------------------------------------------------------------------------------------------------------------------------------------- NSPS Subpart VV...................... .......... x x .............. .......... 60.482-10(d)......... 60.484(a)-(f). NSPS Subpart VVa..................... .......... x x .............. x 60.482-10a(d)........ 60.484a(a)-(f). NSPS Subpart NNN..................... .......... x x x x 60.662(b)............ CAA section 111(h)(3). NSPS Subpart QQQ..................... .......... x x .............. .......... 60.692-5(c).......... 42 U.S.C. 7411(h)(3). NSPS Subpart RRR..................... .......... x x .............. x 60.702(b)............ CAA section 111(h)(3). NSPS Subpart Kb...................... .......... x x .............. x 60.112b(a)(3)(ii).... 60.114b. NESHAP Subpart V..................... .......... x x .............. x 61.242-11(d)......... 40 CFR 63.6(g); 42 U.S.C. 7412(h)(3). NESHAP Subpart J..................... .......... .............. ........... .............. x 61.242-11(d)......... 40 CFR 63.6(g); 42 U.S.C. 7412(h)(3). NESHAP Subpart Y..................... .......... x x .............. .......... 61.271-(c)(2)........ 40 CFR 63.6(g); 40 CFR 61.273; 42 U.S.C. 7412(h)(3). NESHAP Subpart BB.................... .......... x x .............. .......... 61.302(c)............ 40 CFR 63.6(g); 42 U.S.C. 7412(h)(3). NESHAP Subpart FF.................... .......... x x .............. x 61.349(a)(2)......... 61.353(a); also see 61.12(d). NESHAP Subpart F..................... .......... x x .............. x 63.103(a)............ 63.6(g); 42 U.S.C. 7412(h)(3). [[Page 18037]] NESHAP Subpart G..................... .......... x x .............. x 63.113(a)(1)(i), 63.6(g); 42 U.S.C. 63.116(a)(2), 7412(h)(3). 63.116(a)(3), 63.119(e), 63.120(e)(1) through (4), 63.126(b)(2)(i), 63.128(b), 63.139(c)(3), 63.139(d)(3), 63.145(j). NESHAP Subpart H..................... .......... x x .............. x 63.172(d), 63.180(e). 63.177; 42 U.S.C. 7412(h)(3). NESHAP Subpart SS.................... .......... x x .............. x 63.982(b)............ CAA section 112(h)(3). NESHAP Subpart CC.................... x x x x .......... 63.643(a)(1)......... 63.670(r). NESHAP Subpart UU.................... .......... .............. ........... .............. x 63.1034.............. 63.1021(a)-(d). NESHAP Subpart YY.................... .......... .............. ........... .............. x Table 7 to 63.1103(e) 63.1113. cross-references to NESHAP subpart SS above. NESHAP Subpart EEEE.................. .......... x x .............. .......... 63.2378(a), 63.2382, 63.6(g); 42 U.S.C. 63.2398. 7412(h)(3). -------------------------------------------------------------------------------------------------------------------------------------------------------- The provisions in each NSPS and NESHAP cited above, which ensure that flares meet certain specific operating requirements when used to satisfy the requirements of the NSPS or NESHAP were established as work practice standards pursuant to CAA sections 111(h)(1) or 112(h)(1). For standards established according to these provisions, CAA sections 111(h)(3) and 112(h)(3) allow the EPA to permit the use of an AMEL by a source if, after notice and opportunity for comment,\3\ it is established to the Administrator's satisfaction that such an AMEL will achieve emissions reductions at least equivalent to the reductions required under the applicable CAA section 111(h)(1) or 112(h)(1) standards. As noted in Table 1, many of the identified NSPS and NESHAP also include specific regulatory provisions allowing sources to request an AMEL. --------------------------------------------------------------------------- \3\ CAA section 111(h)(3) requires that the EPA provide an opportunity for a hearing. --------------------------------------------------------------------------- ExxonMobil, Marathon, Blanchard, Chalmette, and LACC submitted AMEL requests to operate above the applicable maximum permitted velocity requirements for flares in the General Provisions in 40 CFR parts 60 and 63 and/or in 40 CFR 63.670. ExxonMobil, Marathon, Blanchard, Chalmette, and LACC provided information that the flare designs achieve a reduction in emissions at least equivalent to the reduction in emissions for flares complying with the applicable General Provisions and/or MACT subpart CC requirements. For further information on ExxonMobil's, Marathon's, Blanchard's, Chalmette's, and LACC's AMEL requests, see supporting materials from ExxonMobil, Marathon, Blanchard, Chalmette, and LACC at Docket ID No. EPA-HQ-OAR-2010-0682 and EPA-HQ-OAR-2014-0738. II. Requests for AMEL A. ExxonMobil Corporation Baytown Refinery Flexicoker Flare ExxonMobil submitted an AMEL for Flare 26 at the ExxonMobil Baytown Refinery. Flare 26 is an elevated flare, with an approximate height of 284 feet. Flare 26 will be modified to install a 52-inch gas-assisted flare tip. Gas-assisted means that natural gas is discharged near or at the flare tip exit and is used to improve the combustion efficiency in the combustion zone, but it is not part of the vent gas, and, as such, does not contribute to the vent gas volume that determines the exit tip velocity. Still, this flare cannot meet the exit velocity limitation in 40 CFR 63.670(d). Flare 26 receives low BTU gas (LBG) from episodic and maintenance events from the Flexicoking LBG system during startup, shutdown, and other non-routine operations. Flare 26 will also accept flow from the Flexicoking LBG system during normal operations where there is a fuel gas imbalance. B. Marathon Petroleum Company Garyville, Louisiana, and Blanchard Refining's Galveston Bay Refinery MPGFs Marathon submitted an AMEL for their two MPGFs at their Garyville refinery and also for one MPGF at their subsidiary, Blanchard Refining's GBR. These three MPGFs were included in a single AMEL request because the principle is the same for each MPGF. All three MPGFs are designed to operate with tip exit velocities greater than those allowed in 40 CFR 60.18, 63.11, and 63.670, while achieving >96.5-percent combustion efficiency and 98-percent destruction efficiency. The scope of the AMELs include steam-assisted steam kinetic energy combustors (SKEC burners) at Garyville, pressure-assisted linear relief gas oxidizers (LRGO burners) at Garyville and GBR, and an air- assisted burner (LH burner) at GBR. All three of the MPGFs covered in this AMEL request were manufactured by John Zink Company, LLC (John Zink). Marathon is seeking AMELs to operate these flares during periods of startup, shutdown, upsets, and emergency events. C. Chalmette Refinery Request Chalmette Refining, LLC submitted an AMEL for their No. 1 Flare. The No. 1 Flare was designed by John Zink and constructed in 1982. The flare is an 8-stage candelabra style raised pressure-assisted flare with multiple flare tips comprised of two designs. The flare is elevated 171.92 feet above ground. Stage one is equipped with John Zink LRGO-Spider model burners. All other stages have John Zink model LRGO- FF burners. The gases being flared can range in composition and flow, but the flare only operates during upset and emergency conditions. D. LACC, LLC Request LACC, LLC submitted an AMEL for two MPGF operating in series. This system consists of an enclosed ground flare and a high-pressure ground flare that operates as a cascading system whereby the enclosed ground flare serves as the primary relief control device and the high-pressure ground flare serves as the secondary relief control device should the enclosed ground flare approach burner utilization capacity. The high- pressure header portion of these ground flares are MPGF and utilize two different types of pressure assisted burners; LRGO-HC (both flares) and INDAIR (enclosed ground flare only). Both are designed and produced by John Zink. The high[hyphen]pressure header MPGFs will be used for destruction of vent streams [[Page 18038]] during startups, shutdowns, upsets, and emergency events. E. Information Supporting Flare AMEL Requests As mentioned above, ExxonMobil, Marathon, Blanchard, and Chalmette provided the information specified in the flare AMEL framework at 40 CFR 63.670(r) to support their AMEL requests. LACC provided the information specified in the flare AMEL framework finalized on April 21, 2016 (81 FR 23486), to support its AMEL request. The information specified in both frameworks includes, but is not limited to: (1) Details on the project scope and background; (2) information on regulatory applicability; (3) flare test data on destruction efficiency/combustion efficiency; (4) flare stability testing data; (5) flare cross-light testing data; (6) information on flare reduction considerations; and (7) information on appropriate flare monitoring and operating conditions. (For further information on the supporting materials provided, see Docket ID No. EPA-HQ-OAR-2010-0682 and EPA-HQ- OAR-2014-0738.) Information supplied by these companies indicates that the flares can achieve adequate combustion efficiency if operated under certain conditions. Generally, testing of burners for the vent gas mixture determined to be representative of the flare operation was used to set the appropriate combustion zone net heating value (NHVcz) minimum limit. Exxon Mobil conducted a series of combustion efficiency tests over a range of operating conditions and vent gas velocities to establish limits on a representative gas-assisted burner. Marathon and Blanchard submitted combustion efficiency test data for all three different types of burners to establish their minimum NHVcz. Burners in these flares include steam assisted (SKEC) and non-assisted (LRGO) burners at Garyville and an air-assisted (LH) and non-assisted (LRGO) at the Blanchard GBR. At the Garyville Refinery, the MPGFs are operated in series such that the flare gas is directed to the SKEC burners in stages 1 through 4, and then to the LRGO burners in stages 5 through 11. Therefore, we selected an operating limit of the higher of 600 BTU/ standard cubic feet (scf) NHVcz or the NHVcz value resulting from the equation of the line presented in Table 2 appropriate for the SKEC burner. At the Blanchard GBR, we selected a value of 600 BTU/scf NHVcz based on the successful combustion efficiency test at 600 BTU/scf for the representative waste gas. The LRGO operating limit is limiting because the LRGO burners follow the air-assisted LH burner at the GBR. Chalmette Refining submitted required information and requested a minimum NHVcz of 1000 BTU/scf or a maximum lower flammability limit (LFL) of less than or equal to 6.5 percent, based on the conditions that were demonstrated to cross light flare stage 8A from adjacent stages 5 and 7 and stage 8B from stages 6 and 7. Stages 8A and B are not equipped with pilots, and, therefore, lighting of these stages relies on lighting from adjacent stages. Chalmette also requested that video records be used to show that cross lighting is successful, even if the NHVcz or LFL conditions are not met. However, we do not intend to allow an alternate compliance method based on visual indication and have not included this in the proposed alternatives. Finally, LACC requested two separate limits to account for the two sets of burners on their MPGF, LRGO, and INDAIR burners operating on waste gas from ethylene and downstream chemical manufacturing (ethylene oxide and monoethylene glycol) processes. LACC cited previous combustion efficiency information for the LRGO burners and successful cross light and stability at 800 BTU/scf for the representative waste gas composition. The combustion efficiencies for the INDAIR burners testing showed that a minimum of 1,067 BTU/scf for NHVcz was necessary to achieve the desired combustion efficiency. For process control, LACC requested a minimum limit of 1,075 BTU/scf for these burners. It is also important to note that LACC has the ability to lock out the stages containing the four INDAIR burners so that they can meet the 800 BTU/ scf minimum for the LRGO burners only. III. AMEL for the Flares Based upon our review of the AMEL requests, we have concluded that, by complying with the proposed AMEL specified in Table 2 and accompanying paragraphs, the flares will achieve emission reductions at least equivalent to reduction in emissions being controlled by flares complying with the flare requirements under the applicable NESHAP and NSPS identified in Table 1. We are seeking the public's input on the requests that the EPA approve AMELs for these flares. Specifically, the EPA seeks the public's input on the conditions specified in this document in the following paragraphs. The EPA's proposed AMEL for Chalmette Refining does not include the requested provision to allow a source not to meet the limits in Table 2 as long as evidence of cross light and combustion exists. Table 2--Proposed Alternative Operating Conditions ---------------------------------------------------------------------------------------------------------------- Proposed alternative AMEL submitted Company Affected facilities Flare type(s) operating conditions. ---------------------------------------------------------------------------------------------------------------- 11/7/17.................... ExxonMobil.......... Baytown, TX Elevated gas-assist >=270 BTU/scf NHV Flexicoker Flare flare. and velocity <361 26. feet per second (ft/sec). 10/7/17.................... Marathon............ Garyville, LA...... 2 MPGFs............ When both SKEC and LRGO burners are being used, the higher of >=600 BTU/scf NHVcz or >=127.27 ln(v)- 110.87 NHVcz. When only the SKEC burner is being used >=127.27 ln(v)-110.87 NHVcz. 10/7/17.................... Marathon/ Blanchard GBR (Texas City, MPGF............... >=600 BTU/scf NHV. Refining. TX). 9/19/17.................... Chalmette Refining.. Chalmette, LA...... Elevated multi- >=1000 BTU/scf NHV point flare. or LFL<=6.5 vol%. 5/1/17..................... LACC................ Lake Charles, LA... 2 MPGFs............ >=1075 BTU/scf NHV for INDAIR Burners; >=800 BTU/ scf NHV for LRGO only. ---------------------------------------------------------------------------------------------------------------- (1) All flares must be operated such that the combustion zone gas net heating value (NHVcz) or the lower flammability in the combustion zone (LFLcz) as specified in Table 2 is met. Owners or operators must demonstrate compliance with the applicable NHVcz or LFLcz specified in Table 2 on a 15-minute block average. Owners or [[Page 18039]] operators must calculate and monitor for the NHVcz or LFLcz according to the following: (a) Calculation of NHVcz (i) If an owner or operator elects to use a monitoring system capable of continuously measuring (i.e., at least once every 15 minutes), calculating, and recording the individual component concentrations present in the flare vent gas, NHVvg shall be calculated using the following equation: [GRAPHIC] [TIFF OMITTED] TN25AP18.000 Where: NHVvg = Net heating value of flare vent gas, BTU/scf. Flare vent gas means all gas found just prior to the tip. This gas includes all flare waste gas (i.e., gas from facility operations that is directed to a flare for the purpose of disposing the gas), flare sweep gas, flare purge gas, and flare supplemental gas, but does not include pilot gas. i = Individual component in flare vent gas. n = Number of components in flare vent gas. xi = Concentration of component i in flare vent gas, volume fraction. NHVi = Net heating value of component i determined as the heat of combustion where the net enthalpy per mole of offgas is based on combustion at 25 degrees Celsius ([deg]C) and 1 atmosphere (or constant pressure) with water in the gaseous state from values published in the literature, and then the values converted to a volumetric basis using 20 [deg]C for ``standard temperature.'' Table 3 summarizes component properties including net heating values. (ii) If the owner or operator uses a continuous net heating value monitor, the owner or operator may, at their discretion, install, operate, calibrate, and maintain a monitoring system capable of continuously measuring, calculating, and recording the hydrogen concentration in the flare vent gas. The owner or operator shall use the following equation to determine NHVvg for each sample measured via the net heating value monitoring system. [GRAPHIC] [TIFF OMITTED] TN25AP18.001 Where: NHVvg = Net heating value of flare vent gas, BTU/scf. NHVmeasured = Net heating value of flare vent gas stream as measured by the continuous net heating value monitoring system, BTU/scf. xH2 = Concentration of hydrogen in flare vent gas at the time the sample was input into the net heating value monitoring system, volume fraction. 938 = Net correction for the measured heating value of hydrogen (1,212-274), BTU/scf. (iii) For non-assisted flare burners, NHVvg = NHVcz. For assisted burners, such as the Marathon Garyville MPGF SKEC burners, the Blanchard Refining MPGF LH burner, and the ExxonMobil gas-assisted burner, NHVcz should be calculated using Equation 3. [GRAPHIC] [TIFF OMITTED] TN25AP18.002 Where: NHVcz = Net heating value of combustion zone gas, BTU/scf. NHVvg = Net heating value of flare vent gas for the 15-minute block period as determined according to (1)(a)(i), BTU/scf. Qvg = Cumulative volumetric flow of flare vent gas during the 15- minute block period, scf. Qag = Cumulative volumetric flow of assist gas during the 15-minute block period, standard cubic feet flow rate, scf. NHVag = Net heating value of assist gas, BTU/scf; this is zero for air or for steam. (b) Calculation of LFLcz (i) The owner or operator shall determine LFLcz from compositional analysis data by using the following equation: [GRAPHIC] [TIFF OMITTED] TN25AP18.003 Where: LFLvg = Lower flammability limit of flare vent gas, volume percent (vol %). n = Number of components in the vent gas. i = Individual component in the vent gas. [chi]i = Concentration of component i in the vent gas, vol %. LFLi = Lower flammability limit of component i as determined using values published by the U.S. Bureau of Mines (Zabetakis, 1965), vol %. All inerts, including nitrogen, are assumed to have an infinite LFL (e.g., LFLN2 = [infin], so that [chi]N2LFLN2 = 0). LFL values for common flare vent gas components are provided in Table 3. (ii) For non-assisted flare burners, LFLvg = LFLcz. (c) Calculation of Vtip For the ExxonMobil flexicoker flare (F-26), the owner or operator shall calculate the 15-minute block average Vtip by using the following equation: [GRAPHIC] [TIFF OMITTED] TN25AP18.004 [[Page 18040]] Where: Vtip = Flare tip velocity, ft/sec. Qvg = Cumulative volumetric flow of vent gas over 15-minute block average period, scf. Area = Unobstructed area of the flare tip, square ft. 900 = Conversion factor, seconds per 15-minute block average. (d) For all flare systems specified in this document, the operator shall install, operate, calibrate, and maintain a monitoring system capable of continuously measuring the volumetric flow rate of flare vent gas (Qvg), the volumetric flow rate of total assist steam (Qs), the volumetric flow rate of total assist air (Qa), and the volumetric flow rate of total assist gas (Qag). (i) The flow rate monitoring systems must be able to correct for the temperature and pressure of the system and output parameters in standard conditions (i.e., a temperature of 20 [deg]C (68 [deg]Fahrenheit) and a pressure of 1 atmosphere). (ii) Mass flow monitors may be used for determining volumetric flow rate of flare vent gas provided the molecular weight of the flare vent gas is determined using compositional analysis so that the mass flow rate can be converted to volumetric flow at standard conditions using the following equation: [GRAPHIC] [TIFF OMITTED] TN25AP18.005 Where: Qvol = Volumetric flow rate, scf/sec. Qmass = Mass flow rate, pounds per sec. 385.3 = Conversion factor, scf per pound-mole. MWt = Molecular weight of the gas at the flow monitoring location, pounds per pound-mole. (e) For each measurement produced by the monitoring system used to comply with (1)(a)(ii), the operator shall determine the 15-minute block average as the arithmetic average of all measurements made by the monitoring system within the 15-minute period. (f) The operator must follow the calibration and maintenance procedures according to Table 4. Maintenance periods, instrument adjustments, or checks to maintain precision and accuracy and zero and span adjustments may not exceed 5 percent of the time the flare is receiving regulated material. Table 3--Individual Component Properties ---------------------------------------------------------------------------------------------------------------- MW (pounds per Component Molecular formula pound-mole) NHV (BTU/scf) LFL (volume %) ---------------------------------------------------------------------------------------------------------------- Acetylene............................. C2H2.................... 26.04 1,404 2.5 Benzene............................... C6H6.................... 78.11 3,591 1.3 1,2-Butadiene......................... C4H6.................... 54.09 2,794 2.0 1,3-Butadiene......................... C4H6.................... 54.09 2,690 2.0 iso-Butane............................ C4H10................... 58.12 2,957 1.8 n-Butane.............................. C4H10................... 58.12 2,968 1.8 cis-Butene............................ C4H8.................... 56.11 2,830 1.6 iso-Butene............................ C4H8.................... 56.11 2,928 1.8 trans-Butene.......................... C4H8.................... 56.11 2,826 1.7 Carbon Dioxide........................ CO2..................... 44.01 0 [infin] Carbon Monoxide....................... CO...................... 28.01 316 12.5 Cyclopropane.......................... C3H6.................... 42.08 2,185 2.4 Ethane................................ C2H6.................... 30.07 1,595 3.0 Ethylene.............................. C2H4.................... 28.05 1,477 2.7 Hydrogen.............................. H2...................... 2.02 * 1,212 4.0 Hydrogen Sulfide...................... H2S..................... 34.08 587 4.0 Methane............................... CH4..................... 16.04 896 5.0 Methyl-Acetylene...................... C3H4.................... 40.06 2,088 1.7 Nitrogen.............................. N2...................... 28.01 0 [infin] Oxygen................................ O2...................... 32.00 0 [infin] Pentane+ (C5+)........................ C5H12................... 72.15 3,655 1.4 Propadiene............................ C3H4.................... 40.06 2,066 2.16 Propane............................... C3H8.................... 44.10 2,281 2.1 Propylene............................. C3H6.................... 42.08 2,150 2.4 Water................................. H2O..................... 18.02 0 [infin] ---------------------------------------------------------------------------------------------------------------- * The theoretical net heating value for hydrogen is 274 BTU/scf, but for the purposes of the flare requirement in this subpart, a net heating value of 1,212 BTU/scf shall be used. [[Page 18041]] Table 4--Accuracy and Calibration Requirements ------------------------------------------------------------------------ Accuracy Calibration Parameter requirements requirements ------------------------------------------------------------------------ Flare Vent Gas Flow Rate20 Performance percent of flow evaluation rate at biennially (every 2 velocities years) and following ranging from 0.1 any period of more to 1 foot per than 24 hours second throughout which the 5 flow rate exceeded percent of flow the maximum rated rate at flow rate of the velocities sensor, or the data greater than 1 recorder was off foot per second. scale. Checks of all mechanical connections for leakage monthly. Visual inspections and checks of system operation every 3 months, unless the system has a redundant flow sensor. Select a representative measurement location where swirling flow or abnormal velocity distributions due to upstream and downstream disturbances at the point of measurement are minimized. Flow Rate for All Flows Other 5 Conduct a flow sensor Than Flare Vent Gas percent over the calibration check at normal range of least biennially flow measured or (every 2 years); 1.9 liters per conduct a minute (0.5 calibration check gallons per following any period minute), of more than 24 whichever is hours throughout greater, for which the flow rate liquid flow. exceeded the manufacturer's specified maximum rated flow rate or install a new flow sensor. 5 At least quarterly, percent over the inspect all normal range of components for flow measured or leakage, unless the 280 liters per continuous parameter minute (10 cubic monitoring system feet per (CPMS) has a minute), redundant flow whichever is sensor. greater, for gas flow. 5 Record the results of percent over the each calibration normal range check and measured for inspection. mass flow. Locate the flow sensor(s) and other necessary equipment (such as straightening vanes) in a position that provides representative flow; reduce swirling flow or abnormal velocity distributions due to upstream and downstream disturbances. Pressure 5 Review pressure percent over the sensor readings at normal range least once a week measured or 0.12 for straight-line kilopascals (0.5 (unchanging) inches of water pressure and perform column), corrective action to whichever is ensure proper greater. pressure sensor operation if blockage is indicated. Performance evaluation annually and following any period of more than 24 hours throughout which the pressure exceeded the maximum rated pressure of the sensor, or the data recorder was off scale. Checks of all mechanical connections for leakage monthly. Visual inspection of all components for integrity, oxidation, and galvanic corrosion every 3 months, unless the system has a redundant pressure sensor. Select a representative measurement location that minimizes or eliminates pulsating pressure, vibration, and internal and external corrosion. Net Heating Value by 2 Calibration Calorimeter percent of span. requirements should follow manufacturer's recommendations at a minimum. Temperature control (heated and/or cooled as necessary) the sampling system to ensure proper year-round operation. Where feasible, select a sampling location at least 2 equivalent diameters downstream from and 0.5 equivalent diameters upstream from the nearest disturbance. Select the sampling location at least 2 equivalent duct diameters from the nearest control device, point of pollutant generation, air in- leakages, or other point at which a change in the pollutant concentration or emission rate occurs. Net Heating Value by Gas As specified in Follow the procedure Chromatograph Performance in PS 9 of 40 CFR Standard (PS) 9 part 60, appendix B, of 40 CFR part except that a single 60, appendix B. daily mid-level calibration check can be used (rather than triplicate analysis), the multi- point calibration can be conducted quarterly (rather than monthly), and the sampling line temperature must be maintained at a minimum temperature of 60 [deg]C (rather than 120 [deg]C). Hydrogen Analyzer 2 Specify calibration percent over the requirements in your concentration site specific CPMS measured, or 0.1 monitoring plan. volume, percent, Calibration whichever is requirements should greater. follow manufacturer's recommendations at a minimum. Specify the sampling location at least 2 equivalent duct diameters from the nearest control device, point of pollutant generation, air in- leakages, or other point at which a change in the pollutant concentration occurs. ------------------------------------------------------------------------ (2) The flare system shall be operated with a flame present at all times when in use. Additionally, each stage that cross-lights must have at least two pilots with a continuously lit pilot flame, except for Chalmette Refining, which has one pilot for each stage, excluding stages 8A and 8B. Each pilot flame must be continuously monitored by a thermocouple or any other equivalent device used to detect the presence of a flame. The time, date, and duration of any complete loss of pilot flame on any of the burners must be recorded. Each monitoring device must be maintained or replaced at a frequency in accordance with the manufacturer's specifications. (3) Flares at refineries shall comply with the requirements of 40 CFR 63.670(h). For LACC, LLC, the flare system shall be operated with no visible emissions except for periods not to exceed a total of 5 minutes during any 2 consecutive hours. A video camera that is capable of continuously recording (i.e., at least one frame every 15 seconds with time and date stamps) images of the flare flame and a reasonable distance above the flare flame at an angle suitable for visible emissions observations must be used to demonstrate compliance with this requirement. The owner or operator must provide real-time video surveillance camera output to the control room or other continuously [[Page 18042]] manned location where the video camera images may be viewed at any time. (4) For the MPGF and the Chalmette elevated multi-point flare, the operator of a flare system shall install and operate pressure monitor(s) on the main flare header, as well as a valve position indicator monitoring system capable of monitoring and recording the position for each staging valve to ensure that the flare operates within the range of tested conditions or within the range of the manufacturer's specifications. The pressure monitor shall meet the requirements in Table 4. Maintenance periods, instrument adjustments or checks to maintain precision and accuracy, and zero and span adjustments may not exceed 5 percent of the time the flare is receiving regulated material. (5) Recordkeeping Requirements (a) All data must be recorded and maintained for a minimum of 3 years or for as long as required under applicable rule subpart(s), whichever is longer. (6) Reporting Requirements (a) The information specified in section III (6)(b) and (c) below must be reported in the timeline specified by the applicable rule subpart(s) for which the flare will control emissions. (b) Owners or operators shall include the final AMEL operating requirements for each flare in their initial Notification of Compliance status report. (c) The owner or operator shall notify the Administrator of periods of excess emissions in their Periodic Reports. The notification shall include: (i) Records of each 15-minute block for all flares during which there was at least 1 minute when regulated material was routed to the flare and a complete loss of pilot flame on a stage of burners occurred, and for all flares, records of each 15-minute block during which there was at least 1 minute when regulated material was routed to the flare and a complete loss of pilot flame on an individual burner occurred. (ii) Records of visible emissions events (including the time and date stamp) that exceed more than 5 minutes in any 2-hour consecutive period. (iii) Records of each 15-minute block period for which an applicable combustion zone operating limit (i.e., NHVcz or LFLcz) is not met for the flare when regulated material is being combusted in the flare. Indicate the date and time for each period, the NHVcz and/or LFLcz operating parameter for the period, the type of monitoring system used to determine compliance with the operating parameters (e.g., gas chromatograph or calorimeter), and also indicate which high-pressure stages were in use. (iv) Records of when the pressure monitor(s) on the main flare header show the flare burners are operating outside the range of tested conditions or outside the range of the manufacturer's specifications. Indicate the date and time for each period, the pressure measurement, the stage(s) and number of flare burners affected, and the range of tested conditions or manufacturer's specifications. (v) Records of when the staging valve position indicator monitoring system indicates a stage of the flare should not be in operation and is or when a stage of the flare should be in operation and is not. Indicate the date and time for each period, whether the stage was supposed to be open, but was closed, or vice versa, and the stage(s) and number of flare burners affected. IV. Request for Comments We solicit comments on all aspects of ExxonMobil's, Marathon's, Blanchard's, Chalmette's, and LACC's requests for approval of an AMEL for flares to be used to comply with the standards specified in Table 1. We specifically seek comment regarding whether or not the alternative operating requirements listed in section III above will achieve emission reductions at least equivalent to emissions being controlled by flares complying with the applicable flare requirements in 40 CFR 60.18(b), 63.11(b), and/or 63.670. Dated: April 18, 2018. Panagiotis Tsirigotis, Director, Office of Air Quality Planning and Standards. [FR Doc. 2018-08575 Filed 4-24-18; 8:45 am] BILLING CODE 6560-50-P
![18034 Federal Register / Vol. 83, No. 80 / Wednesday, April 25, 2018 / Notices
Description: § 205(d) Rate Filing: 3294 intervention is necessary to become a Avenue NW, Washington, DC 20460.
Otter Tail Power Company NITSA and party to the proceeding. Use the following Docket Center address
NOA Notice of Cancellation to be eFiling is encouraged. More detailed if you are using express mail,
effective 1/1/2018. information relating to filing commercial delivery, hand delivery, or
Filed Date: 4/19/18. requirements, interventions, protests, courier: EPA Docket Center, EPA WJC
Accession Number: 20180419–5124. service, and qualifying facilities filings West Building, Room 3334, 1301
Comments Due: 5 p.m. ET 5/10/18. can be found at: http://www.ferc.gov/ Constitution Avenue NW, Washington,
Docket Numbers: ER18–1398–000. docs-filing/efiling/filing-req.pdf. For DC 20004. Delivery verification
Applicants: Southern California other information, call (866) 208–3676 signatures will be available only during
Edison Company. (toll free). For TTY, call (202) 502–8659. regular business hours.
Description: § 205(d) Rate Filing: Dated: April 19, 2018. Do not submit electronically any
Second Amended IFA re: City of information you consider to be
Nathaniel J. Davis, Sr.,
Riverside Wilderness Substation to be Confidential Business Information (CBI)
Deputy Secretary.
effective 4/20/2018. or other information whose disclosure is
[FR Doc. 2018–08611 Filed 4–24–18; 8:45 am] restricted by statue. See the
Filed Date: 4/19/18. BILLING CODE 6717–01–P SUPPLEMENTARY INFORMATION section of
Accession Number: 20180419–5141.
Comments Due: 5 p.m. ET 5/10/18. this preamble for instructions on
submitting CBI.
Docket Numbers: ER18–1399–000. ENVIRONMENTAL PROTECTION The EPA may publish any comment
Applicants: PJM Interconnection, AGENCY received to its public docket.
L.L.C. Multimedia submissions (audio, video,
Description: § 205(d) Rate Filing: [EPA–HQ–OAR–2014–0738 and EPA–HQ–
OAR–2010–0682; FRL–9976–29–OAR] etc.) must be accompanied by a written
Original Cost Responsibility Agreement, comment. The written comment is
Service Agreement No. 5069, NQ161 to Notice of Requests for Approval of considered the official comment and
be effective 3/28/2018. Alternative Means of Emission should include discussion of all points
Filed Date: 4/19/18. Limitation you wish to make. The EPA will
Accession Number: 20180419–5164. generally not consider comments or
Comments Due: 5 p.m. ET 5/10/18. AGENCY: Environmental Protection comment contents located outside of the
Docket Numbers: ER18–1400–000. Agency (EPA). primary submission (i.e., on the Web,
Applicants: Southern California ACTION: Notice; request for comments. cloud, or other file sharing system). For
Edison Company. additional submission methods, the full
SUMMARY: This action provides public
Description: Tariff Cancellation: EPA public comment policy,
notice and solicits comment on the
Notice of Cancellation GIA & DSA information about CBI or multimedia
alternative means of emission limitation
SCEBESS–003 Project SA Nos. 962–963 submissions, and general guidance on
(AMEL) requests from ExxonMobil
to be effective 7/9/2018. making effective comments, please visit
Corporation; Marathon Petroleum
Filed Date: 4/19/18. http://www2.epa.gov/dockets/
Company, LP (for itself and on behalf of
Accession Number: 20180419–5193. commenting-epa-dockets.
its subsidiary, Blanchard Refining, LLC); Public Hearing. If a public hearing is
Comments Due: 5 p.m. ET 5/10/18. and Chalmette Refining, LLC, under the
Docket Numbers: ER18–1401–000. requested, it will be held at EPA
Clean Air Act (CAA), to operate flares at Headquarters, EPA WJC East Building,
Applicants: Public Service Company several refineries in Texas and
of Colorado. 1201 Constitution Avenue NW,
Louisiana, as well as the AMEL request Washington, DC 20004. If a public
Description: § 205(d) Rate Filing: from LACC, LLC to operate flares at a
PSCo-WAPA-Multi CFA 350-Exb B 0.1.0 hearing is requested, then we will
chemical plant in Louisiana. provide details about the public hearing
to be effective 6/19/2018. DATES: Comments. Comments must be
Filed Date: 4/19/18. on our website at: https://
received on or before June 11, 2018. www3.epa.gov/ttn/atw/groundflares/
Accession Number: 20180419–5203. Public Hearing. If a public hearing is groundflarespg.html. The EPA does not
Comments Due: 5 p.m. ET 5/10/18. requested by April 30, 2018, then we intend to publish another document in
Docket Numbers: ER18–1402–000. will hold a public hearing on May 10, the Federal Register announcing any
Applicants: KCP&L Greater Missouri 2018 at the location described in the updates on the request for a public
Operations Company. ADDRESSES section. The last day to pre- hearing. Please contact Ms. Virginia
Description: § 205(d) Rate Filing: register in advance to speak at the Hunt of the Sector Policies and
Normal filing FERC NO 18 to be public hearing will be May 8, 2018. Programs Division (E143–01), Office of
effective 5/1/2018. ADDRESSES: Comments. Submit your Air Quality Planning and Standards,
Filed Date: 4/19/18. comments, identified by Docket ID No. Environmental Protection Agency,
Accession Number: 20180419–5245. EPA–HQ–OAR–2014–0738, at http:// Research Triangle Park, NC 27711;
Comments Due: 5 p.m. ET 5/10/18. www.regulations.gov. Follow the online telephone number: (919) 541–0832;
The filings are accessible in the instructions for submitting comments. email address: hunt.virginia@epa.gov; to
Commission’s eLibrary system by Once submitted, comments cannot be request a public hearing, to register to
clicking on the links or querying the edited or removed from Regulations.gov, speak at the public hearing, or to inquire
docket number. Regulations.gov is our preferred method as to whether or not a public hearing
Any person desiring to intervene or of receiving comments. However, other
sradovich on DSK3GMQ082PROD with NOTICES
will be held.
protest in any of the above proceedings submission methods are accepted. To The EPA will make every effort to
must file in accordance with Rules 211 ship or send mail via the United States accommodate all speakers who arrive
and 214 of the Commission’s Postal Service, use the following and register. If a hearing is held at a U.S.
Regulations (18 CFR 385.211 and address: U.S. Environmental Protection government facility, individuals
385.214) on or before 5:00 p.m. Eastern Agency, EPA Docket Center, Docket ID planning to attend should be prepared
time on the specified comment date. No. EPA–HQ–OAR–2014–0738, Mail to show a current, valid state- or federal-
Protests may be considered, but Code 28221T, 1200 Pennsylvania approved picture identification to the
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![18036 Federal Register / Vol. 83, No. 80 / Wednesday, April 25, 2018 / Notices
requests and the corresponding reductions as flares complying with the chemical plant in Louisiana according
operating conditions that would requirements of 40 CFR 60.18(b), to the framework for pressure assisted
demonstrate that the requested AMEL 63.11(b) and/or 63.670(d), whichever is multi-point ground flares (MPGFs) that
would achieve a reduction in emissions applicable.1 was published in the Federal Register
of volatile organic compounds (VOC) Alternative Means of Emission on April 21, 2016 (see 81 FR 23486).
and hazardous air pollutants (HAP) at Limitation requests were submitted to The flare designs in these requests vary
least equivalent to the reduction in the EPA for flares that cannot comply from a single tip design that is gas-
emissions required by various standards with the applicable flare tip velocity assisted to multi-point tip designs
in 40 Code of Federal Regulations (CFR) requirements in the Petroleum Refinery which employ large numbers of tips at
parts 60, 61, and 63 that apply to MACT, 40 CFR part 63, subpart CC and varying heights from close to ground
emission sources controlled by these General Provisions to parts 60 and 63. level (these are termed multi-point
flares. These standards incorporate the These maximum flare tip velocity ground flares [MPGF]) to an elevated
flare design and operating requirements requirements ensure that the flame does multi-point design. The EPA has
in the parts 60 and 63 General not ‘‘lift off’’ or separate from the flare reviewed these requests and deemed
Provisions (i.e., 40 CFR 60.18(b) and tip, which could cause flame instability them to be complete.
63.11(b)) into the individual new source and/or potentially result in a portion of
performance standards (NSPS) and the flare gas being released without The ExxonMobil Corporation
maximum achievable control proper combustion. Proper combustion Baytown Refinery in Baytown, Texas, is
technology (MACT) subparts, except for for flares is considered to be 98-percent seeking an AMEL to operate a gas-
the Petroleum Refinery MACT, 40 CFR destruction efficiency or greater for assisted flare during periods of startup,
part 63, subpart CC, which specifies its organic HAP and VOC. The flares in shutdown, upsets, and emergency
flare requirements within the subpart these requests are designed to operate events, as well as during fuel gas
(i.e., 40 CFR 63.670). Four of the with tip exit velocities greater than imbalance events. Marathon Petroleum
requests are for flares located at those allowed in 40 CFR 60.18, 63.11, Company, LP’s Garyville, Louisiana
petroleum refineries, while the request and 63.670 while achieving ≥96.5- Refinery, and Blanchard Refining, LLC’s
from LACC, LLC is for a flare design at percent combustion efficiency and 98- Galveston Bay Refinery (GBR) in Texas
a chemical manufacturing facility. None percent destruction efficiency. Requests City, Texas, are seeking AMELs to
of the flares located at petroleum from ExxonMobil Corporation, operate their flares only during periods
refineries can meet the flare tip velocity Marathon Petroleum Company, LP, of startup, shutdown, upsets, and
limits in the Petroleum Refinery MACT, Blanchard Refining, LLC, and Chalmette emergency events. Chalmette Refining,
40 CFR part 63, subpart CC. In addition, Refining, LLC were submitted to the LLC in Chalmette, Louisiana, is seeking
flares at these refineries and at LACC’s EPA on November 7, 2017; October 7, an AMEL to operate its flare during
chemical plant that are subject to other 2016; September 20, 2017; and August periods of upset and emergency events.
part 60 and 63 standards cannot meet 10, 2017, respectively. These requests, LACC, LLC is seeking an AMEL to
the flare tip velocity limits contained in which seek AMEL for flares to be used operate flares at its chemical plant in
the applicable General Provisions to at certain refineries subject to the Lake Charles, Louisiana, during
part 60 and 63. Based on our review of Petroleum Refinery MACT, 40 CFR part startups, shutdowns, upsets, and
these requests and their supporting 63, subpart CC, followed the AMEL emergency events. See Table 1 for a list
information, we conclude that, by framework specified in 40 CFR part 63, of regulations, by subparts, that each
following the conditions specified in subpart CC at 40 CFR 63.670(r).2 On refinery and chemical plant has
this notice, the proposed flares will May 7, 2017, LACC, LLC submitted an identified as applicable to the flares
achieve at least equivalent emissions AMEL request for flares to be used at a described above.
TABLE 1—SUMMARY OF APPLICABLE RULES THAT MAY APPLY TO STREAMS CONTROLLED BY FLARES
Exxon Blanchard
Applicable rules with vent Mobil Marathon Rule citation from Title 40
Refining Chalmette Provisions for alternative
streams going to control Baytown, Garyville, LA LACC CFR that allow for use of a
GBR No. 1 Flare means of emission limitation
device(s) Texas MPGF flare
MPGF
Flare 26
NSPS Subpart VV ................ ................ x x ...................... ................ 60.482–10(d) ........................... 60.484(a)–(f).
NSPS Subpart VVa .............. ................ x x ...................... x 60.482–10a(d) ......................... 60.484a(a)–(f).
NSPS Subpart NNN ............. ................ x x x x 60.662(b) ................................. CAA section 111(h)(3).
NSPS Subpart QQQ ............ ................ x x ...................... ................ 60.692–5(c) ............................. 42 U.S.C. 7411(h)(3).
NSPS Subpart RRR ............. ................ x x ...................... x 60.702(b) ................................. CAA section 111(h)(3).
NSPS Subpart Kb ................ ................ x x ...................... x 60.112b(a)(3)(ii) ...................... 60.114b.
NESHAP Subpart V ............. ................ x x ...................... x 61.242–11(d) ........................... 40 CFR 63.6(g); 42 U.S.C.
7412(h)(3).
NESHAP Subpart J .............. ................ ...................... .................. ...................... x 61.242–11(d) ........................... 40 CFR 63.6(g); 42 U.S.C.
7412(h)(3).
NESHAP Subpart Y ............. ................ x x ...................... ................ 61.271–(c)(2) ........................... 40 CFR 63.6(g); 40 CFR
61.273; 42 U.S.C.
7412(h)(3).
NESHAP Subpart BB ........... ................ x x ...................... ................ 61.302(c) ................................. 40 CFR 63.6(g); 42 U.S.C.
sradovich on DSK3GMQ082PROD with NOTICES
7412(h)(3).
NESHAP Subpart FF ........... ................ x x ...................... x 61.349(a)(2) ............................ 61.353(a); also see 61.12(d).
NESHAP Subpart F ............. ................ x x ...................... x 63.103(a) ................................. 63.6(g); 42 U.S.C. 7412(h)(3).
1 Per 40 CFR 63.640(s), flares that are subject to 2 Although the Marathon, Blanchard, and to NESHAP subpart CC, 40 CFR 63.640(s) of subpart
the provisions of 40 CFR 63.670 are required only Chalmette refineries are subject to other national CC allows flares that are subject to flare
to comply with 40 CFR 63.670 and not the General emission standards for hazardous air pollutants requirements in both subpart CC and General
Provisions at 40 CFR 60.18 and 63.11. (NESHAP) and NSPS (and, therefore, the General Provisions to elect to comply only with the subpart
Provisions at 40 CFR 60.18 and 63.11) in addition CC flare requirements at 40 CFR 63.670.
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manned location where the video indicate which high-pressure stages technology and work practices
camera images may be viewed at any were in use. developed for removal and replacement
time. (iv) Records of when the pressure of asbestos cement (A/C) pipe. In this
(4) For the MPGF and the Chalmette monitor(s) on the main flare header action, the Environmental Protection
elevated multi-point flare, the operator show the flare burners are operating Agency (EPA) is soliciting comment on
of a flare system shall install and outside the range of tested conditions or all aspects of this request for an AWP
operate pressure monitor(s) on the main outside the range of the manufacturer’s that, in order to be approved, should be
flare header, as well as a valve position specifications. Indicate the date and at least environmentally equivalent to
indicator monitoring system capable of time for each period, the pressure the existing work practices in the
monitoring and recording the position measurement, the stage(s) and number National Emission Standards for
for each staging valve to ensure that the of flare burners affected, and the range Hazardous Air Pollutants for Asbestos
flare operates within the range of tested of tested conditions or manufacturer’s (Asbestos NESHAP), which applies to
conditions or within the range of the specifications. the removal and replacement of A/C
manufacturer’s specifications. The (v) Records of when the staging valve pipe.
pressure monitor shall meet the position indicator monitoring system DATES:
requirements in Table 4. Maintenance indicates a stage of the flare should not Comments. The EPA must receive
periods, instrument adjustments or be in operation and is or when a stage written comments on or before June 25,
checks to maintain precision and of the flare should be in operation and 2018.
accuracy, and zero and span is not. Indicate the date and time for Public Hearing. If a public hearing is
adjustments may not exceed 5 percent each period, whether the stage was requested by April 30, 2018, then we
of the time the flare is receiving supposed to be open, but was closed, or will hold a public hearing on May 10,
regulated material. vice versa, and the stage(s) and number 2018 at the EPA William Jefferson
(5) Recordkeeping Requirements of flare burners affected. Clinton (WJC) East Building, 1201
(a) All data must be recorded and IV. Request for Comments Constitution Avenue NW, Washington,
maintained for a minimum of 3 years or DC 20004. If a public hearing is
for as long as required under applicable We solicit comments on all aspects of requested, then we will provide
rule subpart(s), whichever is longer. ExxonMobil’s, Marathon’s, Blanchard’s, additional details about the public
(6) Reporting Requirements Chalmette’s, and LACC’s requests for hearing on our website at https://
(a) The information specified in approval of an AMEL for flares to be www.epa.gov/stationary-sources-air-
section III (6)(b) and (c) below must be used to comply with the standards pollution/asbestos-national-emission-
reported in the timeline specified by the specified in Table 1. We specifically standards-hazardous-air-pollutants. To
applicable rule subpart(s) for which the seek comment regarding whether or not request a hearing, to register to speak at
flare will control emissions. the alternative operating requirements a hearing, or to inquire if a hearing will
(b) Owners or operators shall include listed in section III above will achieve be held, please contact Aimee St. Clair
the final AMEL operating requirements emission reductions at least equivalent at (919) 541–1063 or by email at
for each flare in their initial Notification to emissions being controlled by flares stclair.aimee@epa.gov. The EPA does
of Compliance status report. complying with the applicable flare not intend to publish any future notices
(c) The owner or operator shall notify requirements in 40 CFR 60.18(b), in the Federal Register regarding a
the Administrator of periods of excess 63.11(b), and/or 63.670. public hearing on this proposed action
emissions in their Periodic Reports. The Dated: April 18, 2018. and directs all inquiries regarding a
notification shall include: Panagiotis Tsirigotis, hearing to the website and contact
(i) Records of each 15-minute block Director, Office of Air Quality Planning and person identified above. The last day to
for all flares during which there was at Standards. pre-register in advance to speak at the
least 1 minute when regulated material [FR Doc. 2018–08575 Filed 4–24–18; 8:45 am] public hearing will be May 8, 2018.
was routed to the flare and a complete BILLING CODE 6560–50–P ADDRESSES: Comments. Submit your
loss of pilot flame on a stage of burners comments, identified by Docket ID No.
occurred, and for all flares, records of EPA–HQ–OAR–2017–0427, at http://
each 15-minute block during which ENVIRONMENTAL PROTECTION www.regulations.gov. Follow the online
there was at least 1 minute when AGENCY instructions for submitting comments.
regulated material was routed to the Once submitted, comments cannot be
[EPA–HQ–OAR–2017–0427; FRL–9975–48–
flare and a complete loss of pilot flame OAR] edited or removed from Regulations.gov.
on an individual burner occurred. Regulations.gov is our preferred method
(ii) Records of visible emissions RIN 2060–AT73 of receiving comments. However, other
events (including the time and date submission formats are accepted. To
stamp) that exceed more than 5 minutes National Emission Standards for ship or send mail via the United States
in any 2-hour consecutive period. Hazardous Air Pollutants for Asbestos: Postal Service, use the following
(iii) Records of each 15-minute block Request for Approval of an Alternative address: U.S. Environmental Protection
period for which an applicable Work Practice for Asbestos Cement Agency, EPA Docket Center, Docket ID
combustion zone operating limit (i.e., Pipe Replacement No. EPA–HQ–OAR–2017–0427, Mail
NHVcz or LFLcz) is not met for the flare AGENCY: Environmental Protection Code 28221T, 1200 Pennsylvania
when regulated material is being Avenue NW, Washington, DC 20460.
sradovich on DSK3GMQ082PROD with NOTICES
Agency (EPA).
combusted in the flare. Indicate the date ACTION: Notification of request for Use the following Docket Center address
and time for each period, the NHVcz comments. if you are using express mail,
and/or LFLcz operating parameter for the commercial delivery, hand delivery, or
period, the type of monitoring system SUMMARY: This action provides public courier. EPA Docket Center, WJC West
used to determine compliance with the notice and solicits comment on an Building, Room 3334, 1301 Constitution
operating parameters (e.g., gas alternative work practice (AWP) request Avenue NW, Washington, DC 20004.
chromatograph or calorimeter), and also under the Clean Air Act, to use new Delivery verification signatures will be
VerDate Sep<11>2014 19:12 Apr 24, 2018 Jkt 244001 PO 00000 Frm 00050 Fmt 4703 Sfmt 4703 E:\FR\FM\25APN1.SGM 25APN1](https://thefederalregister.org/doc/83_FR_18114/page/9.svg)
Document Created: 2018-11-02 08:17:30
Document Modified: 2018-11-02 08:17:30
| Category | Regulatory Information | |
| Collection | Federal Register | |
| sudoc Class | AE 2.7: GS 4.107: AE 2.106: | |
| Publisher | Office of the Federal Register, National Archives and Records Administration | |
| Section | Notices | |
| Action | Notice; request for comments. | |
| Dates | Comments. Comments must be received on or before June 11, 2018. | |
| Contact | For questions about this action, contact Ms. Angie Carey, Sector Policies and Programs Division (E143- 01), Office of Air Quality Planning and Standards (OAQPS), U.S. Environmental Protection Agency, Research Triangle Park, North Carolina 27711; telephone number: (919) 541-2187; fax number: (919) 541-0516; | |
| FR Citation | 83 FR 18034 |
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