Proposed General Plan Approval and/or General Operating Permit No. 5A for Unconventional Natural Gas Well Site Operations or Remote Pigging Stations (BAQ-GPA/GP-5A); Proposed Modifications to General Plan Approval and/or General Operating Permit No. 5 for Natural Gas Compressor Stations, Processing Plants and Transmission Stations (BAQ-GPA/GP-5); Proposed Modifications to the Air Quality Permit Exemptions List (Doc. No. 275-2101-003); Public Comment Opportunity
[48 Pa.B. 1902]
[Saturday, March 31, 2018]
The Department of Environmental Protection (Department) announces the opportunity for public comment on the proposed General Plan Approval and/or General Operating Permit for Unconventional Natural Gas Well Site Operations or Remote Pigging Stations (BAQ-GPA/GP-5A or GP-5A); revisions to the existing General Plan Approval and/or General Operating Permit for Natural Gas Compressor Stations, Processing Plants and Transmission Stations (BAQ-GPA/GP-5 or GP-5); and revisions to the Air Quality Permit Exemptions List (Doc. No. 275-2101-003).
Notice of availability of these documents and opportunity to submit comments for GP-5A, GP-5 and the Exemptions List was published at 47 Pa.B. 733 (February 4, 2017), which initial notice is hereby reissued in accordance with 25 Pa. Code § 127.612(a) (relating to public notice and review period). This notice will be published in the Pennsylvania Bulletin and in six newspapers of general circulation, and sent to nearby states and the United States Environmental Protection Agency in full compliance with 25 Pa. Code § 127.612(a). A second notice was published at 47 Pa.B. 1235 (February 25, 2017) to extend the comment period to June 5, 2017. The Department received more than 10,000 comments on the proposals. Based on these comments, the Department made significant changes to GP-5A, GP-5 and the Exemptions List.
The proposed GP-5A was developed under the authority of section 6.1(f) of the Air Pollution Control Act (35 P.S. § 4006.1(f)) and 25 Pa. Code Chapter 127, Subchapter H (relating to general plan approvals and operating permits), and will be applicable to unconventional natural gas well site operations or remote pigging stations. The revised GP-5 was developed under the same authorities and will remain applicable to natural gas compressor stations and processing plants and add applicability to natural gas transmission stations.
The proposed GP-5A and revisions to GP-5 include requirements for the following:
(1) Natural Gas-Fired Combustion Units—which includes requirements for combustion units rated greater than or equal to 10 MMBtu/h to meet emission limits for oxides of nitrogen (NOx), carbon monoxide (CO) and particulate matter (PM) and for all combustion units to keep records of fuel usage and throughput to facilitate emissions calculations. Combustion units at unconventional natural gas well sites or remote pigging stations are limited to a rating less than 10 MMBtu/h.
(2) Glycol Dehydration Units—which includes a control threshold requirement of 200 tpy of methane, 2.7 tpy volatile organic compound (VOC), 0.5 tpy of a single hazardous air pollutant (HAP) or 1.0 tpy of total HAP and a control efficiency requirement of 98% if any of the stated thresholds are exceeded.
(3) Stationary Natural Gas-Fired Spark Ignition Internal Combustion Engines—which includes a best available technology (BAT) requirement to meet emission limits for NOx, CO, nonmethane nonethane hydrocarbons (NMNEHC) and formaldehyde.
(4) Reciprocating Compressors—which includes the Federal requirements from 40 CFR Part 60, Subpart OOOOa (relating to standards of performance for crude oil and natural gas facilities for which construction, modification, or reconstruction commenced after September 18, 2015). This includes the requirement to replace the rod-end packing every 26,000 hours of operation or every 3 years.
(5) Storage Vessels—which includes a control threshold requirement of 200 tpy of methane, 2.7 tpy VOC, 0.5 tpy of a single HAP or 1.0 tpy of total HAP and a control efficiency requirement of 98% if any of the stated thresholds are exceeded.
(6) Tanker Truck Load-Out Operations—which includes a requirement to use a vapor recovery system and that trucks that perform load-out operations are appropriately certified. The requirement is met by keeping records that detail the load-out operations, including the identification (ID) number of the truck performing the load-out and the volume of liquids loaded and keeping a list of trucks authorized to perform load-out operations with an ID number and the date of the most recent certification test.
(7) Fugitive Emissions Components—which includes requirements to perform monthly audio, visual and olfactory inspections and quarterly leak detection and repair (LDAR) inspections. LDAR inspections can be performed using an optical gas imaging camera, a Method 21 gas analyzer or other approved methods. For LDAR programs at unconventional natural gas well sites and remote pigging stations, there is an option to track the number of leaking components and reduce the inspection frequency to the Federally required semiannual increment if less than 2% of components are found to be leaking in two consecutive inspections. If 2% or more of components are found to be leaking at the reduced frequency, the LDAR returns to the quarterly schedule.
(8) Controllers—which includes a requirement that electric controllers be installed where electricity is available onsite. For sites where electricity is not available onsite, the Federal requirements from 40 CFR Part 60, Subpart OOOOa must be met.
(9) Pumps—which includes a requirement that electric pumps be installed where electricity is available onsite. For sites where electricity is not available onsite, the Federal requirements from 40 CFR Part 60, Subpart OOOOa must be met. There are also recordkeeping requirements for pumps that are not subject to 40 CFR Part 60, Subpart OOOOa.
(10) Control Devices—which includes the Federal requirements from 40 CFR Part 60, Subpart OOOOa. The only modification of these requirements is that if the option to monitor combustion zone temperature is chosen instead of stack testing an enclosed flare or other combustion device, the combustion zone temperature must be 1,600°F to ensure a 98% methane destruction efficiency.
(11) Pigging Operations—which includes the requirements to install a liquids drain in pig receiver chambers, to route emissions from a high-pressure pig launcher or receiver to a low-pressure vessel or line, a control threshold requirement of 200 tpy of methane, 2.7 tpy VOC, 0.5 tpy of a single HAP or 1.0 tpy of total HAP, and a control efficiency requirement of 98% if any of the stated thresholds are exceeded.
The proposed GP-5A also includes the following additional requirements:
(1) Well Drilling and Hydraulic Fracturing Operations—which includes requirements to notify the Department at least 24 hours prior to the beginning of either type of operation and ensuring that engines used during the operation meet the applicable nonroad engine standards. Records of engine usage are required to facilitate emissions calculations.
(2) Well Completion Operations—which includes the Federal requirements from 40 CFR Part 60, Subpart OOOOa. This includes the requirement to perform a reduced emissions completion, also known as Green Completion, to notify the Department at least 24 hours prior to the beginning of flowback and to keep records of the duration of flowback and the disposition of gas during the flowback period.
(3) Wellbore Liquids Unloading Operations—which includes a requirement that an operator remain onsite for the duration of a manual unloading operation.
The proposed GP-5 also includes the following additional requirements:
(1) Stationary Natural Gas-Fired Combustion Turbines—which includes a BAT requirement for turbines rated above 1,000 hp to meet emission limits for NOx, CO, NMNEHC and PM.
(2) Centrifugal Compressors—which includes the Federal requirements from 40 CFR Part 60, Subpart OOOOa, except that the required control efficiency is 98%. There are also recordkeeping requirements for centrifugal compressors that are not subject to 40 CFR Part 60, Subpart OOOOa.
The general permits include emission limits, testing, monitoring, recordkeeping and reporting requirements designed to keep the facility operating within all applicable State and Federal air quality requirements. The general permits also include the fee required to authorize the construction and operation of sources. The term for general permit is 5 years and authorization can be renewed before the expiration date.
The Department proposes to make changes to the Air Quality Permits Exemption List under 25 Pa. Code § 127.14(a)(8) (relating to exemptions), Category Nos. 35 and 38; under 25 Pa. Code § 127.14(a)(9), Category No. 16; and under the Trivial Activities provision, Category No. 40.
These documents are available on the Department's Bureau of Air Quality web site at http://www.dep.pa.gov/Business/Air/BAQ/Permits/Pages/GeneralPermits.aspx and by contacting Frank Zarefoss, P.O. Box 8468, Harrisburg, PA 17105, (717) 787-4325 or email@example.com.
The Department must receive comments no later than May 15, 2018. Commentators are encouraged to submit comments using the Department's eComment system at www.ahs.dep.pa.gov/eComment or by e-mail to firstname.lastname@example.org. Comments submitted by facsimile will not be accepted. Comments, including comments submitted by e-mail, must include the originator's name and address. Written comments may be mailed to the Policy Office, Department of Environmental Protection, Rachel Carson State Office Building, P.O. Box 2063, Harrisburg, PA 17105-2063.
[Pa.B. Doc. No. 18-502. Filed for public inspection March 30, 2018, 9:00 a.m.]
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