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Proposed General Plan Approval and/or General Operating Permit No. 5A for Unconventional Natural Gas Well Site Operations and Remote Pigging Stations; 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 Exemption List (275-2101-003)

[47 Pa.B. 733]
[Saturday, February 4, 2017]

 The Department of Environmental Protection (Department) proposes a new General Plan Approval and/or General Operating Permit for Unconventional Natural Gas Well Site Operations and 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) issued in February 2013, and modified in January 2015; and revisions to the Air Quality Permit Exemptions document (275-2101-003) with this notice. The General Permits establish Best Available Technology (BAT) requirements and other applicable Federal and State requirements including air emission limits, source testing, leak detection and repair, recordkeeping, and reporting requirements for the applicable air contamination sources.

 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 and remote pigging stations. Remote pigging stations are defined as a pigging station not located at an unconventional natural gas well site, natural gas compressor station, natural gas processing plant or natural gas transmission station and that emits more than 200 tons per year (tpy) of methane, 2.7 tpy of volatile organic compounds (VOC), 0.5 tpy of any individual hazardous air pollutant (HAP) or 1.0 tpy of total HAP.

 The revised GP-5 was developed under the authority of section 6.1(f) of the Air Pollution Control Act and 25 Pa. Code Chapter 127, Subchapter H, and will remain applicable to natural gas compressor stations and processing plants and add applicability to natural gas transmission stations.

Proposed GP-5A and GP-5 Requirements

 Both the proposed GP-5A and proposed modifications to GP-5 include requirements for the following:

 (1) Fugitive Particulate Matter—which includes requirements to maintain a written procedures document that describes the methods used to reduce emissions of fugitive particulate matter from the facility and records documenting their implementation.

 (2) 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 and remote pigging stations are limited to a rating less than 10 MMBtu/h.

 (3) Glycol Dehydration Units—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.

 (4) Stationary Natural Gas-Fired Spark Ignition Internal Combustion Engines—which includes a BAT requirement to meet emission limits for NOx, CO, nonmethane, nonethane, hydrocarbons (NMNEHC) and formaldehyde.

 (5) 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.

 (6) 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.

 (7) 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 their most recent certification test.

 (8) 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.

 (9) 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.

 (10) 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.

 (11) 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.

 (12) 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.

Additional Proposed GP-5A Requirements

 The proposed GP-5A also includes requirements for the following:

 (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.

Additional Proposed GP-5 Requirements

 The proposed GP-5 also includes requirements for the following:

 (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.

 A Technical Support Document (TSD) will also be made available for review. The TSD provides background information and the details of the Department's BAT analyses that serve as the bases for the conditions found in both General Permits.

Proposed Revisions to the Air Quality Exemptions Technical Guidance Document

 The proposed revisions to the Air Quality Exemptions document include:

 (1) Dividing Category Number 38 into two separate categories, Category Number 38a and Category Number 38b.

 (2) Category Number 38a will be applicable only to conventional and unconventional natural gas well sites that were constructed or modified between August 10, 2013, and the effective date of the proposed amendment.

 (3) Category Number 38b will be applicable only to conventional natural gas well sites constructed after the effective date of the proposed amendment.

Public Comment

 Interested persons may submit written comments on the Draft General Permits and Air Quality Permit Exemption List by Wednesday, March 22, 2017. Comments submitted by facsimile will not be accepted. Comments, including comments submitted by e-mail, must include the originator's name and address. Commentators are encouraged to review the proposed General Permits and Air Quality Permit Exemption List and submit comments using the Department's online eComment system at www.ahs.dep.pa.gov/eComment or by e-mail to ecomment@pa.gov. Written comments should be submitted to the Policy Office, Department of Environmental Protection, Rachel Carson State Office Building, P.O. Box 2063, Harrisburg, PA 17105-2063.

PATRICK McDONNELL, 
Acting Secretary

[Pa.B. Doc. No. 17-200. Filed for public inspection February 3, 2017, 9:00 a.m.]



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