### MEMORANDUM

TO: Docket # EPA-HQ-OAR-2011-0512

FROM: Alexis McKittrick and Mark DeFigueiredo, EPA/CCD

DATE: February 20, 2014

SUBJECT: Proposed Minor Technical Corrections to Subpart W, Petroleum and Natural Gas Systems, in the Greenhouse Gas Reporting Program

The EPA is proposing to make certain revisions to the petroleum and natural gas systems source category of the Greenhouse Gas Reporting Rule (40 CFR part 98, subpart W). The proposed changes revise calculation methods , amend monitoring and data re porting requirements, clarify certain terms and definitions, and correct techni cal and editorial errors identified during the course of implementation.

The purpose of this memorandum is to provide a deta iled list of minor or clarifying changes that are not discussed in the preamble to the propos ed amendments to subpart W (“Revisions and Confidentiality Determinations for Petroleum and Natural Gas Systems; Proposed Rule”). Table 1 contains a list of the minor proposed changes, the current ru le language for the requirement, and the proposed revi sed rule language. An explana tion for the change is included. These changes are minor clarifications to bett er reflect EPA’s intent and include simple

corrections to calculation terms or cross-refe rences that do not revi se the output of the calculations, harmonizing changes within a subpart (such as changes to terminology), simple

editorial and minor error correc tions, or removal of redundant te xt. Proposed revisions to the reporting section of subpart W are not included in this memorandum, but are discussed in a separate document included in this docket entitled, “Proposed Revisi ons to the Subpart W Reporting Requirements.”

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change §98 .232(c)(11), (d)(1), (e)(1), (f)(1),(g)(1), (h)(1) Reciprocating compressor rod packing venting Reciprocating compressor venting Harmonizing edit

§98.232(i)(1) (1) Meters, regulators, and associated equipment atabove grade transmissiondistribution transfer stations, including equipment leaks from connectors, block valves, control valves, pressure relief valves, orifice meters, regulators, and open ended lines. (1) Equipment leaks from connectors, block valves, control valves, pressure relief valves, orifice meters, regulators, and open-ended lines at above grade transmission-distribution transfer stations. Clarifying edit

§98.232(i)(2) and (i)(4) (2) Equipment leaks from vaults at... (2) Equipment leaks at... Clarifying edit

§98.232(i)(3) (3) Meters, regulators, and associated equipment atabove grade meteringregulating station. (3) Equipment leaks at above grade metering-regulating stations that are not above grade transmission-distribution transfer stations. Clarifying edit

§98.232(i)(5) (5) Pipeline main equipment leaks. (5) Distribution main equipment leaks. Clarifying edit

§98.232(i)(6) (6) Se rvice line equipment leaks. (6) Distribution services equipment leaks. Clarifying edit

§98.233 throughout Methodologies Methods Clarifying edit CEMS Continuous emissions monitoring system (CEMS) Clarifying edit

General Stationary Fuel Combustion General Stationary Fuel Combustion Sources Clarifying edit

§98.233(a) and (c) Equation W-1 and W-2 calculate mass emissions in CO 2 e. Removed term “Conv i ” so that Equations W-1 and W-2 calculate volumetric emissions instead of mass emissions in CO 2 e. Global warming potential for methane removed from calculation.

§98.233(a) and (c); Terms Mass t,i ” and “Mass i ” in Equations W-1 and W-2 Mass t,i = Annual total mass GHG emissions in metric tons CO 2 e per year from natural gas pneumatic device venting (pump venting) for GHG i

. E s,i = Annual total volumetric GHG emissions at standard conditions in standard cubic feet per year from natural gas pneumatic devices (pumps) for GHG i. Revised intro paragraph (a) to reflect volumetric emissions of CH 4 and CO 2 ; Changed equation terms from “Mass t,i ” (Equation W-1) and “Mass i ” (Equation W2) to “E s,i ” and revised units from mass to volumetric at standard condition (EPA is proposing to revise the reporting of annual emissions from each source from units of metric tons of CO 2 e to

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change metric tons of each reported GHG). §98.233(a) and (c); Terms “T t ” and “T” in Equation W-1 and W-2 Average estimated number of hours in the operating year the devices of each type were operational. Default is 8760 hours Average estimated number of hours in the operating year the devices of each type were operational using engineering estimates based on best available data. Default is 8760 hours Clarifying edit

§98.233 (a) and (c); Term “EF t ” in Equation W-1 and “EF” in Equation W-2 EF t = Population emission factors for natural gas pneumatic device venting listed in Tables...

EF = Population emission factors for natural gas pneumatic devices (natural gas driven pumps) listed in Tables... EF t = Population emission factors for natural gas pneumatic device vents (in standard cubic feet per hour per device) of each type “t” listed in Tables...

EF = Population emissions factors for natural gas driven pneumatic devices (in standard cubic feet per hour per pump) listed in Table... Clarifying edit

§98.233(c); Term “Count” in Equation W-2 Count = Total number of natural gas pneumatic pumps Count = Total number of natural gas driven pneumatic

pumps. Clarifying edit

§98.233(a)(4) and (c)(2) None Calculate both CH 4 and CO 2 mass emissions from volumetric emissions using calculations in paragraph (v) of this section. Added (a)(4) and (c)(2) to convert volumetric to mass emissions.

§98.233(d)(2) Term “Vol CO2 ” in Equation W-3 Vol CO2 – Volumetric fraction of CO 2 content in vent gas out of the AGR unit as determined in (d)(6) of this section. Vol CO2 – Annual average volumetric fraction of CO 2 content in vent gas flowing out of the AGR unit as determined in paragraph (d)(6) of this section. Clarified that the term should be an annual

average

§98.233(d)(3) Term “Vol I ” in Equations W-4A and W-4B Vol I , - Volume fraction of CO 2 content in natural gas into the AGR unit... Vol I , - Annual average volumetric fraction of CO 2 content in natural gas flowing into the AGR unit... Clarified that the term should be an annual

average

§98.233(d)(3); Term “Vol o ” in Equations W-4A and W-4B Vol o – volume fraction of CO 2 content in natural gas out of the AGR unit... Vol o – Annual average volumetric fraction of CO 2 content in natural gas flowing out of the AGR unit... Clarified that the term should be an annual

average

§98.233(d)(4) AspenTech HYSYS ® , and API 4679 AMINECalc AspenTech HYSYS ® , or API 4679 AMINECalc Clarifying edit

§98.233(d)(5) Similar changes for (d)(6,7,8) Record the gas flow rate of the inlet and outlet natural gas stream of an AGR unit... For Calculation Method 3, record the gas flow rate of theinlet when using Equation W4A of this section or the gas flow rate of the outlet when using Equation W-4B of this Clarified instructions so that they refer to specific equations and calculation methods

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change section for the natural gas stream of an AGR unit... §98.233(d)(6) If continuous gas analyzer is not available on the vent stack, either install a continuous gas analyzer or take quarterly gas samples from the vent gas stream to determine Vol CO2 according to methods set forth in §98.234(b). For Calculation Method 2, if a continuous gas analyzer is not available on the vent stack, either install a continuous gas analyzer or take quarterly gas samples from the vent gas stream to determine Vol CO2 in Equation W-3 of this section according to methods set forth in §98.234(b). §98.233(d)(7) If a continuous gas analyzer is installed on the inlet gas stream, then the continuous gas analyzer results must be used. If a continuous gas analyzer is not available, either install a continuous gas analyzer or take quarterly gas samples from the inlet gas stream to determine Vol I according to methods set forth in §98.234(b). For Calculation Method 3, if a continuous gas analyzer is installed on the inlet gas stream, then the continuous gas analyzer results must be used. If a continuous gas analyzer is not available, either install a continuous gas analyzer or take quarterly gas samples from the inlet gas stream to determine Vol I in Equation W-4A or W-4B of this section according to methods set forth in §98.234(b). §98.233(d)(8) Determine volume fraction of CO 2 content in natural gas out of the AGR unit using one of the methods specified in paragraph (d)(8) of this section. For Calculation Method 3, determine annual average volumetric fraction of CO 2 content in natural gas flowing out of the AGR unit using one of the methods specified in paragraphs (d)(8)(i) through (d)(8)(iii) of this section. §98.233(d)(8)(ii) (ii) If a continuous gas analyzer is not available or installed, quarterly gas samples may be taken from the outlet gas stream to determine Vol O according to methods set forth in §98.234(b). (ii) If a continuous gas analyzer is not available or installed, quarterly gas samples may be taken from the outlet gas stream to determine Vol O in Equation W-4A or W4B of this section according to methods set forth in §98.234(b). Clarifying edits

§98.233(d)(8)(iii) Use sales line quality specification for CO 2 in natural gas. If a continuous gas analyzer is not available or installed, you may use sales line quality specification for CO 2 in natural

gas. Clarifying edit

§98.233(d)(9) Calculate CO 2 volumetric emissions at standard Calculate annual volumetric CO 2 emissions at standard Clarified that the result is annual emissions.

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change conditions using calculations in paragraph (t) of this section. conditions using calculations in paragraph (t) of this section.

§98.233(d)(10) Mass CO 2 emissions shall be calculated from volumetric CO 2 emissions using calculations in paragraph (v) of this section. Calculate CO 2 annual mass emissions at standard conditions using calculations in paragraph (v) of this section. Revised to specify emissions at standard conditions

§98.233(d)(11) Determine if emissions from the AGR unit are recovered and transferred outside the facility. Adjust the emission estimated in paragraphs (d)(1) through (d)(10) of this section downward by the magnitude of CO 2 emission recovered and transferred outside the facility. Determine if CO 2 emissions from the AGR unit are recovered and transferred outside the facility. Adjust the CO 2 emissions estimated in paragraphs (d)(1) through (d)(10) of this section downward by the magnitude of CO 2 emissions recovered and transferred outside the facility. Clarifying edit

§98.233(e)(1) (1) Calculation Methodology 1. Calculate annual mass emissions from dehydrator vents with annual average daily throughput greater than or equal to 0.4 million standard cubic feet per day using a software program, such as AspenTech HYSYS® or GRI-GLYCalc, that uses the Peng-Robinson equation of state to calculate the equilibrium coefficient, speciates CH 4 and CO 2 emissions from dehydrators, and has provisions to include regenerator control devices, a separator flash tank, stripping gas and a gas injection pump or gas assist pump. A minimum of the following parameters determined by engineering estimate based on best available data must be used to characterize emissions from dehydrators: (1) Calculation Method 1. Calculate annual mass emissions from absorbent dehydrators that have an annual average of daily natural gas throughput that is greater than or equal to 0.4 million standard cubic feet per day by using a software program, such as AspenTech HYSYS® or GRI-GLYCalcTM, that uses the Peng-Robinson equation of state to calculate the equilibrium coefficient, speciates CH 4 and CO 2 emissions from dehydrators, and has provisions to include regenerator control devices, a separator flash tank, stripping gas and a gas injection pump or gas assist pump. The following parameters must be determined by engineering estimate based on best available data and must be used at a minimum to characterize emissions from dehydrators: Clarifying edits

§98.233(e)(1)(iv) (iv) Absorbent circulation pump type (natural gas pneumatic/air pneumatic/electric). (iv) Absorbent circulation pump type (e.g., natural gas pneumatic/air pneumatic/electric). Clarifying edit

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change §98.233(e)(1)(vi) (vi) Absorbent type: including triethylene glycol (TEG), diethylene glycol (DEG) or ethylene glycol (EG). (vi) Absorbent type (e.g., triethylene glycol (TEG), diethylene glycol (DEG) or ethylene glycol (EG)). Clarifying edit

§98.233(e)(1)(xi) xi) Wet natural gas composition. Determine this parameter by selecting one of the methods described under paragraph (e)(1)(xi) of this section. (A) Use the wet natural gas composition as defined in paragraph (u)(2)(i) or (u)(2)(ii) of this section. (B) If wet natural gas composition cannot be determined using paragraph (u)(2)(i) or (u)(2)(ii) of this section, select a representative analysis. (xi) Wet natural gas composition. Determine this parameter using one of the methods described in paragraphs (e)(1)(xi)(A) through (e)(1)(xi)(D) of this section. (A) Use the GHG mole fraction as defined in paragraph (u)(2)(i) or (u)(2)(ii) of this section. (B) If the GHG mole fraction cannot be determined using paragraph (u)(2)(i) or (u)(2)(ii) of this section, select a representative analysis. Harmonizing edit

§98.233(e)(2) (2) Calculation Methodology 2. Calculate annual CH 4 and CO2 emissions from glycol dehydrators with annual average daily throughput less than 0.4 million standard cubic feet per day using Equation W-5 of this section: (2) Calculation Method 2. Calculate annual volumetric emissions from glycol dehydrators that have an annual average of daily natural gas throughput that is less than 0.4 million standard cubic feet per day using Equation W-5 of this section: Clarifies that result is annual volumetric emissions.

Term “Count” in Equation W-5 Count = Total number of glycol dehydrators with throughput less than 0.4 million standard cubic feet per day. Count = Total number of glycol dehydrators that have an annual average of daily natural gas throughput that is less than 0.4 million standard cubic feet per day. Clarifying edits

Term “P” in Equation W-6 P p Corrects typo (to lower case). §98.233(f) (f) Well venting for liquids unloadings. Calculate CO 2 and CH 4 emissions from well venting for liquids unloading using one of the calculation methodologies described in paragraphs (f)(1), (f)(2) or (f)(3) of this section. (f) Well venting for liquids unloadings. Calculate annual volumetric natural gas emissions from well venting for liquids unloading using one of the calculation methods described in paragraphs (f)(1), (f)(2), or (f)(3) of this section. Calculate annual CH 4 and CO 2 volumetric and mass emissions using the method described in paragraph (f)(4) of this section. Clarifies that results of (f)(1), (f)(2), and (f)(3) are annual volumetric natural gas emissions and provides (f)(4) for calculation of annual CH 4 and CO 2 volumetric and mass emissions.

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change §98.233(f)(1)(i) (i) Determine the well vent average flow rate as specified under paragraph (f)(1)(i) of this section for at least one well in a unique well tubing diameter group and pressure groupcombination in each subbasin category. (i) Determine the well vent average flow rate (“FR” in Equation W-7A of this section) as specified in paragraphs (f)(1)(i)(A) through (f)(1)(i)(C) of this section for at least one well in a unique well tubing diameter group and pressure group combination in each sub-basin category. Calculate emissions from wells with plunger lifts and wells without plunger lifts separately. Clarifies instructions so that they refer to specific equation terms and calculation methods

§98.233(f)(1)(i)(A) (A) The average flow rate per hour of venting is calculated for each unique tubing diameter group and pressure group combination in each sub-basin category by dividing the recorded total flow by the recorded time (in hours) for all measured liquid unloading events with venting to the atmosphere. (A) Calculate the average flow rate per hour of venting for each unique tubing diameter group and pressure group combination in each sub-basin category by dividing the recorded total annual flow by the recorded time (in hours) for all measured liquid unloading events with venting to the atmosphere. Clarifies that recorded total flow is total annual flow.

§98.233(f)(1)(i)(B) (B) This average flow rate per hour is applied to all wells in the same pressure group that have the same tubing diameter group, for the number of hours of venting these wells. (B) Apply the average hourly flow rate calculated under paragraph (f)(1)(i)(A) of this section to all wells in the same pressure group that have the same tubing diameter group, for the number of hours of venting these wells. Clarifying edits

§98.233(f)(1)(i)(C) (C) A new average flow rate is calculated every other calendar year for each reporting sub-basin category starting the first calendar year of data collection. For a new producing sub-basin category, an average flow rate is calculated beginning in the first year of production. (C) Calculate a new average flow rate every other calendar year starting with the first calendar year of data collection. For a new producing sub-basin category, calculate an average flow rate beginning in the first year of production. Harmonizing edit with changes to term “FR” in Equation W-7.

§98.233(f)(2) and (f)(3); Term “E s,n ” ofEquations W-8 and W9 E s,n = Annual natural gas emissions at standard conditions, in cubic feet/year. E s = Annual natural gas emissions for each sub-basin at standard conditions, s, in cubic feet per year. Clarifying edits

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change §98.233(f)(2) and (f)(3); Terms “p” and “q” of Equations W-8 and W-9 None p = Wells 1 through W with well venting for liquids unloading for each sub-basin.

... q = Unloading event. Clarifies terms not previously defined

§98.233(f)(2) and (f)(3); Term “V p ” ofEquations W-8 and W9 V p = Number of unloading events per year per well, p. V p = Total number of unloading events in the monitoring period per well, p. Corrects equation term to reflect the number of unloading events in each monitoring period. §98.233(f)(2) and (f)(3); Term “SFR p ” ofEquations W-8 and W9 SFR p = Average flow-line rate of gas for well, p, at standard conditions in cubic feet per hour. Use Equation W-33 to calculate the average flow-line rate at standard conditions. SFR p = Average flow-line rate of gas for well, p, at standard conditions in cubic feet per hour. Use Equation W-33 of this section to calculate the average flow-line rate at standard conditions. Clarifying edit

§98.233(f)(3)(i) and (ii) Reserved None Removes reserved paragraphs §98.233(f)(4) (4) Both CH 4 and CO 2 volumetric and mass emissions shall be calculated from volumetric natural gas emissions using calculations in paragraphs (u) and (v) of this section. (4) Calculate CH 4 and CO 2 volumetric and mass emissions from volumetric natural gas emissions using calculations in paragraphs (u) and (v) of this section. Applies active voice

§98.233(g) introductory paragraph; §98.233(g)(3) (g) Gas well venting during completions and workovers from hydraulic fracturing

. Calculate CH 4 , CO 2 and N 2 O annual emissions from gas well venting during completions involving hydraulic fracturing in wells and well workovers using Equation W-10A or Equation W-10B of this section. Equation W-10A applies to well venting when the backflow rate is measured or calculated, Equation W-10B applies when the backflow vent or flare volume ismeasured. Use Equation W10A if the flow rate for backflow during well completions and workovers from hydraulic fracturing is known for the specified number of wells perparagraph (g)(1) in a subbasin and well type (g) Gas well venting during completions and workovers with hydraulic fracturing

. Calculate annual volumetric natural gas emissions from gas well venting during completions and workovers involving hydraulic fracturing using Equation W-10A or Equation W-10B of this section. Equation W-10A applies to well venting when the flowback rate is measured from a specified number of example completions orworkovers and Equation W10B applies when the flowback vent or flare volume is measured for each completion or workover. Completion and workover activities are separated into two periods, an initial period when flowback is routed to open pits or tanks and a subsequent period when gas Clarifies instructions; clarifies that results of (g)(1) and (g)(2) are annual volumetric natural gas emissions and clarifies (g)(3) for calculation of annual CH 4 and CO 2 volumetric and mass emissions.

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change (horizontal or vertical) combination. Use Equation W-10B if the flow volume for backflow during well completions and workovers from hydraulic fracturing isknown for all wells in a subbasin and well type (horizontal or vertical) combination. Both CH 4 and CO 2 volumetric and mass emissions shall be calculated from volumetric total gas emissions using calculations in paragraphs (u) and (v) of this section. content is sufficient to route the flowback to a separator or when the gas content is sufficient to allow measurement by the devices specified in paragraph (g)(1) of this section, regardless of whether a separator is actually utilized. If you elect to use Equation W-10A of this section, you must follow the procedures specified in paragraph (g)(1) of this section. Emissions must be calculated separately for completions and workovers, for each sub-basin, and for each well type combination identified in paragraph (g)(2) of this section. You must calculate CH 4 and CO 2 volumetric and mass emissions as specified in paragraph (g)(3) of this section. If emissions from gas well venting during completions and workovers with hydraulic fracturing are routed to a flare, you must calculate CH 4 , CO 2 , and N 2 O annual emissions as specified in paragraph (g)(4) of this section. Term E s,n in Equations

W-10A and W-10B Annual volumetric total gas emissions in cubic feet at standard conditions from gas well venting during completions or workovers following hydraulic fracturing for each sub-basin and well type (horizontal vs. vertical) combination. Annual volumetric natural gas emissions in standard cubic feet from gas well venting during completions or workovers following hydraulic fracturing for each sub-basin and well type combination. Clarifying edits

Term W in equations

W-10A and W-10B Total number of wells completed or worked over using hydraulic fracturing in a sub-basin and well type (horizontal vs. vertical) combination. Total number of wells completed or worked over using hydraulic fracturing in a sub-basin and well type combination. Clarifying edits

Term FRM s of Equations W-10A and W-10B FRM s = Ratio of flowback during well completions and workovers from hydraulic fracturing to 30-day FRM s = Ratio of average flowback, during the period when sufficient quantities of gas are present to enable Harmonizing edits with changes to Equations W-10A and W-10B

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change production rate from Equation W-12. separation, of well completions and workovers from hydraulic fracturing to 30-day production rate Term EnF s,p in equations W-10A and

W-10B Volume of CO 2 or N 2 injected gas in cubic feet at standard conditions that was injected into the reservoir during an energized fracture job for each well, p. If the fracture process did not inject gas into the reservoir, then EnF s,p is 0. If injected gas is CO 2 then EnF s,p is 0. Volume of N 2 injected gas in cubic feet at standard conditions that was injected into the reservoir during an energized fracture job for each well, p, as determined by using an appropriate meter according to methods described in §98.234(b), or by using receipts of gas purchases that are used for the energized fracture job. Convert to standard conditions using paragraph (t) of this section. If the fracture process did not inject gas into the reservoir or if the injected gas is CO 2 then EnF s ,p is 0. Clarifies acceptable measurement methods

§98.233(g)(1)(i) Calculation Methodology 1

.When using Equation W10A, for each measured well completion(s) in each gas producing sub-basin category and well type (horizontal or vertical) combination and for each measured well workover(s) in each gas producing sub-basin category and well type (horizontal or vertical) combination, a recording flow meter (digital or analog) shall be installed on the vent line, ahead of a flare or vent if used, to measure the backflow rate according to methods set forth in §98.234(b). Calculation Method 1 . You must use Equation W-12A as specified in paragraph (g)(1)(iii) of this section to determine the value of FRM s .You must use Equation W12B as specified in paragraph (g)(1)(iv) of this section to determine the value of FRM i

. The procedures specified in paragraphs (g)(1)(v) and (g)(1)(vi) also apply. When making flowback measurements for use in Equations W-12A and W-12B of this section, you must use a recording flow meter (digital or analog) installed on the vent line, ahead of a fl are or vent, to measure the flowback rates in units of standard cubic feet per hour according to methods set forth in §98.234(b). Harmonizing changes with edits to Equation W-10A and W-10B

§98.233(g)(1)(ii) (ii) Calculation Methodology 2 . When using Equation W10A, for each calculated horizontal well completion and each calculated vertical well completion in each gas (ii) Calculation Method 2 . You must use Equation W-12A as specified in paragraph (g)(1)(iii) of this section to determine the value of FRM s .You must use Equation WHarmonizing changes with edits to Equation W-10A and W-10B

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change producing sub-basin category and for each calculated well horizontal workover and for each calculated vertical well workover in each gas producing sub-basin category, record the well flowing pressure upstream (and downstream in subsonic flow) of a well choke according to methods set forth in §98.234(b) to calculate the well backflow during well completions and workovers from hydraulic fracturing. Calculateemissions using Equation W11A of this section for subsonic flow or Equation W-11B of this section for sonic flow. Use best engineering estimate based on best available data along with Equation W-11C of this section to determine whether the predominant flow is sonic or subsonic. If the value of R in Equation W-11C is greater than or equal to 2, then flow is sonic; otherwise, flow is subsonic. 12B as specified in paragraph (g)(1)(iv) of this section to determine the value of FRM i

. The procedures specified in paragraphs (g)(1)(v) and (g)(1)(vi) also apply. When calculating the flowback rates for use in Equations W-12A and W-12B of this section based on well parameters, you must record the well flowing pressure immediately upstream (and immediately downstream in subsonic flow) of a well choke according to methods set forth in §98.234(b) to calculate the well flowback. The upstream pressure must be surface pressure and reservoir pressure cannot be assumed. The downstream pressure must be measured after the choke and atmospheric pressure cannot be assumed. Calculate flowback rate using Equation W-11A of this section forsubsonic flow or Equation W11B of this section for sonic flow. You must use best engineering estimates based on best available data along with Equation W-11C of this section to determine whether the predominant flow is sonic or subsonic. If the value of R in Equation W-11C is greater than or equal to 2, then flow is sonic; otherwise, flow is subsonic. Calculated FR a values shall be converted from actual conditions upstream of the restriction orifice to standard conditions (FR s,p and FR i,p ) for use in Equations W12A and W-12B of this section using Equation W-33 in paragraph (t) of this section. Term “FR a ” of Equation W-11A and W-11B FR a= Average flow rate in cubic feet per hour, under actual subsonic flow conditions. FR a= Flowback rate in actual cubic feet per hour, under actual subsonic flow conditions. Harmonizing edits withchanges to Equation W12a and W-12b

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change

Terms “P 1 ”, “T u ”, and “P 2 ” of Equation W11A P 1 = Upstream pressure (psia). T u= Upstream temperature (degrees Kelvin). P 2 = Downstream pressure (psia). P 1 = Pressure immediately upstream of the choke (psia). T u= Temperature immediately upstream of the choke (degrees Kelvin). P 2 = Pressure immediately downstream of the choke (psia). Clarifying edits

Term “T u ” of Equation W-11B T u= Upstream temperature (degrees Kelvin). T u= Temperature immediately upstream of the choke (degrees Kelvin). Clarifying edits

Terms “P 1 ” and “P 2 ” of Equation W-11C P 1 = Pressure upstream of the restriction orifice in pounds per square inch absolute. P 2 = Pressure downstream of the restriction orifice in pounds per square inch absolute. P 1 = Pressure immediately upstream of the choke (psia). P 2 = Pressure immediately downstream of the choke (psia). Clarifying edits

§98.233(g)(1)(iii) For Equation W-10A, the ratio of backflow rate during well completions and workovers from hydraulic fracturing to 30-day production rate is calculated using Equation W-12 of this section. For Equation W-10A of this section, calculate FRM s using Equation W-12A of this section. Harmonizing edits withchanges to Equation W10A

Terms “FRM s ” and “FR s,p ” of Equation W12A FRM s = Ratio of flowback rate during well completions and workovers from hydraulic fracturing to 30- day production rate.

FR s,p = Measured flowback rate from Calculation Methodology 1 described in paragraph (g)(1)(i) of this section or calculated flow rate from Calculation Methodology 2 described in paragraph (g)(1)(ii) of this section in standard cubic feet per hour for well(s) p for each sub-basin and well type (horizontal or vertical) combination. Measured and calculated FR avalues shall be converted from actual conditions (FR a ) to standard conditions (FR s,p ) for each well p using Equation W-33 FRM s = Ratio of average flowback rate during period of time when sufficient quantities of gas are present to enable separation of well completions and workovers from hydraulic fracturing to 30-dayproduction rate for each subbasin and well type combination.

FR s,p = Measured average flowback rate from Calculation Method 1 described in paragraph (g)(1)(i) of this section or calculated average flowback rate from Calculation Method 2 described in paragraph (g)(1)(ii) of this section, during the separation period in standard cubic feet per hour for well(s) p for each sub-basin and well type combination. Measured and Harmonizing edits withchanges to Equation W10A

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change in paragraph (t) of this section. You may not use flow volume as used in Equation W-10B converted to a flow rate for this parameter. calculated FR avalues shall be converted from actual conditions upstream of the restriction orifice (FR a ) to standard conditions (FR s,p ) foreach well p using Equation W33 in paragraph (t) of this section. You may not use flow volume as used in Equation W-10B converted to a flow rate for this parameter. Term “N” of Equation W-12A None N = Number of measured or calculated well completions or workovers using hydraulic fracturing in a sub-basin and well type combination. Harmonizing edits withchanges to Equation W10A

§98.233(g)(1)(iv) None For Equation W-10A of this section, calculate FRM i using Equation W-12B of this section.

, 1

, 1 N

i p

p i N

s p p 

### FR

FRM

PR 

 

###  

# 

 (Eq. W12B)

Where: FRM i = Ratio of flowback gas rate while flowing to open tanks/pits during well completions and workovers from hydraulic fracturing to 30-day production rate.

FR i,p = Initial measured gas flowback rate from Calculation Method 1 described in paragraph (g)(1)(i) of this section or initial calculated flow rate from Calculation Method 2 described in paragraph (g)(1)(ii) of this section in standard cubic feet per hour for well(s), p, for each sub-basin and well type combination. Measured and calculated FR i,p values must be based on flow conditions at the beginning of the separation Harmonizing edits withchanges to Equation W10A

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change period and must be expressed at standard conditions.

PR s,p = Average production flow rate during the first 30- days of production after completions of newly drilled gas wells or gas well workovers using hydraulic fracturing, in standard cubic feet per hour of each well, p,that was measured in the subbasin and well type combination.

N = Number of measured or calculated well completions or workovers using hydraulic fracturing in a sub-basin and well type combination. §98.233(g)(1)(v) and (vi) (iv) For Equation W-10A, the ratio of backflow rate during well completions and workovers from hydraulic fracturing to 30-day production rate for horizontal and vertical wells are applied to all horizontal and vertical well completions in the gas producing sub-basin and well type combination and to all horizontal and vertical well workovers, respectively, in the gas producing sub-basin and well type combination for the total number of hours of backflow for each of these wells.

(v) For Equation W-10A, new flow rates for horizontal and vertical gas well completions and horizontal and vertical gas well workovers in each sub-basin category shall be calculated once every two years starting in the first calendar year of data collection. (v) For Equation W-10A of this section, the ratio of flowback rate during well completions and workovers from hydraulic fracturing to 30-day production rate for horizontal and vertical wells are applied to all horizontal and vertical well completions in the gas producing sub-basin and well type combination and to all horizontal and vertical well workovers, respectively, in the gas producing sub-basin and well type combination for the total number of hours of flowback and for the first 30 day average production rate for each of these wells.

(vi) For Equation W-12A and W-12B of this section, calculate new flowback rates for horizontal an d vertical gas well completions and horizontal and vertical gaswell workovers in each subbasin category once every two years starting in the first calendar year of data collection. Renumbered and revised to harmonize with edits to Equation W-10A

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change §98.233(g)(4) (5) Calculate annual emissions from gas well venting during well completions and workovers from hydraulic fracturing to flares as follows: (i) Use total gas well venting volume during well completions and workovers as determined in paragraph (g) of this section. (ii) Use the calculation methodology of flare stacks in paragraph (n) of this section to determine gas well venting during well completions and workovers using hydraulic fracturing emissions from the flare. This adjustment to emissions from completions using flaring versus completions without flaring accounts for the conversion of CH 4 to CO 2 in the flare. (4) Calculate annual emissions from gas well venting during well completions and workovers from hydraulic fracturing where all or a portion of the gas is flared as specified in paragraphs (g)(4)(i) and (g)(4)(ii) of this section. (i) Use the volumetric total natural gas emissions vented to the atmosphere during well completions and workovers as determined in paragraph (g) of this section to calculate volumetric and mass emissions using paragraphs (u) and (v) of this section. (ii) Use the calculation method of flare stacks in paragraph (n) of this section to adjust emissions for the portion of gas flared during well completions and workovers using hydraulic fracturing. This adjustment to emissions from completions using flaring, versus completions without flaring, accounts for the conversion of CH 4 to CO 2 in the flare and for the formation on N 2 O during flaring. Renumbered; clarifies calculation method where a portion of the gas is flared

§98.233(h) introductory paragraph; §98.233(h)(1) Calculate CH 4 , CO 2 and N 2 O annual emissions from gas well venting during completions and not involving hydraulicfracturing using Equation W13of this section. Calculate annual volumetric natural gas emissions from each gas well venting during workovers without hydraulicfracturing using Equation W13A of this section. Calculate annual volumetric natural gas emissions from each gas well venting during completions without hydraulic fracturing using Equation W-13B of this section. You must convert annual volumetric natural gas emissions to CH 4 and CO 2 volumetric and mass emissions as specified in paragraph (h)(1) of this section. If emissions from gas well Edits clarify instructions; clarifies that results of Equations W-13A and W-13B are annual volumetric natural gas emissions and clarifies (h)(1) for calculation of annual CH 4 and CO 2 volumetric and mass emissions

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change venting during completions and workovers without hydraulic fracturing are routed to a flare, you must calculate CH 4 , CO 2 , and N 2 O annual emissions as specified in paragraph (h)(2) of this section. Term “Tp” of Equation W-13 T p = Time each well completion without hydraulic fracturing, p, was venting in hours during the year. T p = Time that gas is vented to either the atmosphere or a flare for each well, p, undergoing completion without hydraulic fracturing, in hours during the

year. Clarifying edits

§98.233(h)(2) (2) Calculate annual emissions from gas well venting during well completions and workovers not involving hydraulic fracturing to flares as follows: (i) Use the gas well venting volume during well completions and workovers as determined in paragraph (h) of this section. (ii) Use the calculation methodology of flare stacks in paragraph (n) of this section to determine gas well venting during well completions and workovers emissions without hydraulic fracturing from the flare. (2) Calculate annual emissions of CH 4 , CO 2 , and N 2 O from gas well venting to flares during well completions and workovers not involving hydraulic fracturing as specified in paragraphs (h)(2)(i) and (h)(2)(ii) of this section. (i) Use the gas well venting volume and gas composition during well completions and workovers that are flared as determined using the methods specified in paragraphs (h) and (h)(1) of this section. (ii) Use the calculation method of flare stacks in paragraph (n) of this section to determine emissions from the flare for gas well venting to a flare during completions and workovers without hydraulic fracturing. Clarifying edits

§98.233(i) Blowdown vent stacks

. Calculate CO 2 and CH 4 blowdown vent stack emissions from depressurizing equipment(s) to reduce system pressure for planned or emergency shutdowns resulting from human intervention or to take equipment out of service for maintenance (excluding depressurizing to a flare, over-pressure relief, Blowdown vent stacks

. Calculate CO 2 and CH 4 blowdown vent stack emissions from the depressurization of equipment to reduce system pressure for planned or emergency shutdowns resulting from human intervention or to take equipment out of service for maintenance as specified in either paragraph (i)(2) or (i)(3) of this section. Equipment with Clarifies the applicability of requirements to equipment with a physical volume of less than 50 cubic feet

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change operating pressure control venting and blowdown of non-GHG gases; desiccant dehydrator blowdown venting before reloading is covered in paragraph (e)(5) of this section) as follows: a unique physical volume of less than 50 cubic feet as determined in paragraph (i)(1) of this section are not subject to the requirements in paragraphs (i)(2) through (i)(4) this section. The requirements in this paragraph (i) do not apply to blowdown vent stack emissions from depressurizing to a flare, over-pressure relief, operating pressure controlventing, blowdown of nonGHG gases, and desiccant dehydrator blowdown venting before reloading. §98.233(i)(1) (1) Calculate the unique physical volume (including pipelines, compressor case or cylinders, manifolds, suction bottles, discharge bottles, and vessels) between isolation valves determined by engineering estimates based on best available data. (1) Method for calculating unique physical volumes . You must calculate each unique physical volume (including pipelines, compressor case or cylinders, manifolds, suction bottles, discharge bottles, and vessels) between isolation valves, in cubic feet, by using engineering estimates based on best available data. Clarifies units

§98.233(i)(2) (2) If the unique physical volume between isolation valves is greater than or equal to 50 cubic feet, retain logs of the number of blowdowns for each unique physical volume (including but not limited to compressors, vessels, pipelines, headers, fractionators, and tanks). Unique physical volumes smaller than 50 cubic feet are exempt from reporting under paragraph (i) of this section. None Harmonizing change with edits to Equations W-14A and W-14B

§98.233(i)(3) (3) Calculate the total annual venting emissions for unique volumes using either Equation W-14A or W-14B of this section. (2) Method for determining emissions from blowdown vent stacks according to equipment type . If you elect to determine emissions according to each equipment type, using unique physical volumes as calculated in paragraph (i)(1) of this section, you must calculate emissions as Renumbered and revised; clarifies instructions for determining emissions by equipment type.

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change specified in paragraphs (i)(2)(i) through (i)(2)(iii) of this section for each equipment type. Equipment types must be grouped into the following seven categories: station piping, pipeline venting,

compressors, scrubbers/strainers, pig launchers and receivers, emergency shutdowns, and all other blowdowns greater than or equal to 50 cubic feet. (i) Calculate the total annual natural gas emissions from each unique physical volume that is blown down usingeither Equation W-14A or W14B of this section.

.... (ii) Calculate the annual natural gas emissions, in cubic feet, from each equipment type by summing E s,n , as calculated in either Equation W-14A or Equation W-14B of this subpart, for all unique physical volumes associated with the equipment type. (iii) Calculate total annual CH 4 and CO 2 volumetric and mass emissions from each equipment type by using the annual natural gas emission value calculated in paragraph (i)(2)(ii) of this section for the equipment type and the calculation method specified in paragraph (i)(4) of this section. §98.233(i)(4) Calculate both CH 4 and CO 2 volumetric and mass emissions using calculations in paragraph (u) and (v) of this section. Method for converting from natural gas emissions to GHG volumetric and mass emissions . Calculate both CH 4 and CO 2 volumetric and mass emissions using the methods specified in paragraphs (u) and (v) of this section. Clarifying edits

§98.233(j), (j)(1) introductory paragraph, (j)(2) introductory (j) ... not owned or operated by the reporter), calculate annual CH 4 and CO 2 emissions using any of the (j) ... not owned or operated by the reporter), as specified in this paragraph (j). For wells flowing to gas-liquid Clarifies and consolidates instructions for use of calculation methods by

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change paragraph, removal of (j)(3)introductory paragraph, removal of (j)(4), and revision and renumbering of paragraph (j)(5). calculation methodologies described in this paragraph (j). (1) Calculation Methodology 1 . For separators with annual average daily throughput of oil greater than or equal to 10 barrels per day. Calculate... (2) Calculation Methodology 2 . Calculate annual CH 4 and CO 2 emissions from onshore production storage tanks for wellhead gas-liquid separators with annual average daily throughput of oil greater than or equal to 10 barrels per day by.... (3) Calculation Methodology 3 . For wells with annual average daily oil production greater than or equal to 10 barrels per day that flow directly to atmospheric storage tanks without passing through a wellhead separator, calculate annual CH 4 and CO 2 emissions by either of the methods in paragraph (j)(3) of this section: ... (4) Calculation Methodology 4 . For wells with annual average daily oil production greater than or equal to 10 barrels per day that flow to a separator not at the well pad, calculate annual CH 4 and CO 2 emissions by either of the methods in paragraph (j)(4) of this section: ... (5) Calculation Methodology 5 . For well pad gas-liquid separators and for wells flowing off a well pad without passing through a gas-liquid separator with annual average daily throughput of oil less than 10 barrels per day use.... separators with annual average daily throughput of oil greater than or equal to 10 barrels per day, calculate annual CH 4 and CO 2 using Calculation Method 1 or 2 as specified in paragraphs (j)(1) and (j)(2) of this section. For wells flowing directly to atmospheric storage tanks without passing through a wellhead separator with throughput greater than 10 barrels per day, calculate annual CH 4 and CO 2 emissions using Calculation Method 2 as specified in paragraph (j)(2) of this section. For wells flowing to gas-liquid separators or directly to atmospheric storage tanks with throughput less than 10 barrels per day, use Calculation Method 3 as specified in paragraphs (j)(3) of this section. You must also calculate emissions that may have occurred due to dump valves not closing properly using the method specified in paragraphs (j)(6) of this section. If emissions from atmospheric pressure fixed roof storage tanks are routed to a vapor recovery system, you must adjust the emissions downward according to paragraph (j)(4) of this section. If emissions from atmospheric pressure fixed roof storage tanks are routed to a flare, you must calculate CH 4 , CO 2 , and N 2 O annual emissions as specified in paragraph (j)(5) of this section. removing and combining text from (j)(1) introductory, (j)(2) introductory, (j)(3) introductory, and (j)(4) paragraphs. Clarifies instructions in (j) intro to account for situations where part of the gas is recovered or flared

§98.233(j)(1)(vii) (vii) Separator oil composition and Reid vapor pressure. If this data is not (vii) Separator oil composition and Reid vapor pressure. If this data is not available, Corrects reference

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change available, determine these parameters by selecting one of the methods described under paragraph (j)(1) (vii) of this section. determine these parameters by using one of the methods described in paragraphs (j)(1)(vii)(A) through (j)(1)(vii)(C) of this section. §98.233(j)(9) and §98.233(l)(5) ...emissions from volumetric natural gas emissions... ...emissions from natural gas volumetric emissions... Grammatical correction; paragraph (j)(9) is renumbered to (j)(7) §98.233(k), (l), and (m) introductory paragraphs (k) .... calculate CH 4 , CO 2 and N 2 O annual emissions from compressor scrubber dump valve leakage as follows.

(l) .... Calculate CH 4, CO 2 and N 2 O (when flared) well testing venting and flaring emissions as follows:

(m) ... Calculate CH 4 , CO 2 and N 2 O (when flared) associated gas venting and flaring emissions not in conjunction with well testing (refer to paragraph (l): Well testing venting and flaring of this section) as follows: (k) ... calculate CH 4 and CO 2 annual emissions from compressor scrubber dump valve leakage as specified in paragraphs (k)(1) through (k)(3) of this section. If emissions from compressor scrubber dump valve leakage are routed to a flare, you must calculate CH 4 , CO 2 , and N 2 O annual emissions as specified in paragraph (k)(4) of this section.

(l) .. . Calculate CH 4 and CO 2 annual emissions from well testing venting as specified in paragraphs (l)(1) through (l)(5) of this section. If emissions from well testing venting are routed to a flare, you must calculate CH 4 , CO 2 , and N 2 O annual emissions as specified in paragraph (l)(6) of this section.

(m) ... Calculate CH 4 and CO 2 annual emissions from associated gas venting not in conjunction with well testing (refer to paragraph (l): Well testing venting and flaring of this section) as specified in paragraphs (m)(1) through (m)(4) of this section. If emissions from associated gas venting are routed to a flare, you must calculate CH 4 , CO 2 , and N 2 O annual emissions as specified in paragraph (m)(5) of this section. Clarifies instructions; clarifies N 2 O to be calculated from emissions routed to a flare

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change §98.233(k)(1) (k)(1) Monitor the tank vapor vent stack annually for emissions using an optical gas imaging instrument according to methods set forth in §98.234(a)(1) or by directly measuring the tank vent using a flow meter or high volume sampler according to methods in §98.234(b) through (d) for a duration of 5 minutes, or a calibrated bag according to methods in §98.234(b). Or you may annually monitor leakage through compressor scrubber dump valve(s) into the tank using an acoustic leak detection device according to methods set forth in §98.234(a)(5). (1) Except as specified in paragraph (k)(1)(iv) of this section, you must monitor the tank vapor vent stack annually for emissions using one of the methods specified in paragraphs (k)(1)(i) through (k)(1)(iii) of this section. (i) Use an optical gas imaging instrument according to methods set forth in §98.234(a)(1). (ii) Measure the tank vent directly using a flow meter or high volume sampler according to methods in §98.234(b) or (d) for a duration of 5 minutes. (iii) Measure the tank vent using a calibrated bag according to methods in §98.234(c) for a duration of 5 minutes or until the bag is full, whichever is shorter. (iv) You may annually monitor leakage through compressor scrubber dump valve(s) into the tank using an acoustic leak detection device according to methods set forth in §98.234(a)(5). Clarifying edits

§98.233(k)(2), (k)(2)(i), and (k)(4) (2) ... detects a leak, then use one of the following two methods in paragraph (k)(2) of this section to quantify annual emissions. (i) Use a meter, such as a turbine meter, calibrated bag, or high flow sampler to estimate tank vapor volumes from the vent stack according to methods set forth in §98.234(b) through (d)....If the vent is directly measured for five minutes under paragraph §98.233(k)(1) of this section to detect continuous leakage, this serves as the measurement. (2) ... detects a leak, then you must use one of the methods in either paragraph (k)(2)(i) or (k)(2)(ii) of this section and the requirements specified in paragraphs (k)(2)(iii) and (k)(2)(iv) of this section to quantify annual emissions. (i) Use a flow meter, such as a turbine meter, calibrated bag, or high volume sampler to estimate tank vapor volumes from the vent stack according to methods set forth in §98.234(b) through (d)....If the vent is directly measured for five minutes under paragraph (k)(1)(ii) or (k)(1)(iii) of this section to detect continuous leakage, this Clarifying edits; corrects references

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change serves as the measurement. §98.233(k)(2)(iv) (iv) Calculate GHG volumetric and mass emissions at standard conditions.... (iv) Calculate CH 4 and CO 2 volumetric and mass emissions at standard conditions... Clarifying edits

§98.233(k)(3) (3) If the leaking dump valve(s) is fixed following leak detection, the annual emissions shall be calculated from the beginning of the calendar year to the time the valve(s) is repaired (3) If a leaking dump valve is identified, the leak must be counted as having occurred since the beginning of the calendar year, or from the previous test that did not detect leaking in the same calendar year. If the leaking dump valve is fixed following leak detection, the leak duration will end upon being repaired. If a leaking dump valve is identified and not repaired, the leak must be counted as having occurred through the rest of the calendar year. Clarifying edits, including what to do if an earlier test showed no leak, and how to determine end of leak duration

§98.233(k)(4) (4) Calculate annual emissions from storage tanks to flares as follows: (4) Calculate annual emissions from storage tanks to flares as specified in paragraphs (k)(4)(i) and (k)(4)(ii) of this section. Corrects reference

§98.233(l)(2) and §98.233(m)(2) (l)(2) ... according to one of the two procedures in paragraph (l)(2) of this section to determine GOR:

(m)(2) ...then use one of the two procedures in paragraph (m)(2) of this section to determine GOR: (l)(2) ... according to one of the procedures specified in paragraph (l)(2)(i) or (l)(2)(ii) of this section to determine GOR.

(m)(2) ....then you must use one of the procedures specified in paragraphs (m)(2)(i) or (m)(2)(ii) of this section to determine GOR. Clarifying edits

§98.233(l)(2)(ii) and §98.233(m)(2)(ii) (ii) Or you may use an industry standard practice as described in §98.234(b). (ii) You may use an industry standard practice as described in §98.234(b). Applies active voice

§98.233(l)(3) (3) Estimate ventingemissions using Equation W17A or Equation W-17B of this section. (3) Estimate venting emissions using Equation W-17A (for oil wells) or Equation W-17B (for gas wells) of this section. Clarifying edits

Terms “FR” and “D” of Equations W-17A and W-17B FR = Flow rate in barrels of oil per day for the oil well(s) being tested.

... D = Number of days during the year, the well(s) is tested. FR = Average annual flow rate in barrels of oil per day for the oil well(s) being tested.

... D = Number of days during the calendar year that the Clarifying edits

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change well(s) is tested. §98.233(l)(5) (5) Calculate both CH 4 and CO 2 volumetric and mass emissions from volumetric natural gas emissions using calculations in paragraphs (u) and (v) of this section. (5) Calculate both CH 4 and CO 2 volumetric and mass emissions from natural gas volumetric emissions using calculations in paragraphs (u) and (v) of this section. Clarifying edit

§98.233(l)(6) and §98.233(m)(6) (l)(6) Calculate emissions from well testing to flares as follows: (i) Use the well testing emissions volume and gas composition as determined in paragraphs (l)(1) through (3) of this section.

(m)(6) Calculate emissions from associated natural gas to flares as follows: (i) Use the associated natural gas volume and gas composition as determined in paragraph (m)(1) through (4) of this section. (l)(6) Calculate emissions from well testing if emissions are routed to a flare as specified in paragraphs (l)(6)(i) and (l)(6)(ii) of this section. (i) Use the well testing emissions volume and gas composition as determined in paragraphs (l)(1) through (4) of this section.

(m)(5) Calculate emissions from associated natural gas if emissions are routed to a flare as specified in paragraphs (m)(5)(i) and (m)(5)(ii) of this section. (i) Use the associated natural gas volume and gas composition as determined in paragraph (m)(1) through (m)(4) of this section. Corrects references; §98.233(m)(6) is renumbered to (m)(5)

§98.233(m)(1) (1) ... If GOR from each well is not available, the GOR from a cluster of wells in the same sub-basin category shall be used. (1) ... If GOR from each well is not available, use the GOR from a cluster of wells in the same sub-basin category. Applies active voice

Term “V p,q ” of Equation W-18 V p,q= Volume of oilproduced, for well p in subbasin q, in barrels in the calendar year during which associated gas was vented or flared. V p,q= Volume of oil produced, for well p in sub-basin q, in barrels in the calendar year during time periods in which associated gas was vented or flared. Clarifying edits

§98.233(n) (n) Flare stack emissions

. Calculate CO 2 , CH 4 , and N 2 O emissions from a flare stack as follows: (n) Flare stack emissions

. Calculate CO 2 , CH 4 , and N 2 O emissions from a flare stack as specified in paragraphs (n)(1) through (n)(9) of this section. Clarifying edits

§98.233(n)(1) (1) ...If you do not have a continuous flow measurement device on the flare, you can install a flow measuring device on the flare or use engineering (1) ...If you do not have a continuous flow measurement device on the flare, you can use engineering calculations based on process knowledge, company records, and best Clarifying edit, corrects typo

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change calculations based on process knowledge, company records, and best available data. available data.

§98.233(n)(2) (2) ... you must use the appropriate gas compositions for each stream of hydrocarbons going to the flare as follows: (i) For onshore natural gas production, determine natural gas composition using (u)(2)(i) of this section. (ii) For onshore natural gas processing, when the stream going to flare is natural gas, use the GHG mole percent in feed natural gas for allstreams upstream of the demethanizer or dew point control, and GHG mole percent in facility specific residue gas to transmission pipeline systems for all emissions sourcesdownstream of the demethanizer overhead or dew point control for onshore natural gas processing facilities. For onshore natural gas processing plants that solely fractionate a liquid stream, use the GHG mole percent in feed natural gas liquid for all streams. (2) ... you must use the appropriate gas compositions for each stream of hydrocarbons going to the flare as specified in paragraphs (n)(2)(i) through (n)(2)(iii) of this section. (i) For onshore natural gas production, determine the GHG mole fraction using paragraph (u)(2)(i) of this section. (ii) For onshore natural gas processing, when the stream going to flare is natural gas, use the GHG mole fraction in feed natural gas for all streams upstream of the de-methanizer or dew point control, and GHG mole fraction in facility specific residue gas to transmission pipeline systems for all emissions sourcesdownstream of the demethanizer overhead or dew point control for onshore natural gas processing facilities. For onshore natural gas processing plants that solely fractionate a liquid stream, use the GHG mole fraction in feed natural gas liquid for all streams. Clarifying edits

Terms “V a ”, “X CH4 ”, “X CO2 ”, and “Y j ” ofEquation W-19 and W20 V a= Volume of gas sent to flare in cubic feet, during the

year.

... X CH4 = Mole fraction of CH 4 in gas to the flare. X CO2 = Mole fraction of CO 2 in gas to the flare.... Y

j = Mole fraction of gas hydrocarbon constituents j (such as methane, ethane, propane, butane, and pentanes-plus). V s = Volume of gas sent to flare in standard cubic feet, during the year as determined in paragraph (n)(1) of this section.

... X CH4 = Mole fraction of CH 4 in the feed gas to the flare as determined in paragraph (n)(2) of this section. X CO2 = Mole fraction of CO 2 in the feed gas to the flare as determined in paragraph (n)(2) of this section. Specifies requirements for determining each parameter.

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change

...Y j = Mole fraction of hydrocarbon constituents j (such as methane, ethane,propane, butane, and pentanesplus) in the feed gas to the flare as determined in paragraph (n)(1) of this section. §98.233(n)(7) [Reserved] None Removes reserved requirements and renumbers following paragraphs §98.233(n)(9) (9) If you operate and maintain a CEMS that has both a CO 2 concentration monitor and volumetric flow rate monitor, you must calculate only CO 2 emissions for the flare. ... If a CEMS is used to calculate flare stack emissions, the requirements specified in paragraphs (n)(1) through (n)(7) are not required. If a CO 2 concentration monitor and volumetric flow rate monitor are not available, you may elect to install a CO 2 concentration monitor and a volumetric flow rate monitor that comply with all of the requirements specified for the Tier 4 Calculation Methodology in subpart C of this part (General Stationary Fuel Combustion). (8) If you operate and maintain a CEMS that has both a CO 2 concentration monitor and volumetric flow rate monitor for the combustion gases from the flare, you must calculate only CO 2 emissions for the flare. ...If a CEMS is used to calculate flare stack emissions, the requirements specified in paragraphs (n)(1) through (n)(7) are not required. Renumbers paragraph and removes redundant

text

§98.233(q) Leak detection and leaker emission factors . You must use the methods described in §98.234(a) to conduct leak detection(s) of equipment leaks from all component types listed in §98.232(d)(7), (e)(7), (f)(5), (g)(3), (h)(4), and (i)(1). This paragraph (q) applies to component types in streams with gas content greater than 10 percent CH 4 plus CO 2 by weight. Component types in streams with gas content less than 10 Equipment leak surveys . You must use the methods described in §98.234(a) to conduct leak detection(s) of equipment leaks from all component types listed in §98.232(d)(7), (e)(7), (f)(5), (g)(3), (h)(4), and (i)(1). This paragraph (q) applies to component types in streams with gas content greater than 10 percent CH 4 plus CO 2 by weight. Component types in streams with gas content less than or equal to 10 percent Makes terminology consistent with corresponding reporting section (§98.236(q)); clarifying edits

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change percent CH 4 plus CO 2 by weight do not need to be reported. Tubing systems equal to or less than one half inch diameter are exempt from the requirements of this paragraph (q) and do not need to be reported. If equipment leaks are detected for sources listed in this paragraph (q), calculate equipment leak emissions per component type per reportingfacility using Equations W30A or W-30B of this section for each component type. CH 4 plus CO 2 by weight are exempt from the requirements of this paragraph (q) and do not need to be reported. Tubing systems equal to or less than one half inch diameter are exempt from the requirements of this paragraph (q) and do not need to be reported. For industry segments listed in §98.230(a)(3) through (a)(8), if equipment leaks are detected for component types listed in this paragraph (q), then you must calculate equipment leak emissions per component type per reporting facility using Equations W-30 of this section. For the industry segment listed in §98.230(a)(8), the results from Equation W-30 of this section are used to calculate population emission factors on a meter/regulator run basis using Equation W-31 of this section. §98.233(q)(1) You must select to conduct either one leak detection survey in a calendar year or multiple complete leak detection surveys in a calendar year. The number of leak detection surveys selected must be conducted during the calendar year. You must conduct either one leak detection survey in a calendar year or multiple complete leak detection surveys in a calendar year. The leak detection surveys selected must be conducted during the calendar year. Grammatical corrections

§98.233(q)(3) and (q)(4) ... facilities shall use the appropriate default leaker emission factors listed in Table ... of this subpart for equipment leaks detected from valves, connectors, open ended lines, pressure relief valves, and meters. ... facilities must use the appropriate default total hydrocarbon leaker emission factors for compressor components in gas service and non-compressor components in gas service listed in Table ... of this subpart. Clarifying edits

§98.233(q)(5) and (r)(3) (q)(5) Underground natural gas storage facilities for storage stations shall use the appropriate default leaker emission factors listed in Table W-4 of this subpart for (q)(5) Underground natural gas storage facilities must use the appropriate default total hydrocarbon leaker emission factors for storage stations in gas service listed in Table W-4 Clarifying edits

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change equipment leaks detected from valves, connectors, open ended lines, pressure relief valves, and meters.

(r)(3) Underground natural gas storage facilities for storage wellheads shall use the appropriate default population emission factors listed in Table W-4 of this subpart for equipment leak from connectors, valves, pressure relief valves, and open ended lines. of this subpart.

(r)(3) Underground natural gas storage facilities must use the appropriate default total hydrocarbon population emission factors for storage wellheads in gas service listed in Table W-4 of this subpart.

§98.233(q)(6) and (r)(4) (q)(6) ... shall use the appropriate default leaker emission factors listed in Table W-5 of this subpart for equipment leaks detected from valves, pump seals, connectors, and other.

(r)(4) ... shall use the appropriate default population emission factors listed in Table W-5 of this subpart for equipment leak from vapor recovery

compressors. (q)(6) ... must use the appropriate default methane leaker emission factors for LNG storage components in gas service listed in Table W-5 of this subpart.

(r)(4) ... must use the appropriate default methane population emission factor for LNG storage compressors in gas service listed in Table W-5 of this subpart. Clarifying edits

§98.233(q)(7) and (r)(5) (q)(7) ... shall use the appropriate default leaker emission factors listed in Table W-6 of this subpart for equipment leaks detected from valves, pump seals, connectors, and other.

(r)(5) ... shall use the appropriate default population emission factor listed in Table W-6 of this subpart for equipment leak from vapor recovery

compressors. (q)(7) ... must use the appropriate default methane leaker emission factors for LNG terminals components in LNG service listed in Table W-6 of this subpart.

(r)(5) ... must use the appropriate default methane population emission factor for LNG terminal compressors in gas service listed in Table W-6 of this subpart. Clarifying edits

§98.233(q)(8) Natural gas distribution facilities for above grade transmission-distribution transfer stations, shall use the appropriate default leaker emission factors listed in Natural gas distribution facilities must use Equation W-30 of this section and the default methane leaker emission factors for transmission-distribution Clarifying edits; grammatical correction

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change Table W-7 of this subpart for equipment leaks detected from connectors, block valves, control valves, pressure relief valves, orifice meters, regulators, and open ended lines. Leak detection at natural gas distribution facilities is only required at above grade stations thatqualify as transmissiondistribution transfer stations.Below grade transmissiondistribution transfer stations and all metering-regulating stations that do meet thedefinition of transmissiondistribution transfer stations are not required to perform component leak detection under this section. transfer station components in gas service listed in Table W-7 of this subpart to calculate component emissions from annual equipment leak surveys conducted at above grade transmission-distribution transfer stations. Natural gas distribution facilities are required to perform equipment leak surveys only at above grade stations that qualify as transmission-distribution transfer stations. Below grade transmission-distribution transfer stations and all metering-regulating stations that do not meet the definition of transmission-distribution transfer stations are not required to perform equipment leak surveys under this section. §98.233(q)(8)(i) Natural gas distribution facilities may choose to conduct leak detection at the T-D transfer stations over multiple years, not exceeding a five year period to cover all T-D transfer st ations. If the facility chooses to use the multiple year option then the number of T-D transfer stations that are monitored in each year should be approximately equal across all years in the cycle without monitoring the same station twice during the multiple

year survey. Natural gas distribution facilities may choose to conduct equipment leak surveys at all above grade transmission-distribution transfer stations over multiple years, not exceeding a five year period to cover all above grade transmission-distribution transfer stations. If the facility chooses to use the multiple year option then the number of transmission-distribution transfer stations that are monitored in each year should be approximately equal across all years in the cycle. Clarifying edits

§98.233(r) Population count and emission factors . This paragraph applies to emissions sources listed in §98.232 (c)(21), (f)(5), (g)(3), (h)(4), (i)(2), (i)(3), (i)(4), (i)(5), and (i)(6) on streams with gas content greater than 10 percent CH 4 plus CO 2 by weight. Emissions sources in streams with gas content less than 10 Equipment leaks by population

count . This paragraph applies to emissions sources listed in §98.232 (c)(21), (f)(5), (g)(3), (h)(4), (i)(2), (i)(3), (i)(4), (i)(5), and (i)(6) on streams with gas content greater than 10 percent CH 4 plus CO 2 by weight. Emissions sources in streams with gas content less than or equal to 10 percent CH 4 plus CO 2 by weight are Makes terminology consistent with corresponding reporting section (§98.236(r)); clarifying edits

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change percent CH 4 plus CO 2 by weight do not need to be reported. Tubing systems equal to or less than one half inch diameter are exempt from the requirements of paragraph (r) of this section and do not need to be reported. Calculate emissions from all sources listed in thisparagraph using Equation W31 of this section. exempt from the requirements of this paragraph (q) and do not need to be reported. Tubing systems equal to or less than one half inch diameter are exempt from the requirements of paragraph (r) of this section and do not need to be reported. You must calculate emissions from all emission sources listed in thisparagraph using Equation W32A of this section, except for natural gas distribution facility emission sources listed in §98.232 (i)(3). Natural gas distribution facility emission sources listed in §98.232 (i)(3) must calculate emissions using Equation W-32B and according to paragraph (r)(6) of this section. §98.233(r) Equations Eq. W-31 Eq. W-32A and Eq. W-32B Renumbered; harmonizing change with edits to §98.233(q) §98.233(r)(2) Onshore petroleum and natural gas production facilities shall use the appropriate default population emission factors listed in Table W-1A of this subpart for equipment leaks from valves, connectors, open ended lines, pressure relief valves, pump, flanges, and other. Major... Onshore petroleum and natural gas production facilities must use the appropriate default whole gas population emission factors listed in Table W-1A of this subpart. Major... Clarifying edit

§98.233(r)(6) ... shall use the appropriate emission factors as described in paragraph (r)(6) of this section. ... must use the appropriate methane emission factors as described in paragraph (r)(6) of this section. Clarifying edits

§98.233(r)(6)(i) ... shall use the appropriate default population emission factors listed in Table W-7 ofthis subpart. Below grade TD transfer stations shall use the emission factor for below grade metering-regulating stations. ... must use the appropriate default methane population emission factors listed in Table W-7 of this subpart. Below grade transmission-distribution transfer stations must use the emission factor for below grade metering-regulating stations. Clarifying edits

§98.233(r)(6)(ii) Emissions from all above grade metering-regulating Above grade meteringregulating stations (that are not Harmonizing edits with changes to §98.233(q)

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change stations (including above grade TD transfer stations) shall be calculated by applying the emission factor calculated in Equation W-32 and the total count of meter/regulator runs at allabove grade meteringregulating stations (inclusive of TD transfer stations) to Equation W-31. The facility wide emission factor in Equation W-32 will be calculated by using the total volumetric GHG emissions at standard conditions for all equipment leak sourcescalculated in Equation W30B in paragraph (q)(8) of this section and the count of meter/regulator runs locatedat above grade transmissiondistribution transfer stations that were monitored over the years that constitute one complete cycle as per paragraph (q)(8)(i) of this section. A meter on a regulator run is considered one meter/regulator run. Reporters that do not have above grade T-D transfer stations shall report a countof above grade meteringregulating stations only and do not have to comply with §98.236(c)(16)(xix). above grade transmissiondistribution transfer stations) must use the meter/regulator run population emission factor calculated in Equation W-31. Natural gas distribution facilities that do not haveabove grade transmissiondistribution transfer stations are not required to calculate emissions for above grade metering-regulating stations.

§98.233(s)(2) Offshore production facilities that are not under BOEMRE jurisdiction shall use monitoring methods and calculation methodologies published by BOEMRE referenced in 30 CFR 250.302 through 304 to calculate and report emissions (GOADS). Offshore production facilities that are not under BOEMRE jurisdiction shall use the most recent monitoring methods and calculation methods published by BOEMRE referenced in 30 CFR 250.302 through 304 to calculate and report annual emissions (GOADS). Clarifying edits

§98.233(s)(2)(i) For any calendar year that does not overlap with the most recent BOEMRE emissions study publication, For any calendar year that does not overlap with the most recent BOEMRE emissions study publication, you may Clarifying edits

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change report the most recent reported emissions data with emissions adjusted... report the most recently reported emissions data submitted to demonstrate compliance with this subpart of part 98, with emissions adjusted ... §98.233(s)(3) ... shall once in every 4 years use the most recent BOEMRE data collection and emissions estimation methods to report emission from the facility sources. ... shall once in every 4 years use the most recent BOEMRE data collection and emissions estimation methods to estimate emissions. These emission estimates would be used to report emissions from the facility sources as required in paragraph (1)(i) of this section. Clarifying edits

§98.233(s)(4) ... shall use the most recent BOEMRE data collection and emissions estimation methods published by BOEMRE referenced in 30 CFR 250.302 through 304 to calculate and report emissions (GOADS) to report emissions. ... must use the most recent BOEMRE data collection and emissions estimation methods published by BOEMRE referenced in 30 CFR 250.302 through 304 to calculate and report emissions. Applies active language and corrects typographical error

§98.233(t) (t) Volumetric emissions.

... (t) GHG Volumetric emissions using actual conditions.

... Clarifying edits

§98.233(u) (u) GHG volumetric emissions. Calculate GHG volumetric emissions at standard conditions as specified in paragraphs (u)(1) and (2) of this section, with mole fraction of GHGs in the natural gas determined by engineering estimate based on best available data unless otherwise specified. (u) GHG volumetric emissions at standard conditions. Calculate GHG volumetric emissions at standard conditions as specified in paragraphs (u)(1) and (2) of this section. Clarifying edits

§98.233(u)(2)(iii), (v), and (vi) ... You may use a default 95 percent methane and 1 percent carbon dioxide fraction for GHG mole fraction in natural gas. ... You may use either a default 95 percent methane and 1 percent carbon dioxide fraction for GHG mole fraction in natural gas or site specific engineering estimates based on best available data. Clarifying edits

§98.233(vii) ... You may use a default 95 percent methane and 1 percent carbon dioxide fraction for GHG mole fraction in natural gas. ...You may use a default 95 percent methane and 1 percent carbon dioxide fraction for GHG mole fraction in natural gas or site specific engineering estimates based on best available data. Clarifying edits

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change §98.233(w) (w) ... Calculate CO 2 pump blowdown emissions as follows: (1) Calculate the total volume in cubic feet ... (3) Calculate the total annual venting emissions using Equation W-37 of this section: (w) ... Calculate CO 2 pump blowdown emissions from each EOR injection pump system as follows: (1) Calculate the total injection pump system volume in cubic feet ... (3) Calculate the total annual CO 2 emissions from each EOR injection pump system using Equation W-37 of this section: Clarifying edits

Terms “Mass CO2 ”, “N”, and “V

v ” of Equation W-37 Mass CO2 = Annual EOR injection gas venting emissions in metric tons from blowdowns. N = Number of blowdowns for the equipment in the calendar year. V v = Total volume in cubic feet of blowdown equipment chambers (including pipelines, manifolds and vessels) between isolation valves. Mass CO2 = Annual EOR injection pump system emissions in metric tons from blowdowns. N = Number of blowdowns for the EOR injection pump system in the calendar year. V v = Total volume in cubic feet of EOR injection pump system chambers (including pipelines, manifolds and vessels) between isolation valves. Clarifies terminology

§98.233(x), (x)(1), and term “S hl ” of Equation W-38 (§98.233(x)(2)) (x) ... Calculate dissolved CO 2 in hydrocarbon liquids produced through EOR operations as follows: (1) ... Annual samples must be taken according to methods set forth in §98.234(b)... (2)... S hl = Amount of CO 2 retained in hydrocarbon liquids in metric tons per barrel, under standard conditions. (x) ... Calculate CO 2 emissions downstream of the storage tank from dissolved CO 2 in hydrocarbon liquids produced through EOR operations as follows: (1) ... Annual samples of hydrocarbon liquids downstream of the storage tank must be taken according to methods set forth in §98.234(b) ... (2)... S hl = Amount of CO 2 retained in hydrocarbon liquids downstream of the storage tank, in metric tons per barrel, under standard conditions. Clarifying edits

§98.233(z)(1)(i) and (ii) All part 98 rule references in paragraphs (i) and (ii) Added § symbol (e.g., “for that tier listed in §98.33”) Corrects typographical

error Term “V a ” of Equations W-39A and W-39B V a= Volume of gas sent to combustion unit in cubic feet, during the year. V a= Volume of gas sent to combustion unit in actual cubic feet, during the year. Clarifying edit

Terms “Y CO2 ”, “Y j ” and “Y CH4 ” of Equations W-39A and Concentration of... Mole fr action of... Clarifying edit

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change

W-39B Term “HHV” of Equation W-40 HHV = For the higher heating value for field gas or process vent gas, use 1.235 × 10 − 3 mmBtu/scf for HHV. HHV = Higher heating value of fuel, mmBtu/unit of fuel (in units consistent with the fuel quantity combusted). For the higher heating value for field gas or process vent gas, use 1.235 × 10 − 3 mmBtu/scf for HHV. Clarifying edit

§98.234(a) You must use any of the methods described as follows in this paragraph to conduct leak detection(s) ofequipment leaks and throughvalve leakage from all source types listed in §98.233(k), (o), (p) and (q) that occur during a calendar year, except as provided in paragraph (a)(4) of this section. You must use any of the methods described as follows in this paragraph to conduct leak detection(s) of equipment leaks and through-valve leakage from all source types listed in §98.233(k), (o), (p) and (q) that occur during a calendar year. Corrects reference error

§98.234(d)(1) (1) A technician following manufacturer instructions shall conduct measurements, including equipment manufacturer operating procedures and measurement methodologies relevant to using a high volume sampler... (1) A technician following manufacturer instructions shall conduct measurements, including equipment manufacturer operating procedures and measurement methods relevant to using a high volume sampler... Harmonizing edit

§98.234(h) None (h) For well venting for liquids unloading, if a monitoring period other than the full calendar year is used to determine the cumulative amount of time in hours of venting for each well (the term “T p ” in Equation W-7a and W7b of §98.233) or the number of unloading events per well (the term “V p ” in Equations W-8 and W-9 of §98.233), then the monitoring period must begin before February 1 of the reporting year and must not end before December 1 of the reporting year. The end of one monitoring period must immediately precede the start of the next monitoring period for the next reporting year. All Harmonizing edit with changes to §98.233(f).

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change production days must be monitored and all venting accounted for. §98.238 Component means each metal to metal joint or seal of non-welded connection separated by a compression gasket, screwed thread (with or without thread sealing compound), metal to metal compression, or fluid barrier through which natural gas or liquid can escape to the atmosphere.

Equipment leak means those emissions which could not reasonably pass through a stack, chimney, vent, or other functionally-equivalent opening.

Equipment leak detection means the process of identifying emissions from equipment, components, and other point sources. None (these definitions removed in amendments) Harmonizing edits with changes to §98.233(q) and (r)

§98.238 Compressor source means any type of vent or valve (e.g. wet seal, blowdown valve, isolation valve, or rod packing) on a reciprocating or centrifugal compressor.

Manifolded group of

compressor sources means a collection of any combination of manifolded group of compressor sources (as defined in this section) for centrifugal or reciprocating compressors that are manifolded to a common

vent.

Meter/regulator run means a series of components used in regulating pressure or metering natural gas flow or both. Compressor source means any type of vent or valve (i.e., wet seal, blowdown valve, isolation valve, or rod packing) on a centrifugal or reciprocating compressor.

Manifolded group of

compressor sources means a collection of any combination of manifolded compressor sources (as defined in this section) that are manifolded to

a common vent.

Meter/regulator run means a series of components used in regulating pressure or metering natural gas flow or both. At least one meter, at least on regulator, or any combination of both on a single run of piping is considered one meter/regulator run. Grammatical revisions; harmonizing edits

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Table 1. Proposed Minor Technical Corrections

Rule Citation Current Text Proposed Revised Text Reason for Proposed Change Sub-basin category, for onshore natural gas production, means ... Oil, high permeability gas, shale gas, coal seam, or other tight reservoir rock... Wells that produce from high permeability gas, shale gas, coal seam, or other tight reservoir rock are considered gas wells ... All wells that produce hydrocarbon liquids and do not meet the definition of a gas well in this sub-basin category definition are considered to be in the oil formation. All emission sources that handle condensate from gas wells in high permeability gas, shale gas, or tight reservoir rock formations are considered to be in the formation that the gas well belongs to and not in the oil formation. Sub-basin category, for onshore natural gas production, means ...Oil, high permeability gas, shale gas, coal seam, or other tight gas reservoir rock... Wells that produce only from high permeability gas, shale gas, coal seam, or other tight gas reservoir rock are considered gas wells ... All wells that produce hydrocarbon liquids (with or without gas) and do not meet the definition of a gas well in this sub-basin category definition are considered to be in the oil formation. All emission sources that handle condensate from gas wells in high permeability gas, shale gas, or tight gas reservoir rock formations are considered to be in the formation that the gas well belongs to and not in the oil formation.