Page 1 of 27
**Subpart X —**  **Petrochemical Production**
(a) The petrochemical production source category consists of all processes that produce acrylonitrile, carbon black, ethylene, ethylene dichloride, ethylene oxide, or methanol, except as specified in paragraphs (b) through (g) of this section. The source category includes processes that produce the petrochemical as an intermediate in the on

- site production of othe r chemicals as well as processes that produce the petrochemical as an end product for sale or shipment off site. § 98.240 Definition of the source category.

(b) A process that produces a petrochemical as a byproduct is not part of the petrochemical production source category. (c) A facility that mak es methanol, hydrogen, and/or ammonia from synthesis gas is part of the petrochemical source category if the annual mass of methanol produced exceeds the individual annual mass production levels of both hydrogen recovered as product and ammonia. The facili ty is part of subpart P of this part (Hydrogen Production) if the annual mass of hydrogen recovered as product exceeds the individual annual mass production levels of both methanol and ammonia. The facility is part of subpart G of this part (Ammonia Manufa cturing) if the annual mass of ammonia produced exceeds the individual annual mass production levels of both hydrogen recovered as product and methanol.Page 2 of 27 (d) A direct chlorination process that is operated independently of an oxychlorination process to produ ce ethylene dichloride is not part of the petrochemical production source category. (e) A process that produces bone black is not part of the petrochemical source category. (f) A process that produces a petrochemical from bio

- based feedstock is not part of the petrochemical production source category. (g) A process that solely distills or recycles waste solvent that contains a petrochemical is not part of the petrochemical production source category.

You must report GHG emissio ns under this subpart if your facility contains a petrochemical process as specified in §98.240, and the facility meets the requirements of either §98.2(a)(1) or (2). § 98.241 Reporting threshold.

You must report the information in paragraphs (a) through (c) of this section: § 98.242 GHGs to report.

(a) CO 2 CH 4 , and N 2 O process emissions from each petrochemical process unit. Process emissions include CO 2 generated by reaction in the process and by combustion of process off

- gas in stationary combustion units and flares.Page 3 of 27 (1) If you comply with §98.243(b) or (d), report under this subpart the calculated CO 2 , CH 4 , and N 2 O emissions for each stationary combustion source and flare that burns any amount of petrochemical process off

- gas. If you comply with §98.243(b), also report under this subp art the measured CO 2

(2) If you comply with §98.243(c), report under this subpart the calculated CO emission s from process vents routed to stacks that are not associated with stationary combustion units.

2

(b) CO emission s for each petrochemical process unit.

2 , CH 4 , and N 2

(1) If you comply with §98.243(b) or (d), report these emissions from stationary combustion units that are associated with petrochemical process units and burn only supplemental fuel under subpart C of this part (General Stationary Fuel Combustion Sources) by following the requirements of subpart C. O combustion emissions from stationary combustion units.

(2) If you comply with §98.243(c), report CO 2 , CH 4 , and N 2 O combustion emissions under subpart C of this part (General Stationary Fuel Com bustion Sources) by following the requirements of subpart C for all fuels, except emissions from burning petrochemical process off

- gas in any combustion unit are not to be reported under subpart C of this part. only for the combustion of supplemental fuel. Determine the applicable TierPage 4 of 27 in subpart C of this part (General Stationary Fuel Combustion Sources) based on the maximum rated heat input capacity of the stationary combustion source. (c) CO 2 captured. You must report the mass of CO 2 captured under, subpart PP of this part (Suppliers of Carbon Dioxide ( CO 2 ) by following the requirements of subpart PP.

(a) If you route all process vent emissions and emissions from combustion of process off

- gas to one or more stacks a nd use CEMS on each stack to measure CO § 98.243 Calculating GHG emissions.

2

(b) emission s (except flare stacks), then you must determine process

- based GHG emissions in accordance with paragraph (b) of this section. Otherwise, determine process

- based GHG emissions in accordance with the procedur es specified in paragraph (c) or (d) of this section. Continuous emission monitoring system (CEMS)

(1)Determine CO . Route all process vent emissions and emissions from stationary combustion units that burn any amount of process off

- gas to one or more stacks and determ ine GHG emissions as specified in paragraphs (b)(1) through (3) of this section.

2

(2) For each stack (except flare stacks) that includes emissions from combustion of petrochemical process off

- gas, emission s from each stack (except flare stacks) according to the Tier 4 Calculation Methodology requirements in subpart C of this part.Page 5 of 27
calculate CH 4 and N 2

(3) For each flare, calculate CO 0 emissions in accordance with subpart C of this part (use the Tier 3 methodology Equation C

- 10 and the “ fuel
gas ” , emission factors for “Petroleum” in Table C

– 2 of subpart C of this part )
. , and either the default high heat value for fuel gas in Table C

– 1 of subpart C of this part or a calculated HHV, as allowed in Equation C

– 8 of subpart C of this part).

2 , CH 4 , and N 2

(c) O emissions using the methodology specified in §98.253(b)(1) through (b)(3). Mass balance for each petrochemical process unit
. Calculate the emissions of CO 2

(1) For each gaseous and liquid feedstock and product, measure the volume or mass used or produced each calendar month with a flow meter by following the procedures specified in §98.244(b)(2). A lternatively, for liquids, you may calculate the volume used or collected in each month based on measurements of the liquid level in a storage tank at least once per month (and just prior to each change in direction of the level of the liquid) following th e procedures specified in §98.244(b)(3). Fuels used for combustion purposes are not considered to be feedstocks. from each process unit, for each calendar month as d escribed in paragraphs (c)(1) through (c)(5) of this section.Page 6 of 27 (2) For each solid feedstock and product, measure the mass used or produced each calendar month by following the procedures specified in §98.24 4(b)(1). (3) Collect a sample of each feedstock and product at least once per month and determine the carbon content of each sample according to the procedures of §98.244(b)(4). If multiple valid carbon content measurements are made during the monthly

meas urement period, average them arithmetically. However, if a particular liquid or solid feedstock is delivered in lots, and if multiple deliveries of the same feedstock are received from the same supply source in a given calendar month, only one representati ve sample is required. Alternatively, you may use the results of analyses conducted by a fuel or feedstock supplier, or product customer, provided the sampling and analysis is conducted at least once per month using any of the procedures specified in §98.2 44(b)(4). (4) If you determine that the monthly average concentration of a specific compound in a feedstock or product is greater than 99.5 percent by volume ( or mass for liquids and solids) , then as an alternative to the sampling and analysis specified in paragraph (c)(3) of this section, you may determine carbon content in accordance with paragraphs (c)(4)(i) through (iii) of this section.Page 7 of 27 (i)C c alculate the carbon content assuming 100 percent of that feedstock or product is the specific compound
. during periods of normal operation. You must m (ii)M aintain records of any determination made in accordance with this paragraph (c)(4) along with all supporting data, calculations, and other information. This alternative may not be used for products durin g periods of operation when off

specification product is produced. You must (iii)R r eevaluate determinations made under this paragraph (c)(4) after any process change that affects the feedstock or product composition. You must k K eep records of the process change and the corresponding composition determinations. If the feedstock or product composition changes so that the average monthly concentration falls below 99.5 percent, you are no longer permitted to use this alternative method. (5) Calculate the CO 2

(i) m ass emissions for each petrochemical process unit using Equations X

– 1 through X

– 4 of this section. Gaseous feedstocks and products
. Use Equation X

– 1 of this section to calculate the net annual carbon input or output from gaseous feedstocks and products . Note that the result will be a negative value if there are no gaseous feedstocks in the process but there are gaseous products.Page 8 of 27
Where:
C g = Annual net contribution to calculated emissions from carbon (C) in gaseous materials , including streams containi ng CO 2

(F recovered for sale or use in another process ( kilograms/year, kg/yr).
gf ) i,n = Volume or mass of gaseous feedstock i introduced in month “n” ( standard cubic feet, scf or kg ). If you measure mass, the term (MW f ) i (CC /MVC is replaced with “1”.
gf ) i,n

(MW = Average carbon content of the gaseous feedstock i for month “n” (kg C per kg of feedstock).

f ) i ,n
MVC = Molar volume conversion factor (849.5 scf per kg

- mole at 68 °F and 14.7 pounds per square inch absolute or 836.6 scf/kg

- mole at 60 °F and 14.7 pounds per square inch absolute). = Molecular weight of gaseous feedstock i in month “n” (kg/kg

- mole).

(P gp ) i,n = Volume or mass of gaseous product i produced in month “n” (scf or kg ). If you measure mass, the term (MW p ) i (CC /MVC is replaced with “1”.

gp ) i,n = Average carbon content of gaseous product i, including streams containing CO 2

(MW recovered for sale or use in another process, for month “n” (kg C per kg of product).

p ) I i = j = Number of fee dstocks. Molecular weight of gaseous product i in month “n” (kg/kg

- mole).

k = Number of products. (ii) Liquid feedstocks and products
. Use Equation X

– 2 of this section to calculate the net carbon input or output from liquid feedstocks and products. Note that the result will be a negative value if there are no liquid feedstocks in the process but there are liquid products.Page 9 of 27

Where:
C l =

(F Annual net contribution to calculated emissions from carbon in liquid materials, including liquid organic wastes (kg/yr).

lf ) i,n = (CC Volume or mass of liquid feedstock i introduced in month “n” (gallons or kg).

lf ) i,n =

(P Average carbon content of liquid feedstock i for month “n” (kg C per gallon or kg of feedstock).
lp ) i,n = (CC Volume or mass of liquid product i produced in month “n” (gallons or kg).
lp ) i,n
j = Number of feedstocks. = Average carbon content of liquid product i, including organic liquid wastes, for month “n” (kg C per gallon or kg of product).

k = Number of products. (iii) Solid feedstocks and products
. Use Equation X

– 3 of this section to calculate the net annual carbon input or output from solid feedstocks and products. Note that the result will be a negative value if there are no solid feedstocks in the process but there are solid products.

Where:

C s
(F = Annual net contribution to calculated emissions from carbon in solid materials (kg/yr).

sf ) i,n = Mass of solid feedstock i introduced in month “n” (kg).Page 10 of 27
(CC sf ) i,n (P = Average carbon content of solid feedstock i for month “n” (kg C per kg of feedstock).

sp ) i,n (CC = Mass of solid product i produced in month “n” (kg).

sp ) i,n j = Number of feedstocks. = Average carbon content of solid product i in month “n” (kg C per kg of product).

k = Number of products. (iv) Annual emissions
. Use the results from Equations X

– 1 through X

– 3 of this section, as applicable, in Equatio n X

– 4 of this section to calculate annual CO 2 emission s.

Where:
CO 2 = Annual CO 2

0.001 = Conversion factor from kg to metric tons. mass emissions from process operations and process off

- gas combustion (metric tons/year).

44 = Molecular weight of CO 2 12 = Atomic weight of carbon (C) (kg/kg

- mole). (kg/kg

- mole).
(d) Optional combustion methodology for ethylene production
processes

(1) Except as specified in paragraphs (d)(2) and (d)(5) of this section, calculate CO . For each ethylene production process, calculate GHG emissions from combustion units that burn fuel that contains any off

- gas from the ethylene process as specified in paragraphs (d)(1) through (d)(5) of this section.

2 emission s using the Tier 3 or Tier 4 methodology in subpart C of this part.Page 11 of 27 (2) You may use either Equation C

– 1 or Equation C

– 2a in subpart C of this part to calculate CO 2

(i) The annual average flow rate of fuel gas (that contains ethylene process off

- gas) in the fuel gas line to the combustion unit, prior to any split to individual burners or ports, does not exceed 345 standard cubic feet per minute at 60 °F and 14.7 pounds per sq uare inch absolute, and a flow meter is not installed at any point in the line supplying fuel gas or an upstream common pipe. Calculate the annual average flow rate using company records assuming total flow is evenly distributed over 525,600 minutes per ye ar. emission s from combustion of any ethylene process off

- gas streams that meet either of the conditions in paragraphs (d)(2)(i) or (d)(2)(ii) of this section (for any default values in the calculation, use the defaults for fuel gas in Table C

– 1 of subpart C of this part). Follow the otherwise applicable procedures in subpart C to calculate emissions from combustion of all other fuels in the combustion unit.

(ii) The combustion unit has a maximum rated heat input capacity of less than 30 mmBtu/hr, and a flow meter is not installed at any point in the line supplying fuel gas (that contains ethylene process off

- gas) or an upstream common pipe. (3) Except as specified in paragraph (d)(5) of this section, calculate CH 4 and N 2 O emissions using the applicablePage 12 of 27 procedures in §98.33(c) for the same tier methodology that you used for calculating CO 2 (i) For all gaseous fuels that contain ethylene process off

- gas, use the emission factors for “Fuel Gas” “Petroleum” in Table C

– 2 of subpart C of this part (General Stationary Fuel Combustion Sources). emission s.

(ii) For Tier 3, use either the default high heat valu e for fuel gas in Table C

– 1 of subpart C of this part or a calculated HHV, as allowed in Equation C

– 8 of subpart C of this part. (4) You are not required to use the same Tier for each stationary combustion unit that burns ethylene process off

- gas. (5) For each flare, calculate CO 2 , CH 4 , and N 2 O emissions using the methodology specified in §§98.253(b)(1) through (b)(3).

(a) If you use CEMS to determine emissions from process vents, you must comply with the procedur es specified in §98.34(c). § 98.244 Monitoring and QA/QC requirements.

(b) If you use the mass balance methodology in §98.243(c), use the procedures specified in paragraphs (b)(1) through (b)(4) of this section to determine feedstock and product flows and carbon contents. (1) Operate, maintain, and calibrate belt scales or other weighing devices as described in Specifications, Tolerances, andPage 13 of 27 Other Technical Requirements for Weighing and Measuring Devices NIST Handbook 44 (2009) (incorporated by reference, see §98.7), or follow procedures specified b y the measurement device manufacturer. You must recalibrate each weighing device according to one of the following frequencies. You may recalibrate either at the minimum frequency specified by the manufacturer or biennially ( i.e. (2 ) Operate and maintain all flow meters used for gas and liquid feedstocks and products according to the manufacturer's recommended procedures. You must calibrate each of these flow meters as specified in paragraphs (b)(2)(i) and (b)(2)(ii) of this section: , once every two years).

(i) You may use either the calibration methods specified by the flow meter manufacturer or an industry consensus standard method. Each flow meter must meet the applicable accuracy specification in §98.3(i), except as otherwise specified in §§98.3(i)(4) th rough (i)(6). (ii) You must recalibrate each flow meter according to one of the following frequencies. You may recalibrate at the minimum frequency specified by the manufacturer, biennially (every two years), or at the interval specified by the industry co nsensus standard practice used. (3) You must perform tank level measurements (if used to determine feedstock or product flows) according to one of thePage 14 of 27 following methods. You may use any standard method published by

a consensus - based standards organization or you may use an industry standard practice. Consensus

- based standards organizations include, but are not limited to, the following: ASTM International (100 Barr Harbor Drive, P.O. Box CB700, West Conshohocken, Pennsylvania 19428

– B2959, (800) 262

– 1373, h ttp://www.astm.org ) , the American National Standards Institute (ANSI, 1819 L Street, NW., 6th Floor, Washington, DC 20036, (202) 293

– 8020, http://www.ansi.org ) , the American Gas Association (AGA, 400 North Capitol Street, NW., 4th Floor, Washington, DC 200 01, (202) 824

– 7000, http://www.aga.org ) , the American Society of Mechanical Engineers (ASME, Three Park Avenue, New York, NY 10016

– 5990, (800) 843

– 2763, http://www.asme.org ) , the American Petroleum Institute (API, 1220 L Street, NW., Washington, DC 20005

– 4070, (202) 682

– 8000, http://www.api.org ,) and the North American Energy Standards Board (NAESB, 801 Travis Street, Suite 1675, Houston, TX 77002, (713) 356

– 0060, http://www. api.org (4) Beginning January 1, 2010, use any applicable methods specified in paragraphs (b)(4)(i) through (b)(4)(xiv) of this section to determine the carbon content or composition of feedstocks and products and the average molecular weight of
gaseous feedstocks and products. Calibrate instruments in accordance with paragraphs (b)(4)(i) through (b)(4)(xvi), as )
.Page 15 of 27 applicable. For coal used as a feedstock, the samples for carbon content determinations shall be taken at a location that is representative of th e coal feedstock used during the corresponding monthly period. For carbon black products, samples shall be taken of each grade or type of product produced during the monthly period. Samples of coal feedstock or carbon black product for carbon content deter minations may be either grab samples collected and analyzed monthly or a composite of samples collected more frequently and analyzed monthly. Analyses conducted in accordance with methods specified in paragraphs (b)(4)(i) through (b)(4)(xv) of this section may be performed by the owner or operator, by an independent laboratory, or by the supplier of a feedstock , or by a product customer
. (i) ASTM D1945

– 03, Standard Test Method for Analysis of Natural Gas by Gas Chromatography (incorporated by reference,

see (ii) ASTM D6060

– 96 (Reapproved 2001) Standard Practice for Sampling of Process Vents With a Portable Gas Chromatograph (incorporated by reference, §98.7).

see

(iii) ASTM D2505

– 88(Reapproved 2004)e1 Standard Test Method for Ethylene, Other Hydrocar bons, and Carbon Dioxide in High

Purity Ethylene by Gas Chromatography (incorporated by reference, §98.7).

see §98.7).Page 16 of 27 (iv) ASTM UOP539

– 97 Refinery Gas Analysis by Gas Chromatography (incorporated by reference, see (v) ASTM D3176

– 89 (Reapproved 2002) Stand ard Practice Method for Ultimate Analysis of Coal and Coke (incorporated by reference, §98.7).

see (vi) ASTM D5291

– 02 (Reapproved 2007) Standard Test Methods for Instrumental Determination of Carbon, Hydrogen, and Nitrogen in Petroleum Products and Lubrica nts (incorporated by reference, §98.7).

see (vii) ASTM D5373

– 08 Standard Test Methods for Instrumental Determination of Carbon, Hydrogen, and Nitrogen in Laboratory Samples of Coal (incorporated by reference, §98.7).

see

(viii) Method 8015C, Method 8021B, Method 8031, or Method 9060A (all incorporated by reference, §98.7).

see (x) Performance Specification 9 in 40 CFR part 60, appendix B for continuous online gas analyzers. The 7

- day calibration error test period must be completed prior to the effective dat e of the rule. §98.7).

(xi) ASTM D2593

– 93 (Reapproved 2009) Standard Test Method for Butadiene Purity and Hydrocarbon Impurities by Gas Chromatography (incorporated by reference, see (xii) ASTM D7633

– 10 Standard Test Method for Carbon Black

— Carbon Content (incorporated by reference, §98.7).

see §98.7).Page 17 of 27 (xiii) The results of chromatographic analysis of a feedstock or product, provided that the gas chromatograph is operated, maintained, and cali brated according to the manufacturer's instructions. (xiv) The carbon content results of mass spectrometer analysis of a feedstock or product, provided that the mass spectrometer is operated, maintained, and calibrated according to the manufacturer's instr uctions. (xv) Beginning on January 1, 2010, the methods specified in paragraphs (b)(4)(xv)(A) and (B) of this section may be used as alternatives for the methods specified in paragraphs (b)(4)(i) through (b)(4)(xiv) of this section.
(A) An industry standar d practice or a method published by

a consensus - based standards organization if such a method exists for carbon black feedstock oils and carbon black products. Consensus

- based standards organizations include, but are not limited to, the following: ASTM International (100 Barr Harbor Drive, P.O. Box CB700, West Conshohocken, Pennsylvania 19428

- B2959, (800) 262

- 1373, http://www.astm.org), the American National Stan dards Institute (ANSI, 1819 L Street, NW., 6th floor, Washington, DC 20036, (202) 293

- 8020, http://www.ansi.org ), the American Gas Association (AGA, 400 North Capitol Street, NW., 4th Floor, Washington, DC 20001, (202) 824

- 7000,Page 18 of 27 http://www.aga.org ), the American Society of Mechanical Engineers (ASME, Three Park Avenue, New York, NY 10016

- 5990, (800) 843

- 2763, http://www.asme.org ), the American Petroleum Institute (API, 1220 L Street, NW., Washington, DC 20005

- 4070, (202) 682

- 8000, http://www.api.org ), a nd the North American Energy Standards Board (NAESB, 801 Travis Street, Suite 1675, Houston, TX 77002, (713) 356

- 0060, http://www.naesb.org ). The method(s) used shall be documented in the M m onitoring P p lan required under § 98.3(g)(5).

(B) Modifications of existing analytical methods or other methods that are applicable to your process provided that the methods listed in paragraphs (b)(4)(i) through (b)(4)(xiv) of this section are not appropriate because the relevant compounds cannot be detected, the qualit y control requirements are not technically feasible, or use of the method would be unsafe. (c) If you comply with §98.243(b) or (d), conduct monitoring and QA/QC for flares in accordance with §98.254.

For missing feedstock and flow rates, product flow rates, and carbon contents, use the same procedures as for missing fuel usage as specified in § 98.35(b)(2). For missing feedstock and product flow rates and carbon contents and missing molecular § 98.245 Procedures for estimating missing data.Page 19 of 27 weights f or gaseous feedstocks and products, use the same procedures as for missing carbon contents and missing molecular weights for fuels as specified in §98.35 (b)(1)
. For missing flare data, follow the procedures in § 98.255(b) and (c).

In addition to the information required by §98.3(c), each annual report must contain the information specified in paragraphs (a), (b), or (c) of this section, as appropriate for each process unit. § 98.246 Data reporting requirements.

(a) If you use the mass balance methodology i n §98.243(c), you must report the information specified in paragraphs (a)(1) through (a)(11) of this section for each type of petrochemical produced, reported by process unit. (1) The petrochemical process unit ID number or other appropriate descriptor. (2 ) The type of petrochemical produced, names of other products, and names of carbon

- containing feedstocks. (3) Annual CO 2

(4) Each of the monthly volume, mass, and carbon content values used in Equati ons X

– 1 through X

– 3 of this subpart ( emission s calculated using Equation X

– 4 of this subpart.

i.e. , the directly measured values, substitute values, or the calculated values based on other measured data such as tank levels or gas composition) and the molecular weights for gaseousPage 20 of 27 feedstocks and products used in Equation X

– 1 of this subpart, and the temperature (in °F) at which the gaseous feedstock and product volumes used in Equation X

– 1 of this subpart were determined. Indicate whether you used the alternative to sampling and analysis specified in §98.243(c)(4)
. (5) Annual quantity of each type of petrochemical produced from each process unit (metric tons). (6) For each feedstock and product, provide the information specified in paragraphs (a)(6)(i) through (a)(6)(iii) of this section. (i) Name of each method li sted in §98.244 used to determine carbon content or molecular weight in accordance with 98.244(b)(4); (ii)D escription of each type of device (e.g., flow meter, weighing device) used to determine flow or mass in accordance 98.244(b)(1) through (3). (iii)Ide ntification of each method (i.e., method number, title, or other description) used to determine flow or mass in accordance with 98.244( b)(1) through (3). a measured parameter (or description of manufacturer's recommended method). (7) [Reserved] (8) Identif ication of each combustion unit that burned both process off

- gas and supplemental fuel , including combustion units that are not part of the petrochemical process unit
.Page 21 of 27 (9) If you comply with the alternative to sampling and analysis specified in §98.243(c)( 4), the number of days amount of time during which off

- specification product was produced, the volume or mass of off

- specification product produced, and if applicable, the date of any process change that reduced the composition to less than 99.5 percent. (10) You may elect to report the flow and carbon content of wastewater, and you may elect to report the annual mass of carbon released in fugitive emissions and in process vents that are not controlled with a combustion device. These values may be estimate d based on engineering analyses. These values are not to be used in the mass balance calculation. (11) If you determine carbon content or composition of a feedstock or product using a method under §98.244(b)(4)(xv)(B), report the information listed in para graphs (a)(11)(i) through (a)(11)( iv iii ) of this section. Include the information in paragraph (a)(11)(i) of this section in each annual report. Include the information in paragraphs (a)(11)(ii) and (a)(11)(iii) of this section only in the first applicable annual report, and provide any changes to this information in subsequent annual reports. (i) Name or title of the analytical method. (ii) A copy of the method. If the method is a modification of a method listed in §§98.244(b)(4)(i) through (xiv), you mayPage 22 of 27 provide a copy of only the sections that differ from the listed method. (iii) An explanation of why an alternative to the methods listed in §§98.244(b)(4)(i) through (xii) is needed. (b) If you measure emissions in accordance with §98.243(b), then you must report the information listed in paragraphs (b)(1) through (b)(8) of this section. (1) The petrochemical process unit ID or other appropriate descriptor, and the type of petrochemical produced. (2) For CEMS used on stacks that include emissions from for
st ationary combustion units that burn any amount of off

- gas from the petrochemical process , report the relevant information required under §98.36 (c)(2) and (e)(2)(vi) for the Tier 4 calculation methodology. Section s § 98.36( b c )( 9 2 )( i ii) and (c)(2)(ix) do does not apply for the purposes of this subpart. (3) For CEMS used on stacks that do not include emissions from are not used for stationary combustion units, report the information required under § 98.36(b)(6), (b)(7), and §98.36(e)(2)(vi). (4) The CO 2 emission s from each stack and the combined CO 2 emission s from all stacks (except flare stacks) that handle process vent emissions and emissions from stationary combustion units that burn process off

- gas for the petrochemical process unit. For each stationary combu stion unit (or group ofPage 23 of 27 combustion units monitored with a single CO 2 CEMS monitoring location that meets the conditions in paragraph (b)(2) or (3) of this section , ) that burns petrochemical process off

- gas, provide an estimate based on engineering judgmen t of the fraction of the total CO 2

(5) For stationary combustion units that burn process off

gas from the petrochemical process unit, report the information related to CH emissions that is attributable to combustion of off

- gas from the petrochemical process unit.

4 and N 2

(i) The each CEMS monitoring locatio n th e at meet s the conditions in paragraph (b)(2) of this section, report the CH O emissions as specified in paragraphs (b)(5)(i) through (b)(5)(iv) of this section.

4 and N 2 O emissions from each stack that is monitored with a CO 2 CEMS, expressed in metric tons of each gas and in metric tons of CO 2 e . For each CEMS monitoring location , stack provide an estimate based on engineering judgment of the fraction of the total CH 4 and N 2

(i) [Reserved] O emissions that is attributable to combustion of off

- gas from the petrochemical process unit.

(ii) [Reserved] The combined CH 4 and N 2 O emissions from a ll stationary combustion units, expressed in metric tons of each gas and in metric tons of CO 2 (iii) [Reserved] The quantity of each type of fuel used in Equation C

– 8 in §98.33(c) for each stationary combustion unit or e.Page 24 of 27 group of units (as applicable) duri ng the reporting year, expressed in short tons for solid fuels, gallons for liquid fuels, and scf for gaseous fuels. (iv) [Reserved] The HHV (either default or annual average from measured data) used in Equation C

– 8 in §98.33(c) for each stationary combustion unit or group of combustion units (as applicable). (6) [Reserved] ID or other appropriate descriptor of each stationary combustion unit that burns process off

- gas. (7) Information listed in §98.256(e) of subpart Y of this part for each flare tha t burns process off

- gas. (8) Annual quantity of each type of petrochemical produced from each process unit (metric tons). (c) If you comply with the combustion methodology specified in §98.243(d), you must report under this subpart the information listed i n paragraphs (c)(1) through (c)(5) of this section. (1) The ethylene process unit ID or other appropriate descriptor. (2) For each stationary combustion unit that burns ethylene process off

- gas (or group of stationary sources with a common pipe), except fl ares, the relevant information listed in §98.36 for the applicable Tier methodology. For each stationary combustion unit or group of units (as applicable) that burnsPage 25 of 27 ethylene process off

- gas, provide an estimate based on engineering judgment of the fractio n of the total emissions that is attributable to combustion of off

- gas from the ethylene process unit. (3) Information listed in §98.256(e) of subpart Y of this part for each flare that burns ethylene process off

- gas. (4) Name and annual quantity of each f eedstock (metric tons)
. (5) Annual quantity of ethylene produced from each process unit (metric tons).

In addition to the recordkeeping requirements in §98.3(g), you must retain the records specified in paragraphs (a ) through (c) of this section, as applicable. § 98.247 Records that must be retained.

(a) If you comply with the CEMS measurement methodology in §98.243(b), then you must retain under this subpart the records required for the Tier 4 Calculation Methodology in §98.37, records of the procedures us ed to develop estimates of the fraction of total emissions attributable to combustion of petrochemical process off

- gas as required in §98.246(b), and records of any annual average HHV calculations. (b) If you comply with the mass balance methodology in §98.243(c), then you must retain records of the information listed in paragraphs (b)(1) through (b)( 3 4 ) of this section.Page 26 of 27 (1) Results of feedstock or product composition determinations conducted in accordance with §98.243(c)(4). (2) Start and end times and calculated carbon contents for time periods when off

- specification product is produced, if you comply with the alternative methodology in §98.243(c)(4) for determining carbon content of feedstock or product. (3) A part of the monitoring plan required under §98.3(g)(5), record the estimated accuracy of measurement devices and the technical basis for these estimates. (4) The dates and results ( e.g.

(c) If you comply with the combustio n methodology in §98.243(d), then you must retain under this subpart the records required for the applicable Tier Calculation Methodologies in §98.37. If you comply with §98.243(d)(2), you must also keep records of the annual average flow calculations. , percent calibration error) of the calibrations of each measurement device.

Except as specified in this section, all terms used in this subpart have the same meaning given in the Clean Air Act and subpart A of this part. § 9 8.248 Definitions.

Product , as used in §98.243, means each of the following carbon

- containing outputs from a pr ocess: the petrochemical, recovered byproducts, and liquid organic wastes that are notPage 27 of 27
incinerated combusted onsite. Product does not include process vent emissions, fugitive emissions, or wastewater.