Page 1 of 23

**Subpart X**

**— Petrochemical Production**  **§98.240 Definition of the source category.**  (a) The petrochemical production source category consists of processes as described in paragraphs (a)(1) through (3) of this section
. (1) The petrochemical production source category consists of all processes that produce
acryl onitrile, carbon black, ethylene, ethylene dichloride, ethylene oxide, or methanol, except as specified in paragraphs (b) thro ugh (g) of this section. (2) The petrochemical production source category includes processes that produce the petrochemical as an intermediate in the on

- site production of other chemicals as well as processes that produce the petrochemical as an end produ ct for sale or shipment off site. (3) When ethylene dichloride and vinyl chloride monomer are produced in an integrated process, you may consider the entire integrated process to be the petrochemical process for the purpose of compl yi ng with the mass balan ce option in § 98.243(c)
. If you elect to consider the integrated process to be the petrochemical process, then the mass balance must be performed over the entire integrated process. (b) A process that produces a petrochemical as a byproduct is not part of the petrochemical production source category
. (c) A facility

that makes methanol, hydrogen, and/or ammonia from s ynthesis gas is part of the petrochemical source category if the annual mass of methanol produced exceeds the individual annual mass productio n levels of both hydrogen recovered as product and ammonia. The facility

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 Manufacturing)Page 2 of 23

if the annual mass of ammonia produced exceeds the individual annual mass production levels of both hydrogen recovered as product and methanol. (d) A direct chlorination process that is operated independentl y of an ox yc hlorination process to produce eth yl ene 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 solel y distills or recycles waste solvent that contains a petrochemical is not part of the petrochemical production source category
. **§98.241 Reporting threshold.**  You must report GHG emissions 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). **§98.242 GHGs to repo**  **rt.** You must report the information in paragraphs (a) through (c) of this section: (a) CO 2 CH 4 , and N 2 O process emissions from each petrochemical process unit. Process emissions include CO 2 generated b y reaction in the process and b y combustion of process off

- gas in stationary

combustion units and flares. (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 compl y with §98.243(b), also report under this subpartPage 3 of 23

the measured CO 2 emissions from process vents routed to stacks that are not as sociated with stationary combustion units. (2) If you comply

with §98.243(c), report under this subpart the calculated CO 2 emissions for each petrochemical process unit. (b) CO 2 , CH 4 , and N 2 O combustion emissions from stationary combustion units. (1) If yo u 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 follo wing the requirements of subpart C. (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 Combustion Sources) by following the requirements of subpart C for all fuels, except emissions from burning petrochemical process off

- gas in an y combustion unit, including units that are not part of the petrochemical process unit, are not to be reported under subpart C of this part. Determine the applicable Tier 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. **§98.243 Calculating GHG emissions.**  (a) If you route all process vent emissions and emissions from combustion of process off

gas to one or more stacks and use CEMS on each stack to measure CO 2 emissions (except flar e stacks), then you must determine process

- based GHG emissions in accordance with paragraphPage 4 of 23

(b) of this section. Otherwise, determine process

- based GHG emissions in accordance with the procedures specified in paragraph (c) or (d) of this section. (b) Conti nuous emission monitoring sy stem (CEMS)
. 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 determine GHG emissions as specified in paragraphs (b)(1) through (3) of this section. (1) Determine CO 2 emissions from each stack (except flare stacks) according to the Tier 4 Calculation Methodology requirements in subpart C of this part. (2) For each stack (except flare stacks) that includes emissions from combustion of petrochemical process off

- gas, calculate CH 4 and N 2 O emissions in accordance with subpart C of this part (use Equation C

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

- 2 of subpart C of this part). (3) For each flare, calculate CO 2 , CH 4 , and N 2 O emissio ns using the methodology specified in §98.253(b)(1) through (3). (c) Mass balance for each petrochemical process unit
. Calculate the emissions of CO 2 from each process unit, for each calendar month as described in paragraphs (c)(1) through (c)(5) of this s ection. (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). Alternatively , for liquids, you may calculate the volum e 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 the procedures specified in §98.244(b)(3). Fuels used fo r combustion purposes are not considered to be feedstocks.Page 5 of 23

(2) For each solid feedstock and product, measure the mass used or produced each calendar month by

following the procedures specified in §98.244(b)(1). (3) Collect a sample of each feedstock and product at least once per month and determine the molecular weight ( for gaseous materials when the quantity is measured in scf) and carbon content of each sample according to the procedures of §98.244(b)(4). If multiple valid molecular weight or carbon content measurements are made during the monthl y measurement 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 so urce in a given calendar month, only one representative sample is required. Alternatively , you may use the results of anal ys es conducted by a feedstock supplier, or product customer, provided the sampling and anal ys is is conducted at least once per month u sing an y of the procedures specified in §98.244(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, then as an alternative to the sampling and analy sis specified in paragraph (c)(3) of this section, you may determine molecular weight and carbon content in accordance with paragraphs (c)(4)(i) through (iii) of this section. (i) Calculate the molecular weight and carbon content assuming 100 percent o f that feedstock or product is the specific compound. (ii) Maintain records of any determination made in accordance with this paragraph (c)(4) along with all supporting data, calculations, and other information. (iii) Reevaluate determinations made under this paragraph (c)(4) after any process change that affects the feedstock or product composition. Keep records of the process change and the corresponding composition determinations. If the feedstock or product composition changes soPage 6 of 23

that the average monthl y concentration falls below 99.5 percent, you are no longer permitted to use this alternative method. (5) Calculate the CO 2 mass emissions for each petrochemical process unit using Equations X

- 1 through X

- 4 of this section. (i) Gaseous feedstocks and produ cts
. 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.
(E q . X
- 1) Where: C g = Annual net contribution to calculated emissions from carbon (C) in gaseous

materials, including streams containing CO 2 recovered for sale or use in another process (kg/yr). (F gf ) i,n = Volume or mass of gaseous feedstock i introduced in month “n” (scf or kg). If

yo u measure mass, the term (MW f ) i,n/MVC is replaced with “1”. (CC gf ) i,n = Average carbon content of the gaseous feedstock i for month “n” (kg C per kg

of feedstock). (MW f ) i,n = Molecular weight of gaseous feedstock i in month “n”(kg/kg

- mole). 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). (P gp ) i,n = Volume or mass of gaseous product i produced in month “n” (scf or kg). If you

measure mass, the term (MWp ) i,n/MVC is replaced with “1”. (CC gp ) i,n = Average carbon content of gaseous product i, including streams containing CO 2

recovered for sale or use in another process, for month “n” (kg C per kg of product). (MWp ) i,n = Molecular weight of gaseous product i in month “n” (kg/kg

- mole). j = Number of feedstocks.Page 7 of 23

k = Number of products. (ii) Li quid 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.
(Eq. X

- 2) Where: C l = Annual net contribution to calculated emissions from carbon in liquid mat erials,

including liquid organic wastes (kg/yr). (F lf ) i,n = Volume or mass of liquid feedstock i introduced in month “n” (gallons or kg). (CC lf ) i,n = Average carbon content of liquid feedstock i for month “n” (kg C per gallon or

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

month “n” (kg C per gallon or kg of product). j = Number of feedstocks. k = Number of p roducts. (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 proc ess but there are solid products.
(Eq. E

- 3) Where: C s = Annual net contribution to calculated emissions from carbon in solid materials

(kg/yr). (F sf ) i,n = Mass of solid feedstock i introduced in month “n” (kg).Page 8 of 23

(CC sf ) i,n = Average carbon content of soli d feedstock i for month “n” (kg C per kg of

feedstock). (P sp ) i,n = Mass of solid product i produced in month “n” (kg). (CC sp ) i,n = Average carbon content of solid product i in month “n” (kg C per kg of

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

- 1 through X

- 3 of this section, as applicable, in Equation X

- 4 of this section to calculate annual CO 2 emissions.
(Eq. X

- 4) Where: CO 2 = Annual CO 2 mass emissions from process operations and process off

- gas combustion (metric tons/year). 0.001 = Conversion factor from kg to metric tons. 44 = Molecular weight of CO 2 (kg/kg

- mole). 12 = Atomic weight of carbon (C) (kg/kg

- mole). (d) Optional combustion methodology for ethylene production proces ses . For each ethylene production process, calculate GHG emissions from combustion units that burn fuel that contains an y off

- gas from the ethylene process as specified in paragraphs (d)(1) through (d)(5) of this section. (1) Except as specified in paragra phs (d)(2) and (d)(5) of this section, calculate CO 2 emissions using the Tier 3 or Tier 4 methodology in subpart C of this part. (2) You may

use either Equation C

- 1 or Equation C

- 2a in subpart C of this part to calculate CO 2 emissions from combustion of an y ethylene process off

- gas streams that meetPage 9 of 23

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 otherw ise applicable procedures in subpart C to calculate emissions from combustion of all other fuels in the combustion unit. (i) The annual average flow rate of fuel gas (that contains ethylene process off

- gas) in the fuel gas line to the combustion unit, prio r 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 square inch absolute, and a flow meter is not installed at any point in the line supplying fuel gas or an upstream common pipe. C alculate the annual average flow rate using compan y records assuming total flow is evenly distributed over 525,600 minutes per year. (ii) The combustion unit has a maximum rated heat input capacity of less than 30 mmBtu/hr, and a flow meter is not installe d 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 applicable procedures in §98.33(c) for the same tier methodology that you used for calculating CO 2 emissions. (i) For all gaseous fuels that contain eth yl ene process off

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

- 2 of subpart C of this part (General Stationary Fuel Combustion Sources). (ii) For Tier 3, use 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. (4) You are not required to use the same Tier for each stationary c ombustion unit that burns ethylene process off

- gas.Page 10 of 23

(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). **§98.244 Monitoring and QA/QC requirements.**  (a) If you use CEMS to determine emis sions from process vents, you must comply with the procedures specified in §98.34(c). (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 pro duct flows and carbon contents. (1) Operate, maintain, and calibrate belt scales or other weighing devices as described in Specifications, Tolerances, and Other Technical Requirements for Weighing and Measuring Devices NI ST 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., once every

two years). (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 specif

ied in paragraphs (b)(2)(i) and (b)(2)(ii) of this section: (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) through (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, bienniall y (every two years), or at the interval specified b y the industry consensus standard practice used.Page 11 of 23

(3) You must perform tank level measurements (if used to determine feedstock or product flows) according to one of the following methods. You may use any standard me thod 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, http://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 20001, (202) 824

- 7000, http://www.aga.org ), the American Societ y 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 (xv) of this section to determine the carbon content or composition of feedstocks and products and the average molecular weight of gaseous feedstocks and products. Calibr ate instruments in accordance with paragraphs (b)(4)(i) through (xv) of this section, as applicable. For coal used as a feedstock, the samples for carbon content determinations shall be taken at a location that is representative of the coal feedstock used during the corresponding monthly period. For carbon black products, samples shall be taken of each grade or typ e of product produced during the monthly period. Samples of coal feedstock or carbon black product for carbon content determinations may be eithe r grab samples collected and anal yz ed monthl y orPage 12 of 23

a composite of samples collected more frequentl y and anal yz ed monthly . Analy ses conducted in accordance with methods specified in paragraphs (b)(4)(i) through (xv) of this section may be performed b y the own er or operator, b y an independent laboratory , by the supplier of a feedstock, or b y a product customer. (i) ASTM D1945

- 03, Standard Test Method for Analy sis of Natural Gas by Gas Chromatograph y (incorporated b y reference, see §98.7). (ii) ASTM D6060

- 96 (Re approved 2001) Standard Practice for Sampling of Process Vents With a Portable Gas Chromatograph (incorporated b y reference, see §98.7). (iii) ASTM D2505

- 88(Reapproved 2004)e1 Standard Test Method for Ethylene, Other Hydrocarbons, and Carbon Dioxide in High

- Purity Ethylene b y Gas Chromatograph y (incorporated b y reference, see §98.7). (iv) ASTM UOP539

- 97 Refinery Gas Anal ys is by

Gas Chromatography

(incorporated by reference, see §98.7). (v) ASTM D3176

- 89 (Reapproved 2002) Standard Practice Method for Ultimat e Analy sis of Coal and Coke (incorporated by reference, see §98.7). (vi) ASTM D5291

- 02 (Reapproved 2007) Standard Test Methods for Instrumental Determination of Carbon, Hydrogen, and Nitrogen in Petroleum Products and Lubricants (incorporated b y reference, see §98.7). (vii) ASTM D5373

- 08 Standard Test Methods for Instrumental Determination of Carbon, Hydrogen, and Nitrogen in L aboratory Samples of Coal (incorporated by reference, see §98.7). (viii) Method 8015C, Method 8021B, Method 8031, or Method 9060A (all incorporated by reference, see §98.7). (ix) Method 18 at 40 CFR part 60, appendix A

- 6.Page 13 of 23

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

- day

calibration error test period must be completed prior to the effective date of the rule. (xi) ASTM D2593

- 93 (Reapproved 2009) Standard Test Method for Butadiene Purity and Hydrocarbon Impurities by Gas Chromatography

(incorporated by

reference, see §98.7). (xii) ASTM D7633

- 10 Standard Test Method for Carbon Blac k

— Carbon Content (incorporated b y reference, see §98.7). (xiii) The results of chromatographic analy sis of a feedstock or product, provided that the chromatograph is operated, maintained, and calibrated according to the manufacturer's instructions. (xiv) T he results of mass spectrometer anal ys is of a feedstock or product, provided that the mass spectrometer is operated, maintained, and calibrated according to the manufacturer's instructions. (xv) Beginning on January 1, 2010, the methods specified in paragr aphs (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

standard practice or a method published by a consensus - based standards organizatio n 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, Penns yl vania 19428
- B2959, (800) 262

- 1373, http://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 Stre et NW., 4thPage 14 of 23

Floor, Washington, DC 20001, (202) 824

- 7000, http://www.aga.org ), the American Societ y 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.naesb.org ). The method(s) used shall be document ed in the monitoring plan required under §98.3(g)(5). (B) Modifications of existing anal yt ical methods or other methods that are applicable to yo ur 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 quality control requirements are not technicall y feasible, or use of the method would be unsafe. (c) If you compl y with §98.243(b) or (d), conduct monitoring and QA/QC for flares in accord ance with §98.254(b) through (e) for each flare gas flow meter, gas composition meter, and/or heating value monitor that you use to comply with §98.253(b)(1) through (b)(3). You must implement all applicable QA/QC requirements specified in this paragraph ( c) beginning no later than January

1, 2015. **§98.245 Procedures for estimating missing data.**  For missing feedstock and product flow rates, use the same procedures as for missing fuel usage as specified in §98.35(b)(2). For missing feedstock and product carb on contents and missing molecular weights for 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).Page 15 of 23

**§98.246 Data reporting requirements.**  In addition to the information required b y §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. (a) I f you use the mass balance methodology in §98.243(c), you must report the information specified in paragraphs (a)(1) through (13) of this section for each type of petrochemical produced, reported b y process unit. (1) The petrochemical process unit ID number or other appropriate descriptor. (2) The t ype of petrochemical produced, names of products, and names of carbon

containing feedstocks. (3) Annual CO 2 emissions calculated using Equation X

- 4 of this subpart. (4) The temperature (in °F) at which the g aseous feedstock and product volumes used in Equation X

- 1 of §98.243 were determined. (5) Annual quantity of each type of petrochemical produced from each process unit (metric tons). If your petrochemical process is an integrated eth yl ene dichloride and vinyl chloride monomer process, report either the measured eth yl ene dichloride production (metric tons) or both the measured quantity of vin ylchloride monomer production (metric tons) and an estimate of the eth yl ene dichloride production (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 used to determine carbon content or molecular weight in accordance with §98.244(b)(4);Page 16 of 23

(ii) Description of each ty pe of measurement device (e.g., flow meter, weighing device) used to determine volume or mass in accordance with §98.244(b)(1) through (3). (iii) I dentification of each method (i.e., method number, title, or other description) used to deter mine volume or mass in accordance with §98.244(b)(1) through (3). (7) [Reserved] (8) Identification of each combustion unit that burned both process off

- gas and supplemental fuel, including combustion units that are not part of the petrochemical proce ss unit. (9) The number of day s during which off

- specification product was produced if the alternative to sampling and anal ys is specified in §98.243(c)(4) is used for a product, and, if applicable, the date of any process change that reduced the monthly av erage composition to less than 99.5 percent for each product or feedstock for which you compl y with the alternative to sampling and anal ys is specified in §98.243(c)(4). (10) You may

elect to report the flow and carbon content of wastewater, and you may ele ct 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 estimated based on engineering anal ys es. These values are not to be used in the mass balance ca lculation. (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 paragraphs (a)(11)(i) through (a)(11)(iii) of this section. Include the information in para graph (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 analy tical method.Page 17 of 23

(ii) A cop y of the method. If the method is a modification of a method listed in §§98.244(b)(4)(i) through (xiv), you may provide a cop y of onl y the sections that differ from the listed method. (iii) An explanat ion of why an alternative to the methods listed in §§98.244(b)(4)(i) through (xiv) is needed. (12) Name and annual quantity (in metric tons) of each carbon

- containing feedstock included in Equations X

- 1, X
- 2, and X

- 3 of §98.243. (13) Name and annual quanti ty (in metric tons) of each product included in Equations X

1, X
- 2, and X

- 3. (14) Annual average of the measurements of the carbon conte nt of each feedstock and product
. (i) For feedstocks and products that are gaseous or solid, report this quantity in kg carbon per kg of feedstock or product. (ii) For liquid feedstocks and products, report this quantity either in units of kg carbon per kg of feedstock or production , or kg C per gallon of feedstock or product. (15) F or each gaseous feedstock and product , the annual average of the measurements of molecular weight in units of kg per kg mole
. (b) If you measure emissions in accordance with §98.243(b), then you must report the information listed in paragraphs (b)(1) through (10) of this section. (1) The petroc hemical process unit ID or other appropriate descriptor, and the ty pe of petrochemical produced. (2) For CEMS used on stacks that include emissions from stationary combustion units that burn an y amount of off

- gas from the petrochemical process, report the relevant informationPage 18 of 23

required under §98.36(c)(2) and (e)(2)(vi) for the Tier 4 calculation methodology . Sections 98.36(c)(2)(ii) , (c)(2)(ix) and (c)(2)( x) do not apply for the purposes of this subpart. (3) For CEMS used on stacks that do not include emiss ions from stationary combustion units, report the information required under §98.36(b)(6), (b)(7), (b)(9)(i), (b)(9)(ii) and (e)(2)(vi). (4) For each CEMS monitoring location that meets the conditions in paragraph (b)(2) or (3) of this section, provide an estimate based on engineering judgment of the fraction of the total CO 2 emissions that results from CO 2 directly emitted by

the petrochemical process unit plus CO 2 generated b y the combustion of off

- gas from the petrochemical process unit. (5) For each CEM S monitoring location that meets the conditions in paragraph (b)(2) of this section, report the CH 4 and N 2 O emissions expressed in metric tons of each gas. For each CEMS monitoring location, provide an estimate based on engineering judgment of the fraction of the total CH 4 and N 2 O emissions that is attributable to combustion of off

- gas from the petrochemical process unit. (6) [Reserved] (7) Information listed in §98.256(e) of subpart Y of this part for each flare that burns process off

- gas. (8) Annual quantit y of each type of petrochemical produced from each process unit (metric tons). I f your petrochemical process is an integrated eth yl ene dichloride and vinyl chloride monomer process, report either the measured eth yl ene dichloride production (metric t ons) or both the measured quantity of vin ylchloride monomer production (metric tons) and an estimate of th e eth yl ene dichloride product (metric tons). (9) Name and annual quantity (in metric tons) of each carbon

- containing feedstock.Page 19 of 23

(10) Name and annual quantity (in metric tons) of each product. (c) If you compl y with the combustion methodology specified in §98.243(d), you must report under this subpart the information listed in paragraphs (c)(1) through (c)(5) of this section. (1) The eth yl ene process un it 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 flares, the relevant information listed in §98.36 for the applicable Tier methodo logy . For each stationary combustion unit or group of units (as applicable) that burns ethylene process off

- gas, provide an estimate based on engineering judgment of the fraction 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 feedstock (metric tons). (5) Annual quantity of ethylene produced from each proc ess unit (metric tons). **§98.247 Records that must be retained.**  In addition to the recordkeeping requirements in §98.3(g), you must retain the records specified in paragraphs (a) through (d) of this section, as applicable. (a) If you compl y with the CEMS me asurement 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 used to develop estimates of the fraction of total emissions attributable to petro chemical processing and combustion of petrochemical process off

- gas as required in §98.246(b), and records of an y annual average HHV calculations.Page 20 of 23

(b) If you comply

with the mass balance methodology in §98.243(c), then you must retain records of the inform ation listed in paragraphs (b)(1) through (4) of this section. (1) Results of feedstock or product composition determinations conducted in accordance with §98.243(c)(4). (2) Start and end times for time periods when off

- specification product is produced, i f yo u compl y with the alternative methodology in §98.243(c)(4) for determining carbon content of product. (3) As 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., percent calibration error) of the calibrations of each measurement device. (c) If you compl y with the combustion methodology in §98.243(d), then yo u must retain under this subpart the records required for the app licable Tier Calculation Methodologies in §98.37. If you compl y with §98.243(d)(2), you must also keep records of the annual average flow calculations. (d) Verification software records. You must keep a record of the file generated by the verification software specified in §98.5(b) for the applicable data specified in paragraphs (d)(1) through (30) of this section. Retention of this file satisfies the recordkeeping requirement for the data in paragraphs (d)(1) through (30) of this section. (1) Indicate whether the feedstock is measured as mass or volume (Equation X

- 1 of §98.243). (2) Indicate whether you used the alternative to sampling and analysis specified in §98.243(c)(4) (Equation X

- 1).Page 21 of 23

(3) Volume of gaseous feedstock introduced per month (scf) (Equatio n X
- 1). (4) Mass of gaseous feedstock introduced per month (kg) (Equation X

- 1). (5) Average carbon content of the gaseous feedstock per month (kg C per kg of feedstock) (Equation X

- 1). (6) Molecular weight of gaseous feedstock per month (kg per kg

- mole) (E quation X

- 1). (7) Indicate whether the gaseous product is measured as mass or volume (Equation X

- 1). (8) Volume of gaseous product produced per month (scf) (Equation X

- 1). (9) Mass of gaseous product produced per month (kg) (Equation X

- 1). (10) Average carbon content of gaseous product (including streams containing CO 2 recovered for sale or use in another process) per month (kg C per kg of product) (Equation X

- 1). (11) Molecular weight of gaseous product per month (kg per kg

- mole) (Equation X

- 1). (12) Mo lar volume conversion factor of product (scf per kg

- mole) (Equation X

- 1). (13) Indicate whether feedstock is measured as mass or volume (Equation X

- 2 of §98.243). (14) Indicate whether yo u used the alternative to sampling and anal ys is specified in §98.243( c)(4) (Equation X

- 2). (15) Volume of liquid feedstock introduced per month (gallons) (Equation X

- 2). (16) Mass of liquid feedstock introduced per month (kg) (Equation X

- 2). (17) Average carbon content of liquid feedstock per month (kg C per gallon) (Equati on X
- 2). (18) Average carbon content of liquid feedstock per month (kg C per kg of feedstock) (Equation X

- 2). (19) Indicate whether product is measured as mass or volume per month (Equation X

- 2).Page 22 of 23

(20) Volume of liquid product produced per month (gallons) ( Equation X

- 2). (21) Mass of liquid product produced per month (kg) (Equation X

- 2). (22) Average carbon content of liquid product per month, including organic liquid wastes (kg C per gallon) (Equation X

- 2). (23) Average carbon content of liquid product, inc luding organic liquid wastes (kg C per kg of product) (Equation X

- 2). (24) Indicate whether yo u used the alternative to sampling and anal ys is specified in §98.243(c)(4) (Equation X

- 3 of §98.243). (25) Mass of solid feedstock introduced per month (kg) (Equation X

- 3). (26) Average carbon content of solid feedstock per month (kg C per kg of feedstock) (Equation X

- 3). (27) Mass of solid product produced per month (kg) (Equation X

- 3). (28) Average carbon content of solid product per month (kg C per kg of product) (Equation X

- 3). (29) Records required in §98.257(b)(1) through (8) of this section for each flare that burns ethylene process off

- gas. (30) Records required in §98.37 for each stationary fuel combustion unit (or group of stationary sources with a common pipe) that burns ethylene process off

- gas, except flares. **§98.248 Definitions.**  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.Page 23 of 23

Product means each of the following carbon

- containing outputs from a process: the petrochemical, recovered by products, and liquid organic wastes that are not combusted onsite. Product does not include process vent emissions, fugitive emissions, or wastewater.