050 – Industrial Natural Gas Combustion

Page 1 of 17 Rev. Date: 13 June 2006 IndustrialNG2006.doc Rev. By: K Thao 

# 2006 Area Source Emissions Inventory Methodology

050 – INDUSTRIAL NATURAL GAS COMBUSTION

I. Purpose

This document describes the Area Source Methodology used to estimate emissions of carbon monoxide (CO), nitrogen oxides (NOx), fin e particulate matter less then 10 microns (PM 10 

### ), volatile organic compounds (VOC), and sulfur oxi des (SOx) from the combustion of natural gas from industrial sources n ot reported through the District’s point source inventory. An area source is a collec tion of similar emission units within a geographic area (ie., a County). Area sources co llectively represent individual sources that are small and numerous, and that may n ot have not been inventoried as specific point, mobile, or biogenic sources. The California Air Resources Board (CARB) has grouped these individual sources with ot her like sources into area source categories. These source categories are grou ped in such a way that they can be estimated collectively using one methodology.



## II. Applicability

The emission calculations from this Area Source Met hodology apply to facilities that are identified by the following Category of Emissio n Source (CES) codes and Reconciliation Emission Inventory Codes (REIC):

Table 1. Emission inventory codes.

CES REIC Description 66787 050-040-0110-0000 Industrial Stationary - I.C . Engines - Natural Gas
47142 050-995-0110-0000 Industrial Natural Gas Comb ustion (Unspecified)



## III. Point Source Reconciliation

Emissions from the area source inventory and point source inventory are reconciled against each other to prevent double counting. Thi s is done using relationships created by the California Air Resources Board (ARB) between the area source REIC and the point sources’ Standard Industry Classifica tion (SIC) code and emissions process Source Category Code (SCC) combinations. T he area sources in this methodology reconcile against processes in our poin t source inventory with the SIC/SCC combinations listed in Appendix A. 

# San Joaquin Valley

AIR POLLUTION CONTROL DISTRICT050 – Industrial Natural Gas Combustion

Page 2 of 17 Rev. Date: 13 June 2006 IndustrialNG2006.doc Rev. By: K Thao 

## IV. Methodology Description

This area source methodology is a top down estimati on of emissions from the combustion natural gas by the industrial sector in the San Joaquin Valley Air
Pollution Control District. The industrial sector consumes natural gas for process uses (primarily heat), boiler fuel, space heat, ele ctricity generation and feedstock. These end uses are divided into two categories: 1) stationary internal combustion engines - reciprocating engines and turbines, and 2 ) unspecified. The “unspecified” category includes external combustion sources such as heaters, boilers, and burners. The amount of natural gas delivered to in dustrial sources in each county
within the District was obtained from the Californi a Energy Commission (Gough, 2007). From this, the amount of natural gas report ed to the District’s point source inventory as consumed was subtracted. The differen ce between the amount of natural gas reported delivered and the amount repor ted consumed was considered the area source process rate. To estimate area sou rce emissions, the area source process rate was assigned to end uses and then mult iplied by emission factors.



## V. Activity Data

Consumption . Total natural gas deliveries to the industrial s ector for each county in
the district in was obtained from the California En ergy Commission (Gough, 2007) and is presented below. Industrial deliveries excl ude companies whose primary function is to generate electricity or produce oil and gas as determined by their company SIC. Emissions from these industries are t abulated in other EICs. The District’s point source inventory of industrial nat ural gas combustion processes was then reconciled against the amount of natural gas r eported delivered to industrial
sources within the District. The area source consu mption was calculated as the difference between the industrial natural gas deliv eries and the industrial consumption reported through the point source inven tory (Table 2).

Table 2. 2006 industrial natural gas consumption ( MMSCF).

County Industrial Deliveries Reported by CEC Industrial Point Source Consumption Reconciled Area Source Consumption
Fresno 8,868.32 5,691.36 3,176.96 Kern 7,106.00 3,136.98 3,969.01 Kings 3,163.25 2,435.93 727.31 Madera 3,332.25 1,625.83 1,706.42 Merced 7,529.53 5,683.38 1,846.15 San Joaquin 7,231.04 5,861.54 1,369.50 Stanislaus 7,279.97 5,569.08 1,710.89 Tulare 6,960.05 5,521.34 1,438.70
Total 51,470.41 35,525.48 15,944.93050 – Industrial Natural Gas Combustion

Page 3 of 17 Rev. Date: 13 June 2006 IndustrialNG2006.doc Rev. By: K Thao 

### Categorization . To categorize industrial natural gas end use, we used a 1994 report prepared by the Energy Information Administration ( EIA) entitled “How Changing Energy Markets Affects Manufacturing.” This study divided industrial natural gas consumption into the three main end use categories presented in Table 3.

Table 3. Industrial natural gas consumption catego ries.

REIC Category Description Combustion Process Industrial
Natural Gas Consumption

050-040-0110-0000 Industrial Stationary - I.C. Engines - Natural Gas Turbines/Reciprocating Engines 6%

050-995-0110-0000 Industrial Natural Gas Combustion (Unspecified) Heaters, Boilers, and Furnaces 84%

Feedstock Non-combustion
Processes Natural Gas used in the synthesis of other products 10%



### The Feedstock category does not involve natural gas combustion and will not be considered in this area source methodology.



## VI. Emission Factors

CO, NOx, SOx, VOC and PM emission factors for recip rocating engines and “unspecified” industrial natural gas combustion wer e obtained from the EPA’s AP-42 document (EPA, 1998 & 2000b). The SOx emission fac tor for all processes was obtained from San Joaquin Valley Air Pollution Cont rol District Policy APR 1720.

For internal combustion (IC) engines, the NOx, VOC, CO, and PM10 emission factors were taken from AP-42, section 3.2, table 3 .2-2 (EPA, 2000b). The NOx and CO emission factors were used under the assumption that the IC engines are 4- stroke lean-burn engines operating at normal condit ions and less than 90% load. The Total Organic Gas (TOG) emission factor was spe ciated into a VOC emission factor using CARB’s speciation profile. The PM 10 

### emission factor is also taken from the same table. In an effort to provide a more con servative estimate, the total PM (condensable) emission factor was speciated into PM 10 

### emissions using CARB’s speciation profiles.

For small boilers, the NOx, VOC, CO, and PM10 emiss ion factors were taken from AP-42, section 1.4, tables 1.4-1 and 1.4-2 (EPA, 19 98). The NOx and CO emission factors were taken under the assumption that these were small, uncontrolled boilers. The VOC emission factor was taken directly from AP- 42 because it would be higher than the speciated TOC emission factor and therefor e be a more conservative
emission factor. The PM10 emission factor was obta ined by applying the CARB speciation profile to the total PM emission factor.050 – Industrial Natural Gas Combustion

Page 4 of 17 Rev. Date: 13 June 2006 IndustrialNG2006.doc Rev. By: K Thao

Table 4. Industrial natural gas combustion emissio n factors.
Emissions (pounds per million cubic feet) Combustion process NO
x CO SO
x VOC PM 10 Reciprocating Engines 864 568 2.9 4.7 10.2 Unspecified 100 84 2.9 5.5 7.6



## VII. Emissions Calculations

A. Assumptions

1. Natural gas deliveries are accurately reported b y the California Energy
Commission.

2. EIA’s study of the end-use consumption of natura l gas within the manufacturing sector accurately describes the end-u se consumption of natural gas by the industrial sector within the Dis trict.

3. The AP-42 emission factors selected for reciproc ating engines and unspecified devices are representative.

4. All non-permitted natural gas powered internal c ombustion engines within the District are 4-stroke lean-burn engines.

5. All non-permitted unspecified natural gas combus tion devices within the
District are uncontrolled small boilers.

B. Sample Calculations:

The emissions for each criteria pollutant within th is area source methodology can be calculated using the following equation:



# ( )                        

× × × = lbs 2000 ton 1

MMSCF Emissions of lbs Factor Emission Use End %

yr MMSCF

n Consumptio Fuel
yr tons Emissions



### For NO
x 

### emissions due to natural gas combustion in unspeci fied industrial sources in Fresno County:

Given:

1. The reconciled area source consumption of natura l gas by the industrial sector in Fresno County was 3,177 MMSCF (million std. cubi c feet) in 2006.

2. 84% of industrial end use was for unspecified so urces.050 – Industrial Natural Gas Combustion

Page 5 of 17 Rev. Date: 13 June 2006 IndustrialNG2006.doc Rev. By: K Thao 

### 3. The NOx emission factor for unspecified industri al natural gas combustion is 100 pounds per million cubic feet of natural gas bu rned.

Calculate Emissions:



# ( )
Year NOx of lbs 868

, 266

MMSCF NOx of lb 100 84.0 Year MMSCFt 177 ,3 Emissions NOx =      

× ×      

=



### Year NOx of tons 4. 133

lbs 000 ,2 ton 1

Year NOx of lbs 868

, 266 Emissions NOx =        

×      

=



## VIII. Temporal Variation

The following section outlines the daily, weekly, a nd monthly consumption of natural gas within the San Joaquin Valley for each end use category due to temporal
variations.

A. Daily

ARB Code 24. 24 hours per day - uniform activity d uring the day

B. Weekly

ARB Code 7. 7 days per week - uniform activity eve ry day of the week

C. Monthly

Monthly activity in California is relatively unifor m as illustrated by 2006 industrial natural gas consumption data from the U.S. Departme nt of Energy’s Energy Information Administration presented below:

Table 5. California industrial natural gas consump tion.

Month (2006) Natural Gas Consumption

(million cubic feet) Activity Level (% of annual) January 60,043 8.20% February 59,659 8.15% March 61,924 8.46% April 60,888 8.32% May 58,174 7.95% June 57,333 7.83% July 59,573 8.14% August 62,997 8.61% September 64,032 8.75% October 63,729 8.71% November 60,995 8.33% December 62,708 8.57%

Total 732,055 100.00%050 – Industrial Natural Gas Combustion

Page 6 of 17 Rev. Date: 13 June 2006 IndustrialNG2006.doc Rev. By: K Thao 

## IX. Spatial Variation

Industrial natural gas deliveries in 2006 for each county in the SJVAPCD were provided by the California Energy Commission (Gough , 2007) and were presented previously in Section V. Within each county, activ ity can be assigned to parcels zoned for industrial activity.



## X. Growth Factor

Growth factors are developed by either the District ’s Planning Department or CARB
for each EIC. These factors are used to estimate e missions in future years. The growth factors associated with this emissions categ ory may be obtained from the Air Quality Analysis Section of the District’s Planning Department.



## XI. Control Level

Emission units within this area source category may be subject to the following
District Rules:

Table 6. District rules applicable to REIC 050-040 -0110-0000 and 050-995-0110-0000.

Rule No. Rule Description 4701 Internal Combustion Engines - Phase 1 4702 Internal Combustion Engines - Phase 2 4703 Stationary Gas Turbines 4305 Boilers, Steam Generators, and Process Heaters - Phase 2 4306 Boilers, Steam Generators, and Process Heaters - Phase 3 4307 Boilers, Steam Generators, and Process Heaters - 2.0 MMBtu/hr to 5.0 MMBtu/hr 4308 Boilers, Steam Generators, and Process Heaters (0.075 MMBtu/hr to 2.0 MMBtu/hr) 4309 Dryers, Dehydrators and Ovens
4311 Flares
4313 Lime Kilns 4351 Boilers, Steam Generators, and Process Heaters - Phase 1



### Control levels associated with this emissions categ ory may be obtained from the Air Quality Analysis Section of the District’s Planning Department.



## XII. ARB Chemical Speciation

CARB has developed organic gas profiles in order to calculate reactive organic gasses (ROG), volatile organic compounds (VOC) or t otal organic gas (TOG) given any one of the three values. For each speciation p rofile, the fraction of TOG that is ROG and VOC is given. The organic gas profile codes can also be used to lookup associated toxics. CARB’s speciation profiles for industrial natural gas combustion processes are presented in Table 7. Organic gas pr ofile #719 is applied to REIC 050-040-0110-0000 (Industrial stationary IC engines , natural gas). Organic gas050 – Industrial Natural Gas Combustion

Page 7 of 17 Rev. Date: 13 June 2006 IndustrialNG2006.doc Rev. By: K Thao 

### profile #3 is applied to REIC 050-995-0110-0000 (In dustrial natural gas combustion, unspecified).

CARB has developed particulate matter speciation pr ofiles in order to calculate particulate matter (PM), particulate matter with a diameter less than or equal to 10 microns (PM 10 

### ) or particulate matter with a diameter less than o r equal to 2.5 microns (PM 2.5 

### ) given any one of the three values. For each spec iation profile, the
fraction of PM that is PM 10 

### and PM 2.5 

### is given. The particulate matter profile codes can also be used to lookup associated toxics. CARB’ s speciation profiles for industrial natural gas combustion processes are pre sented in Table 8. Particulate matter profile #123 is applied to REIC 050-040-0110 -0000 (Industrial stationary IC engines, natural gas). Particulate matter profile #120 is applied to REIC 050-995- 0110-0000 (Industrial natural gas combustion, unspe cified).

Table 8. CARB chemical speciation profiles for 050 -040-0110-0000, 050-995-0110-0000.

Fractions Profile Description ARB PM
Profile# PM 10 PM 2.5 Stationary I.C. Engine - Natural Gas 123 0.994 0.99 2
Gaseous Material Combustion 120 1 1



## XIII. Assessment Of Methodology

This area source estimate relies on point source an d total District consumption of natural gas to determine area source consumption. It is important that both inventories be accurate and complete.

Although all internal combustion engines less than 50 horsepower are assumed to be reciprocating engines, there are proposals for microturbines within the District for use in the future. However, these microturbines ar e not expected to make a significant impact on the area source estimation.

The manner by which the EIA broke down the natural gas usage in the manufacturing sector (EIA, 1994) is used as a surro gate for the assignment of industrial natural gas consumption to devices. Thi s is based on a national study performed in 1994 and representing the manufacturin g sector only. Future research or studies could lead to a more accurate and up-to- date depiction of the natural gas consumption in the industrial sector. Table 7. CARB chemical speciation profiles for 050

- 040

- 0110

- 0000, 050

- 995

- 0110

- 0000.

Fractions Profile Description ARB Organic
Gas Profile# ROG VOC Internal Combustion Engines - Reciprocating - Natural Gas 719 0.091428 0.091428

External Combustion Boiler - Natural Gas 3 0.422181 0.422181050 – Industrial Natural Gas Combustion

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## XIV. Emissions

Following is the 2006 area source emissions invento ry for REIC 050-040-0110-0000 (Industrial Stationary - I.C. Engines - Natural Gas ) and 050-995-0110-0000 (Industrial Natural Gas Combustion - Unspecified) e stimated by this methodology. Emissions are reported for each county in the Distr ict.

Table 9. Area source emissions for industrial natu ral gas combustion. Emissions (tons/year) County NOx CO SOx VOC (1) PM 10 (2)

INDUSTRIAL STATIONARY - I.C. ENGINES - NATURAL GAS
Fresno 82.35 54.14 0.28 0.45 0.97
Kern (3) 102.88 67.63 0.35 0.56 1.21 Kings 18.85 12.39 0.06 0.10 0.22
Madera 44.23 29.08 0.15 0.24 0.52
Merced 47.85 31.46 0.16 0.26 0.56 San Joaquin 35.50 23.34 0.12 0.19 0.42
Stanislaus 44.35 29.15 0.15 0.24 0.52
Tulare 37.29 24.52 0.13 0.20 0.44

TOTAL 413.3 271.71 1.4 2.24 4.86

INDUSTRIAL NATURAL GAS COMBUSTION (UNSPECIFIED)
Fresno 133.43 112.08 0.80 7.34 6.14
Kern (3) 166.70 140.03 1.00 9.17 7.67 Kings 30.55 25.66 0.18 1.68 1.41
Madera 71.67 60.20 0.43 3.94 3.30
Merced 77.54 65.13 0.47 4.26 3.57 San Joaquin 57.52 48.32 0.35 3.16 2.65
Stanislaus 71.86 60.36 0.43 3.95 3.31
Tulare 60.43 50.76 0.36 3.32 2.78

TOTAL 669.7 562.54 4.02 36.82 30.83 (1) The District only reports ROG to ARB. As noted in Section XII, ROG is the
same as VOC. (2) At this time, the District does not calculate P M2.5 emissions. PM2.5 emissions can be estimated using the speciation profiles foun d in Section XII. (3) Includes both the Valley and non-Valley portion s of Kern County.050 – Industrial Natural Gas Combustion

Page 9 of 17 Rev. Date: 13 June 2006 IndustrialNG2006.doc Rev. By: K Thao 

### Following is the 2006 point source emissions invent ory for REIC 050-040-0110-0000 (Industrial Stationary - I.C. Engines - Natural Gas ) and 050-995-0110-0000 (Industrial Natural Gas Combustion - Unspecified) e stimated by this methodology. Emissions are reported for each county in the Distr ict.

Table 10. Point source emissions for industrial na tural gas combustion. Emissions (tons/year) County NOx CO SOx VOC (1) PM 10 (2)

INDUSTRIAL STATIONARY I.C. ENGINES NG (050-040-0110 -0000)
Fresno 0.47 0.28 0.23 0.42 0.50
Kern (3) 0.05 1.14 0.00 0.08 0.01 Kings 0.00 0.00 0.00 0.00 0.00
Madera 0.03 0.02 0.00 0.00 0.00
Merced 0.00 0.01 0.00 0.00 0.00 San Joaquin 0.14 0.65 0.00 0.16 0.00
Stanislaus 0.00 0.00 0.00 0.00 0.00
Tulare 0.30 1.64 0.12 0.55 0.32

TOTAL 0.99 3.74 0.35 1.21 0.83 INDUSTRIAL NG COMBUSTION (UNSPECIFIED) (050-995-011 0-0000)
Fresno 106.03 133.03 11.44 22.75 23.24
Kern (3) 86.07 70.67 3.54 9.27 12.25 Kings 47.13 57.01 4.46 10.29 13.29
Madera 162.46 41.47 7.71 10.34 10.82
Merced 96.05 166.34 6.76 15.32 16.51 San Joaquin 78.88 91.45 2.84 13.17 12.55
Stanislaus 118.50 74.32 7.06 8.71 20.24
Tulare 83.40 137.49 12.35 13.43 16.72

TOTAL 778.52 771.78 56.16 103.28 125.62 (1) The District only reports ROG to ARB. As noted in Section XII, ROG is the same
as VOC. (2) At this time, the District does not calculate P M2.5 emissions. PM2.5 emissions can be estimated using the speciation profiles foun d in Section XII. (3) Includes only the Valley portion of Kern County

.050 – Industrial Natural Gas Combustion

Page 10 of 17 Rev. Date: 13 June 2006 IndustrialNG2006.doc Rev. By: K Thao 

### Following is the 2006 total unreconciled (point sou rce plus area source) emissions inventory for REIC 050-040-0110-0000 (Industrial St ationary - I.C. Engines - Natural Gas) and 050-995-0110-0000 (Industrial Natural Gas Combustion - Unspecified) estimated by this methodology. Emissions are repor ted for each county in the
District.

Table 11. Total emissions for industrial natural ga s combustion. Emissions (tons/year) County NOx CO SOx VOC (1) PM 10 (2)

INDUSTRIAL STATIONARY I.C. ENGINES NG (050-040-0110 -0000)
Fresno 82.82 54.42 0.51 0.87 1.47
Kern (3) 102.93 68.77 0.35 0.64 1.22 Kings 18.85 12.39 0.06 0.10 0.22
Madera 44.26 29.10 0.15 0.24 0.52
Merced 47.85 31.46 0.16 0.26 0.57 San Joaquin 35.64 23.99 0.12 0.35 0.42
Stanislaus 44.35 29.15 0.15 0.24 0.52
Tulare 37.59 26.16 0.25 0.75 0.76

TOTAL 414.29 275.44 1.75 3.45 5.7 INDUSTRIAL NG COMBUSTION (UNSPECIFIED) (050-995-011 0-0000)
Fresno 239.46 245.11 12.24 30.09 29.38
Kern (3) 252.77 210.70 4.54 18.44 19.92 Kings 77.68 82.67 4.64 11.97 14.70
Madera 234.13 101.67 8.14 14.28 14.12
Merced 173.59 231.47 7.23 19.58 20.08 San Joaquin 136.40 139.77 3.19 16.33 15.20
Stanislaus 190.36 134.68 7.49 12.66 23.55
Tulare 143.83 188.25 12.71 16.75 19.50

TOTAL 1,448.22 1,334.32 60.18 140.1 156.45 (1) The District only reports ROG to ARB. As noted in Section XII, ROG is the same
as VOC. (2) At this time, the District does not calculate P M2.5 emissions. PM2.5 emissions can be estimated using the speciation profiles foun d in Section XII. (3) Includes both the Valley and non-Valley portion s of Kern County.050 – Industrial Natural Gas Combustion

Page 11 of 17 Rev. Date: 13 June 2006 IndustrialNG2006.doc Rev. By: K Thao 

### Following is the net change in total unreconciled e missions between this update (2006 inventory year) and the previous update (2005 inventory year) for REIC 050- 040-0110-0000 (Industrial Stationary - I.C. Engines - Natural Gas) and 050-995- 0110-0000 (Industrial Natural Gas Combustion - Unsp ecified) estimated by this methodology. The change in emissions are reported for each county in the District.

Table 12. Net emissions change for industrial natu ral gas combustion

(2006-2005). Emissions (tons/year) County NOx CO SOx VOC PM 10 INDUSTRIAL STATIONARY I.C. ENGINES NG (050-040-0110 -0000)
Fresno 59.98 39.57 0.42 0.73 1.20
Kern 11.07 8.37 0.04 0.13 0.14 Kings 18.85 12.39 0.06 0.10 0.22
Madera -0.18 -0.07 -0.00 -0.00 -0.00
Merced 47.85 31.46 0.16 0.26 0.57 San Joaquin 35.39 23.74 0.09 0.31 0.34
Stanislaus 38.93 25.59 0.13 0.21 0.46
Tulare -23.59 -14.23 0.03 0.40 0.04

TOTAL 188.3 126.82 0.93 2.14 2.97 INDUSTRIAL NG COMBUSTION (UNSPECIFIED) (050-995-011 0-0000)
Fresno 88.79 102.73 4.09 12.86 9.51
Kern 19.28 -28.79 0.92 3.51 -0.45 Kings 40.94 34.69 2.10 5.82 7.38
Madera 14.78 5.86 1.22 2.64 -0.08
Merced 95.56 59.11 3.23 12.96 9.58 San Joaquin -384.71 64.72 -263.70 6.91 3.86
Stanislaus 69.23 26.71 0.39 4.73 5.11
Tulare -23.92 -22.19 4.11 0.60 -0.85

TOTAL -80.05 242.84 -247.64 50.03 34.06



## XV. Revision History

2006. The methodology was reformatted to the new Di strict standard, and process rates were updated. A correction was made to the I C engine emission factors
which resulted in an increase in emissions for this source category. The reduction in industrial unspecified natural gas com bustion emissions in San Joaquin county is due to moving glass furnace emiss ions to the Glass Manufacturing

source category .

2005. This is a new District methodology based upon one developed by Sonoma Technology as part of the Central California Ozone Study.050 – Industrial Natural Gas Combustion

Page 12 of 17 Rev. Date: 13 June 2006 IndustrialNG2006.doc Rev. By: K Thao 

## XVI. Update Schedule

In an effort to provide inventory information to AR B and other District programs and maximize limited resources, the District has develo ped an update cycle based on emissions within the source category as shown in Ta ble 13.

Table 13. Area source update frequency criteria.

Total Emissions (Tons/Day) Update Cycle (Years)

<1 4
>1 and <= 2.5 3
>2.5 and <=5 2

>5 1



### Since NOx emissions exceed 5 tons per day, these ar ea source estimates will be updated every year.

Table 14. Industrial natural gas combustion method ology update frequency.

EIC Frequency

(In years) Source of Emissions

(Point Source Inventory / Data

Gathering) 050-040-0110-0000 1 Point Source Inventory / Data G athering 050-995-0110-0000 1 Point Source Inventory / Data G athering



## XVII. References

1. E.H. Pechan and Associates. 2005. Appendix A: Industrial fuel combustion, Natural gas. In: Documentation for the draft 2002 nonpoint source national emission inventory for criteria and hazardous air p ollutants (March 2005 version). Prepared for the Emissions Inventory Group (D205-01 ), U.S. Environmental Protection Agency. Pages A88-A90.

2. Energy Information Administration. 1994. How c hanging energy markets affect manufacturing. <http://www.eia.doe.gov/emeu/mecs/mecs94/special_to pics/restructuring_mecs9
4.htm>

3. Gough, A., 2007. E-mailed 2006 natural gas del ivery data from the California Energy Commission, Sacramento, CA to Yu Vu, San Joa quin Valley Unified APCD. (May 30, 2007).

4. Sonoma Technology, Inc. 2002. Central Californ ia ozone study, Attachment A: Natural gas combustion. <http://www.arb.ca.gov/ei/ areasrc/ccosmethods.html>050 – Industrial Natural Gas Combustion

Page 13 of 17 Rev. Date: 13 June 2006 IndustrialNG2006.doc Rev. By: K Thao 

### 5. United States Environmental Protection Agency (1 998). AP 42 Section 1.4: Natural gas combustion. U.S. GPO, Washington D.C. <http://www.epa.gov/ttn/chief/ap42/ch01/final/c01s0 4.pdf>

6. United States Environmental Protection Agency (2 000a). AP 42 Section 3.1: Stationary Gas Turbines. U.S. GPO, Washington D.C. <http://www.epa.gov/ttn/chief/ap42/ch03/final/c03s0 1.pdf>

7. United States Environmental Protection Agency (2 000b). AP 42 Section 3.2: Natural gas-fired reciprocating engines. U.S. GPO, Washington D.C. <http://www.epa.gov/ttn/chief/ap42/ch03/final/c03s0 2.pdf>



## XVIII. Appendices

Appendix A. Inventory Reconciliation Codes050 – Industrial Natural Gas CombustionPage 14 of 17Rev. Date: 13 June 2006IndustrialNG2006.docRev. By: K ThaoXIX. Appendix A. Inventory Reconciliation CodesTable 15. EIC, SCC and SIC codes in the District’s2006 point source inventory that reconciled to REIC 050-040-0110-000.EICSCCPoint Source TypeSIC50-040-0110-0000 20200202INTERNLCOMBUSTION - INDUSTRIAL - NATURAL GAS -RECIPROCATING3069, 3086, 3221, 3471,3511, 399950-045-0110-0000 20200201 INTERNLCOMBUSTION - INDUSTRIAL - NATURAL GAS - TURBINE 306152-040-0110-0000 20200202INTERNLCOMBUSTION - INDUSTRIAL - NATURAL GAS -RECIPROCATING2022, 2033, 2037, 2099Table 16. EIC, SCC and SIC codes in the District’s2006 point source inventory that reconciled to REIC 050-995-0110-000.EICSCCPoint Source TypeSIC10200601 EXTCOMB BOILER - INDUSTRIAL - NATURAL GAS- >100MMBTU/HR 1389, 1442, 2951, 356110200602 EXTCOMB BOILER - INDUSTRIAL - NATURAL GAS- 10-100MMBTU/HR2273, 2499, 2621, 2631,2653, 2656, 2759, 2819,2869, 2873, 2879, 2951,2952, 3061, 3086, 3089,3111, 3221, 3273, 3295,3296, 3479, 3713, 769450-005-0110-000010200603 EXTCOMB BOILER - INDUSTRIAL - NATURAL GAS- <10MMBTU/HR2599, 2621, 2653, 2759,2819, 2851, 2875, 2879,2952, 3061, 3069, 3086,3089, 3211, 3272, 3273,3296, 3315, 3321, 3325,3369, 3411, 3442, 3471,3479, 3483, 3537, 3561,3613, 3663, 3679, 3713,3714, 3728, 3842, 633150-005-0240-0000 10201201EXTCOMB BOILER - INDUSTRIAL - SLD WASTE-SPECIFY - SPEC MATCOMM FLD8733050 – Industrial Natural Gas CombustionPage 15 of 17Rev. Date: 13 June 2006IndustrialNG2006.docRev. By: K ThaoEICSCCPoint Source TypeSIC30190003CHEMICAL MFG - FUEL-FIRED EQPMNT - PROCESS HEATERS- NATGAS723, 2023, 2816, 2819,3089, 769430390003PRIMARY METALS - FUEL-FIRED EQPMNT - PROCESS HEATERS -NAT GAS349930390023 PRIMARY METALS - FUEL-FIRED EQPMNT - FLARES - NAT GAS 131130490003SECONDARY METALS - FUEL-FIRED EQPMNT - PROCESS HEATERS- NAT GAS3325, 3411, 3441, 3442,3444, 3479, 372430500206PETROLEUM INDRY - ASPHALT CONCRETE - ASPHALT HEATER-NATURAL GAS2951, 295230590003MINERAL PRODUCTS - FUEL-FIRED EQPMNT - PROCESS HEATERS -NAT GAS2759, 2951, 329530790003WOOD PRODUCTS - FUEL FIRED EQPMNT - PROCESS HEATERS-NAT GAS2431, 243430890003RUBBER/PLASTICS - FUEL FIRED EQPMNT - PROCESS HEATERS -NAT GAS308630990003FABRICATED METALS - FUEL FIRED EQPMNT - PROCESS HEATERS- NAT GAS344839900601INDUSTRIAL PROCES - MIS IND-FUEL EQPT - PROCESSHTER/FURNACE - NATURAL GAS2657, 3411, 349550-010-0110-000039990003INDUSTRIAL PROCES - MIS IND-FUEL EQPT - PROCESS HEATERS -NAT GAS1459, 2657, 2679, 2813,2952, 3089, 3411, 3479,367950-012-0110-0000 40201001ORGANIC SOLVENT - SURFACE COATING - OVEN HEATER -NATURAL GAS2431, 2656, 2674, 2732,3088, 3312, 3354, 3399,3411, 3441, 3442, 3444,3479, 3493, 3495, 3499,3585, 3621, 3663, 3713,372839000689INDUSTRIAL PROCES - INPROCESS FUEL - NATURAL GAS -NOTCLASSIFIED2099, 3221, 3411, 3479,394939000699INDUSTRIAL PROCES - INPROCESS FUEL - NATURAL GAS -NOTCLASSIFIED1459, 2951, 3211, 3296,355550-070-0110-000039092050INDUSTRIAL PROCES - INPROCESS FUEL - NATURAL GAS -WITHDRAWAL LOSS1321050 – Industrial Natural Gas CombustionPage 16 of 17Rev. Date: 13 June 2006IndustrialNG2006.docRev. By: K ThaoEICSCCPoint Source TypeSIC30490033SECONDARY METALS - FUEL-FIRED EQPMNT - FURNACES - NATGAS2952, 3363, 336450-995-0110-000030505020MINERAL PRODUCTS - NONMETALLIC MINRL - ASPHALT HEATER -NATURAL GAS144210200601 EXTCOMB BOILER - INDUSTRIAL - NATURAL GAS- >100MMBTU/HR723, 2023, 2032, 2033,2034, 2063, 2084, 769410200602 EXTCOMB BOILER - INDUSTRIAL - NATURAL GAS- 10-100MMBTU/HR179, 241, 2011, 2015,2022, 2023, 2024, 2026,2032, 2033, 2034, 2037,2038, 2041, 2043, 2044,2046, 2047, 2048, 2061,2063, 2066, 2068, 2076,2077, 2079, 2084, 2086,2096, 209952-005-0110-000010200603 EXTCOMB BOILER - INDUSTRIAL - NATURAL GAS- <10MMBTU/HR179, 2011, 2015, 2023,2024, 2026, 2032, 2033,2034, 2037, 2041, 2043,2047, 2048, 2051, 2068,2076, 2077, 2084, 2087,2098, 2099, 287430290003FOOD/AGRICULTURE - FUEL-FIRED EQPMNT - PROCESS HEATERS -NAT GAS191, 723, 724, 2011,2015, 2022, 2023, 2026,2033, 2034, 2041, 2043,2044, 2048, 2051, 2066,2068, 2077, 2095, 2096,2099, 514352-010-0110-000030291001FOOD/AGRICULTURE - FUEL-FIRED EQPMNT - BROILING FOOD -NATURAL GAS201352-020-0110-0000 10500206EXTCOMB BOILER - SPACE HEATER - COMMERCL-INSTUTNL -NATURAL GAS209939000689INDUSTRIAL PROCES - INPROCESS FUEL - NATURAL GAS -NOTCLASSIFIED2051, 206352-070-0110-000039000699INDUSTRIAL PROCES - INPROCESS FUEL - NATURAL GAS -NOTCLASSIFIED2022, 2043050 – Industrial Natural Gas CombustionPage 17 of 17Rev. Date: 13 June 2006IndustrialNG2006.docRev. By: K ThaoEICSCCPoint Source TypeSIC30490013SECONDARY METALS - FUEL-FIRED EQPMNT - INCINERATORS-NAT GAS3411, 769430790013WOOD PRODUCTS - FUEL FIRED EQPMNT - INCINERATORS -NATGAS922330890013RUBBER/PLASTICS - FUEL FIRED EQPMNT - INCINERATORS- NATGAS3086, 308930990013FABRICATED METALS - FUEL FIRED EQPMNT - INCINERATORS -NAT GAS4612130-130-0110-000040290013ORGANIC SOLVENT - SURFACE COATING - INCIN./AFTERBURNER -NAT GAS2752, 3411130-132-0110-0000 39990023 INDUSTRIAL PROCES - MISIND-FUEL EQPT - FLARES - NAT GAS 2869