APPENDIX A
Air Quality and Greenhouse Gas Emissions Documentation
Phillips 66 Propane Recovery Project Final Environmental Impact Report
November 2013
Appendix A Air Quality and Greenhouse Gas Emissions Documentation
APPENDIX A.1
Air Quality Supplement
Phillips 66 Propane Recovery Project Final Environmental Impact Report
November 2013
AIR QUALITY SUPPLEMENT
Rodeo Refinery Rodeo, California
Rodeo Propane Recovery Project Air Quality Supplement
November 2012
TABLE OF CONTENTS
LIST OF TABLES
i
1.0
INTRODUCTION
1
2.0
PROJECT EMISSIONS
2
2.1
4 4 5 6
EMISSIONS CHANGES FROM PRP 2.1.1 Propane Recovery Unit Boiler 2.1.2 Fugitive Component Emissions 2.1.3 Transportation Emissions
3.0
CONSTRUCTION PHASE EMISSIONS
11
4.0
ANSWERS TO AIR QUALITY DATA REQUESTS
15
5.0
REFERENCES
17
ATTACHMENT 1 – AIR EMISSIONS CALCULATIONS
LIST OF TABLES Table 1
Summary of Annual PRP Emissions
2
Table 2
Summary of Daily PRP Emissions
3
Table 3
Criteria Pollutant Emissions from Boiler
5
Table 4
Fugitive Component Count, Emission Factors and POC Emissions
6
Table 5
Locomotive Emissions
8
Table 6
Commuter Trip Criteria Pollutant Emissions
10
Table 7
Daily Maximum Construction Criteria Pollutant Emissions
12
Table 8
Annual Maximum Construction Criteria Pollutant Emissions
13
i
1.0
INTRODUCTION
This supplemental data document provides information to assist in the determination of air quality impacts from proposed operation of the Propane Recovery Project (PRP) at the Phillips 66 Rodeo Refinery (Refinery). Emissions changes have been estimated for all sources included in the project, including stationary and mobile sources, and emissions associated with construction. More details for the operational emissions of on-site stationary sources will be submitted to the Bay Area Air Quality Management District (BAAQMD) in the Rodeo Propane Recovery Project BAAQMD Authority to Construct and Minor Revision to Major Facility Review Permit Application (Permit Application). The Refinery has recently shut down operation of one of its large process heaters, the U240 B-401 process heater. There is a resulting emissions decrease for combustion pollutants from this shutdown that will be accounted for as part of this project.
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2.0
PROJECT EMISSIONS
This section describes the changes in criteria pollutant emissions associated with the PRP. Changes in toxic air contaminant emissions resulting from these projects are described in the Rodeo Propane Recovery Project Public Health Supplement. Tables 1 and 2 below summarize annual and daily criteria pollutant emissions from all PRP sources. The stationary sources of emissions include a boiler firing a combination of refinery fuel gas and natural gas, and fugitive component leaks in piping resulting from railcar loading rack modifications. Indirect emissions will result from additional railcars needed for propane/butane transport and worker commute vehicles. Table 1
Summary of Annual PRP Emissions Emissions (tons/year) NOx
CO
PM10
PM2.5
SO2
POC
3.7
4.5
4.6
4.6
7.6
3.3
---
---
---
---
---
4.6
Locomotive
10.2
1.8
0.3
0.3
0.0
0.5
On-road Vehicles Exhaust
0.002
0.27
Neg.
Neg.
Neg.
0.003
On-road Vehicles Fugitives
---
---
0.002
0.001
---
---
Refinery Fuel Gas Hydrotreating
---
---
---
---
-180
---
Total Incremental PRP Emissions
13.9
6.4
4.8
4.8
-172.4
8.4
Available Emission Reductions from B-401 Shutdown2
-13.9
---
---
---
---
---
0
6.4
4.8
4.8
-172.4
8.4
10.0
N/A
15.0
10.0
N/A
10.0
No
No
No
No
No
No
Source Boiler
1
Fugitive Components
1
Total Net Post-PRP Emissions CEQA Threshold
3
Significant Impact (Yes/No)
More details in Rodeo Propane Recovery Project BAAQMD Authority to Construct and Minor Revision to Major Facility Review Permit Application. 2 Emission reductions from shutdown of B-401 heater that will be applied to the PRP (some emission reductions from this shutdown are applied to another unrelated project). 3 Taken from thresholds presented in December 2011 version of BAAQMD California Environmental Quality Act Air Quality Guidelines (BAAQMD 2011). 1
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Table 2
Summary of Daily PRP Emissions
Source
Emissions (lb/day) NOx
CO
PM10
PM2.5
SO2
POC
20.4 ‐‐‐ 79.0 0.0 ‐‐‐
24.8 ‐‐‐ 14.0 0.1 ‐‐‐
25.0 ‐‐‐ 2.0 0.0 0.0
25.0 ‐‐‐ 1.9 0.0 0.0
41.7 ‐‐‐ 0.1 0.0 ‐‐‐
18.1 25.1 3.8 0.0 ‐‐‐
Refinery Fuel Gas Hydrotreating
‐‐‐
‐‐‐
‐‐‐
‐‐‐
-986
‐‐‐
Total Incremental PRP Emissions
99.4
39.0
27.1
27.0
‐944
47.0
‐99.4
‐‐‐ 39.0 N/A No
‐‐‐ 27.1
‐‐‐ 27.0 54.0 No
‐‐‐ ‐944 N/A No
‐‐‐
1
Boiler Fugitive Components1 Locomotive On‐road Vehicles Exhaust On‐road Vehicles Fugitives
Available Emission Reductions from B‐401 Shutdown2 Total Net Post‐PRP Emissions CEQA Threshold3 Significant Impact (Yes/No)
0 54.0 No
82.0 No
47.0 54.0 No
More details in Rodeo Propane Recovery Project BAAQMD Authority to Construct and Minor Revision to Major Facility Review Permit Application. 2 Emission reductions from shutdown of B-401 heater that will be applied to the PRP (some emission reductions from this shutdown are applied to another unrelated project). 3 Taken from thresholds presented in December 2011 version of BAAQMD California Environmental Quality Act Air Quality Guidelines (BAAQMD 2011). 1
Hydrotreating would remove the sulfur compounds from the light hydrocarbon gases, which would not only clean and improve the quality of the propane and butane products, but would also reduce the sulfur in the remaining light hydrocarbon gases that become part of the RFG system. Hydrotreating would decrease SO2 emissions by at least half, resulting in an SO2 emission decrease of at least 180 tons per year. This is based on SO2 emissions to atmosphere of 364 tons per year from the combustion of Unit 233 refinery fuel gas for the period July 2011 to June 2012. This process would be described in detail in the air quality permit application for submittal to the BAAQMD. The amount of reduction will be quantified further in the air quality permit application to BAAQMD.
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2.1
EMISSIONS CHANGES FROM PRP Installation of new equipment and modifications to existing equipment within the Refinery are planned as part of the PRP. Emissions from these sources were estimated and reported in the PRP BAAQMD Permit Application and summarized in the following discussion.
2.1.1
Propane Recovery Unit Boiler The propane recovery unit requires a new steam boiler rated at 140 MMBtu/hr of heat input. This boiler will be fired on a combination of natural gas and treated refinery fuel gas with total sulfur less than 100 ppmvd (calendar month average). The boiler is subject to best available control technology (BACT) requirements per BAAQMD Rule 2-2-301. Controlled emissions were estimated by converting the proposed limits of 5 ppmv NOx and 10 ppmv CO, both at 3%O2 dry (3-hour average), to emission factors in units of lb/MMBtu. These emission factors for NOx and CO use of an F factor of 8,710 scf exhaust/MMBtu, molar volume of 385.3 dry scf/mole of gas at 68 °F and 1 atm pressure, and heating value of 1,020 Btu/scf for natural gas and 1,340 Btu/scf for refinery fuel gas. SO2 emission factor of 0.0124 lb/MMBTU for treated refinery fuel gas was calculated using the 100 ppm sulfur BACT limit, molecular weight of SO2 and molar volume of 385.3 dry scf/mole of gas at 68 °F and 1 atm pressure. The SO2 emission factor for natural gas combustion is from AP-42 (EPA 1998). Emission factors for PM10, and POC1 for both natural gas and treated refinery fuel gas combustion are from AP-42 (EPA 1998). Hourly mass emission rates for the boiler were determined by multiplying the “pounds per MMBtu” emission factor by the rated maximum heat input of the boiler. Daily and annual mass emissions were calculated based on 24-hour-per-day and 365-day-per-year operation, respectively. Emission rates and estimated mass emissions are summarized in Table 3. Calculation details can be found in Attachment 1, Air Emissions Calculations.
1
BAAQMD term for reactive organic gases (ROG).
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Table 3
Criteria Pollutant Emissions from Boiler Emission Factor Pollutants
Emissions
lb/MMscf
lb/MMbtu
Hourly (lb/hr)
Daily (lb/day)
Annual (tons/yr)
NOx1 CO1 PM10
----7.6
0.0061 0.0074 0.0057
0.85 1.03 0.79
20.4 25 19.1
3.72 4.53 3.48
SO21
---
0.0124
1.74
41.65
7.60
2
POC 5.5 0.0041 0.57 13.8 2.52 1 NO emissions per BACT of 5 ppmv NO @ 3% O (3-hr average). Based on BACT x x 2 determination for S-45 Heater from Clean Fuels Expansion Project. CO emissions per BACT of 10 ppmv CO @ 3% O2 (3-hr average). Based on BACT determination for S-45 Heater from Clean Fuels Expansion Project. SO2 emission factor based on total sulfur content of 100 ppmv. 2 Emission factors obtained from AP-42, Chapter 1.4, Table 1.4-2.
2.1.2
Fugitive Component Emissions New process equipment associated with the PRP will emit fugitive POC from various components including valves, flanges, connectors, pumps, and compressors. The number of new fugitive components for the PRP was estimated based on pre-design drawing hand-count, comparison to existing units, Phillips 66 experience in construction of similar units, and other estimation techniques. Table 3 provides an estimated fugitive component count, combined for all the process units of the PRP. These component counts were used to estimate fugitive POC emissions from the proposed PRP. There will not be any new open-ended lines for sampling or other purposes. Fugitive POC emissions were estimated based on U.S. EPA Correlation Equations as presented in Table IV-3a of the February 1999 California Air Resources Board/California Air Pollution Control Officers Association (CARB/CAPCOA) document entitled California Implementation Guidelines for Estimating Mass Emissions of Fugitive Hydrocarbon Leaks at Petroleum Facilities (CARB/CAPCOA 1999). This document is an accepted BAAQMD method for estimating fugitive emissions. The screening values used for valves, flanges, connectors, pump, and compressors and the corresponding correlation equations are shown in Table 3. The screening value (SV) in each Correlation Equation is consistent with the maximum leak rate allowed under the BAAQMD guidelines as a “BACT-1” level. Table 3 also displays resulting emission ERM
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factors in kg/hr per source. Using the Correlation Equation approach and screening values, the resulting emission factors for each component type are the same for each type of service (gas, light liquid, and heavy liquid). Table 3 summarizes the total fugitive component POC emissions for all of the process units. Calculation details can be found in Attachment 1. Table 4
Fugitive Component Count, Emission Factors and POC Emissions
Component Type/ Service
Correlation Equation
Screening Value, SV1 (ppmv)
Emission Factor (kg/hr/ source)
Component Count
Hourly POC (lb/hr)
Daily POC (lb/ day)
Annual POC (tons/ yr)
Valves/ All
2.27E6*(SV)^0.747
100
7.1E-05
2,810
0.44
10.5
1.92
Connectors/ All
1.53E6*(SV)^0.736
100
4.5E-05
5,620
0.56
13.5
2.46
Pump Seals/ All
5.07E5*(SV)^0.622
100
8.9E-04
16
0.03
0.75
0.14
Other2 (PRVs + Compressors)/ All
8.69E6(SV)^0.642
100
1.7E-04
44
0.02
0.39
0.07
Total - All Components
---
---
---
8,490
1.05
25.1
4.58
1 2
Screening Values are consistent with the maximum allowed by BAAQMD guidelines for BACT. The “other” component type includes instruments, loading arms, pressure relief valves, vents, compressors, dump lever arms, diaphragms, drains, hatches, meters, and polished rods stuffing boxes. This “others” component type should be applied for any component type other than connectors, flanges, open-ended lines, pumps, or valves.
2.1.3
Transportation Emissions The implementation of the proposed project would change the quantity of raw materials, products, and waste into and out of the refinery. These materials will be transported by rail car. Rail traffic will increase by up to 12 railcars per day on annual average, with a maximum increase of up to 20 on any given day. Incremental emission estimates from additional railcars required for this project are presented below. Rail Shipments An estimated 12 additional tank cars per day on an annual average will be required to ship the propane and butane recovered by PRP, resulting in a total of 16 railcars when added to the baseline, on an annual average. On any given day, the maximum number of additional railcars could increase to 20, resulting in a total of 24 when added to the baseline. Emissions ERM
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associated with increased locomotive engine load due to these additional tank cars on existing train trips were calculated within the BAAQMD for the purpose of estimating Project emissions increases. Criteria pollutant emission factors for locomotives, in grams per gallon fuel consumed, were obtained from the EPA document – Emission Factors for Locomotives, Technical Highlights, EPA-420-F-09-025, April 2009. Emission factors for the year 2015, when the project first becomes operational, were used in the calculation. Quantity of fuel consumed for line haul was estimated by dividing the product of gross weight hauled and track length by a fuel consumption index in terms of gross ton-miles per gallon, as derived from Union Pacific (UP) and Burlington Northern Santa Fe (BNSF) data. Gross weight hauled includes weight of the compressed gas freight and tare weight of tank cars. For the total track length travelled within the BAAQMD, 50% of the trains are assumed to travel on the UP routing and 50% on the BNSF routing. The lengths of the UP and BNSF routes from the Refinery to the southern and eastern borders of the BAAQMD, respectively, were measured using Google Earth. To account for switching emissions, one hour of activity per day at the Phillips 66 Refinery was assumed. Table 4 presents a summary of locomotive emissions. Attachment 1 presents the details of the railcar emissions estimates, as well as for other operational and construction components of the proposed project. Greenhouse gas emissions, expressed as carbon dioxide equivalent (CO2e), and fuel consumption information are also presented in Attachment 1 for use in the Rodeo Propane Recovery Project Greenhouse Gas Supplement and Rodeo Propane Recovery Project Energy Supplement.
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Table 5
Locomotive Emissions Annual Average: 2015 Line Haul Emissions Within BAAQMD Emissions (tons/year)
Track
Operation Type
CO
ROG
NOx
SOx
PM10
PM2.5
Phillips66 to Richmond Yard
Small Line Haul
0.24
0.13
2.46
0.00
0.06
0.05
Richmond Yard to BAAQMD Border
Large Line Haul
1.52
0.34
7.39
0.01
0.19
0.19
1.76
0.47
9.84
0.01
0.25
0.24
Total Line Haul Emissions
Annual Average: 2015 Total Switching Emissions Emissions (tons/year) Track Phillips66
Operation Type
CO
ROG
NOx
SOx
PM10
PM2.5
Switch
0.04
0.02
0.33
0.00
0.01
0.01
0.04
0.02
0.33
0.00
0.01
0.01
Total Switch Emissions
Average Daily: 2015 Line Haul Emissions Within BAAQMD Emissions (lb/day) Track
Operation Type
CO
ROG
NOx
SOx
PM10
PM2.5
Phillips66 to Richmond Yard
Small Line Haul
1.84
0.97
18.97
0.01
0.43
0.42
Richmond Yard to BAAQMD Border
Large Line Haul
11.78
2.65
57.06
0.04
1.50
1.46
13.62
3.63
76.03
0.05
1.94
1.88
Total Line Haul Emissions
Average Daily: 2015 Total Switching Emissions Emissions (lb/day) Track Phillips66
Operation Type
CO
ROG
NOx
SOx
PM10
PM2.5
Switch
0.38
0.18
2.98
0.00
0.07
0.06
0.38
0.18
2.98
0.00
0.07
0.06
Total Switch Emissions Emission Factors for Locomotives, EPA-420-F-09-025, April 2009
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On-Road Emissions As a result of the PRP, the number of commute vehicles will increase by two per day. Most of this travel will occur on paved roads. Criteria pollutant emissions due to these additional motor vehicle trips were estimated using EMFAC2011 for the exhaust pollutants. The predictive emission factor equation and defaults for paved road dust emissions are provided in AP-42, Chapter 13.2.1, Paved Roads. Calculations are shown in Attachment 1.
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Table 6
Commuter Trip Criteria Pollutant Emissions
Vehicle Type Commuter Vehicles
Vehicle Type Commuter Vehicles
ERM
Number of Trips
Round Trip Length1
trips/day
mile/round-trip
CO
ROG
NOx
SOx
Exhaust PM10
Fugitive PM10
Diesel PM
Exhaust PM2.5
Fugitive PM2.5
2
19
0.148
0.015
0.013
0.000
0.000
0.011
0.000
0.000
0.003
Number of Trips
Round Trip Length1
trips/year
mile/round-trip
CO
ROG
NOx
SOx
Exhaust PM10
Fugitive PM10
Diesel PM
Exhaust PM2.5
Fugitive PM2.5
730
19
0.027
0.003
0.002
0.000
0.000
0.002
0.000
0.000
0.001
Daily Emission Within BAAQMD (lb/day)
Annual Emissions Within BAAQMD (tons/year)
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3.0
CONSTRUCTION PHASE EMISSIONS
The construction period would be approximately 18 months in duration, with the peak activity occurring in 2014. Construction emissions were calculated for all phases of construction, including demolition, grading, structural, painting, and paving. Emission factors from the CARB OFFROAD model, the EMFAC2011 model, and AP-42 were used to calculate emissions from heavy equipment exhaust and earthmoving activities. Maximum daily and annual emissions are presented in Tables 6 and 7, respectively. Calculation details are presented in Attachment 1.
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Table 7
Daily Maximum Construction Criteria Pollutant Emissions Daily ROG Emissions (lb/day)
Source
Month 1
Month 2
Month 3
Month 4
Month 5
Month 6
Month 7
Month 8
Month 9
Month 10
Month 11
Month 12
Month 13
Month 14
Month 15
Month 16
Month 17
Month 18
Onsite Equipment & Vehicles
4.94
4.94
4.94
4.94
4.94
4.94
7.39
7.39
7.39
7.39
7.39
7.39
7.39
7.39
7.39
7.39
7.39
7.39
Fugitives
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
30.22
Offsite Vehicles
3.77
3.77
3.77
3.39
3.39
3.39
3.39
3.39
3.39
3.39
3.39
3.39
3.39
3.39
3.39
3.39
3.39
3.39
Total
8.70
8.70
8.70
8.33
8.33
8.33
10.78
10.78
10.78
10.78
10.78
10.78
10.78
10.78
10.78
10.78
10.78
41.01
Maximum Daily
41.01 Daily CO Emissions (lb/day)
Source
Month 1
Month 2
Month 3
Month 4
Month 5
Month 6
Month 7
Month 8
Month 9
Month 10
Month 11
Month 12
Month 13
Month 14
Month 15
Month 16
Month 17
Month 18
Onsite Equipment & Vehicles
24.24
24.24
24.24
24.24
24.24
24.24
30.27
30.27
30.27
30.27
30.27
30.27
30.27
30.27
30.27
30.27
30.27
30.27
Offsite Vehicles
34.03
34.03
34.03
32.32
32.32
32.32
32.32
32.32
32.32
32.32
32.32
32.32
32.32
32.32
32.32
32.32
32.32
32.32
Total
58.27
58.27
58.27
56.56
56.56
56.56
62.58
62.58
62.58
62.58
62.58
62.58
62.58
62.58
62.58
62.58
62.58
62.58
Maximum Daily
62.58 Daily NOx Emissions (lb/day)
Source
Month 1
Month 2
Month 3
Month 4
Month 5
Month 6
Month 7
Month 8
Month 9
Month 10
Month 11
Month 12
Month 13
Month 14
Month 15
Month 16
Month 17
Month 18
Onsite Equipment & Vehicles
37.79
37.79
37.79
37.79
37.79
37.79
48.40
48.40
48.40
48.40
48.40
48.40
48.40
48.40
48.40
48.40
48.40
48.40
Offsite Vehicles
21.52
21.52
21.52
10.22
10.22
10.22
10.22
10.22
10.22
10.22
10.22
10.22
10.22
10.22
10.22
10.22
10.22
10.22
Total
59.31
59.31
59.31
48.01
48.01
48.01
58.62
58.62
58.62
58.62
58.62
58.62
58.62
58.62
58.62
58.62
58.62
58.62
Maximum Daily
59.31 Daily SOx Emissions (lb/day)
Source
Month 1
Month 2
Month 3
Month 4
Month 5
Month 6
Month 7
Month 8
Month 9
Month 10
Month 11
Month 12
Month 13
Month 14
Month 15
Month 16
Month 17
Month 18
Onsite Equipment & Vehicles
0.05
0.05
0.05
0.05
0.05
0.05
0.06
0.06
0.06
0.06
0.06
0.06
0.06
0.06
0.06
0.06
0.06
0.06
Offsite Vehicles
0.08
0.08
0.08
0.07
0.07
0.07
0.07
0.07
0.07
0.07
0.07
0.07
0.07
0.07
0.07
0.07
0.07
0.07
Total
0.13
0.13
0.13
0.11
0.11
0.11
0.13
0.13
0.13
0.13
0.13
0.13
0.13
0.13
0.13
0.13
0.13
0.13
Maximum Daily
0.13 Daily PM10 Emissions (lb/day)
Source
Month 1
Month 2
Month 3
Month 4
Month 5
Month 6
Month 7
Month 8
Month 9
Month 10
Month 11
Month 12
Month 13
Month 14
Month 15
Month 16
Month 17
Month 18
Onsite Equipment & Vehicles
2.70
2.70
2.70
2.70
2.70
2.70
3.31
3.31
3.31
3.31
3.31
3.31
3.31
3.31
3.31
3.31
3.31
3.31
Fugitives
12.29
12.29
12.29
8.85
8.85
8.85
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
Offsite Vehicles
2.69
2.69
2.69
2.39
2.39
2.39
2.39
2.39
2.39
2.39
2.39
2.39
2.39
2.39
2.39
2.39
2.39
2.39
Total
17.68
17.68
17.68
13.95
13.95
13.95
5.71
5.71
5.71
5.71
5.71
5.71
5.71
5.71
5.71
5.71
5.71
5.71
Maximum Daily
17.68
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Daily PM2.5 Emissions (lb/day) Month 1
Month 2
Month 3
Month 4
Month 5
Month 6
Month 7
Month 8
Month 9
Month 10
Month 11
Month 12
Month 13
Month 14
Month 15
Month 16
Month 17
Month 18
Onsite Equipment & Vehicles
2.24
2.24
2.24
2.24
2.24
2.24
2.91
2.91
2.91
2.91
2.91
2.91
2.91
2.91
2.91
2.91
2.91
2.91
Fugitives
4.80
4.80
4.80
4.28
4.28
4.28
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
Offsite Vehicles
1.04
1.04
1.04
0.82
0.82
0.82
0.82
0.82
0.82
0.82
0.82
0.82
0.82
0.82
0.82
0.82
0.82
0.82
Total
8.08
8.08
8.08
7.34
7.34
7.34
3.72
3.72
3.72
3.72
3.72
3.72
3.72
3.72
3.72
3.72
3.72
3.72
Maximum Daily
8.08
Source
Table 8
Annual Maximum Construction Criteria Pollutant Emissions Annual ROG Emissions (tpy)
Source Month 1
Month 2
Month 3
Month 4
Month 5
Month 6
Month 7
Month 8
Month 9
Month 10
Month 11
Month 12
Month 13
Month 14
Month 15
Month 16
Month 17
Month 18
Onsite Equipment & Vehicles
0.81
0.84
0.87
0.89
0.92
0.95
0.98
0.89
0.81
0.73
0.65
0.57
0.49
0.41
0.33
0.24
0.16
0.08
Fugitives
0.00
0.00
0.00
0.00
0.00
0.00
0.33
0.33
0.33
0.33
0.33
0.33
0.33
0.33
0.33
0.33
0.33
0.33
Offsite Vehicles
0.46
0.46
0.45
0.45
0.45
0.45
0.45
0.41
0.37
0.34
0.30
0.26
0.22
0.19
0.15
0.11
0.07
0.04
Total
1.27
1.30
1.32
1.34
1.37
1.40
1.76
1.64
1.52
1.40
1.28
1.16
1.04
0.93
0.81
0.69
0.57
0.45
Maximum Annual
1.76 Annual CO Emissions (tpy)
Source Month 1
Month 2
Month 3
Month 4
Month 5
Month 6
Month 7
Month 8
Month 9
Month 10
Month 11
Month 12
Month 13
Month 14
Month 15
Month 16
Month 17
Month 18
Onsite Equipment & Vehicles
3.60
3.66
3.73
3.80
3.86
3.93
4.00
3.66
3.33
3.00
2.66
2.33
2.00
1.66
1.33
1.00
0.67
0.33
Offsite Vehicles
4.32
4.30
4.28
4.27
4.27
4.27
4.27
3.91
3.56
3.20
2.84
2.49
2.13
1.78
1.42
1.07
0.71
0.36
Total
7.92
7.97
8.01
8.06
8.13
8.19
8.26
7.57
6.88
6.20
5.51
4.82
4.13
3.44
2.75
2.07
1.38
0.69
Maximum Annual
8.26 Annual NOx Emissions (tpy)
Source Month 1
Month 2
Month 3
Month 4
Month 5
Month 6
Month 7
Month 8
Month 9
Month 10
Month 11
Month 12
Month 13
Month 14
Month 15
Month 16
Month 17
Month 18
Onsite Equipment & Vehicles
5.69
5.80
5.92
6.04
6.16
6.27
6.39
5.86
5.32
4.79
4.26
3.73
3.19
2.66
2.13
1.60
1.06
0.53
Offsite Vehicles
1.72
1.60
1.47
1.35
1.35
1.35
1.35
1.24
1.12
1.01
0.90
0.79
0.67
0.56
0.45
0.34
0.22
0.11
Total
7.41
7.40
7.40
7.39
7.50
7.62
7.74
7.09
6.45
5.80
5.16
4.51
3.87
3.22
2.58
1.93
1.29
0.64
Maximum Annual
7.74 Annual SOx Emissions (tpy)
Source Month 1
Month 2
Month 3
Month 4
Month 5
Month 6
Month 7
Month 8
Month 9
Month 10
Month 11
Month 12
Month 13
Month 14
Month 15
Month 16
Month 17
Month 18
Onsite Equipment & Vehicles
0.01
0.01
0.01
0.01
0.01
0.01
0.01
0.01
0.01
0.01
0.01
0.00
0.00
0.00
0.00
0.00
0.00
0.00
Offsite Vehicles
0.01
0.01
0.01
0.01
0.01
0.01
0.01
0.01
0.01
0.01
0.01
0.01
0.00
0.00
0.00
0.00
0.00
0.00
Total
0.02
0.02
0.02
0.02
0.02
0.02
0.02
0.02
0.01
0.01
0.01
0.01
0.01
0.01
0.01
0.00
0.00
0.00
Maximum Annual
0.02
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Annual PM10 Emissions (tpy) Source Month 1
Month 2
Month 3
Month 4
Month 5
Month 6
Month 7
Month 8
Month 9
Month 10
Month 11
Month 12
Month 13
Month 14
Month 15
Month 16
Month 17
Month 18
Onsite Equipment & Vehicles
0.40
0.40
0.41
0.42
0.42
0.43
0.44
0.40
0.36
0.33
0.29
0.26
0.22
0.18
0.15
0.11
0.07
0.04
Fugitives
0.70
0.56
0.43
0.29
0.19
0.10
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
Offsite Vehicles
0.33
0.32
0.32
0.32
0.32
0.32
0.32
0.29
0.26
0.24
0.21
0.18
0.16
0.13
0.11
0.08
0.05
0.03
Total
1.42
1.29
1.16
1.03
0.93
0.84
0.75
0.69
0.63
0.56
0.50
0.44
0.38
0.31
0.25
0.19
0.13
0.06
Maximum Annual
1.42 Annual PM2.5 Emissions (tpy)
Source Month 1
Month 2
Month 3
Month 4
Month 5
Month 6
Month 7
Month 8
Month 9
Month 10
Month 11
Month 12
Month 13
Month 14
Month 15
Month 16
Month 17
Month 18
Onsite Equipment & Vehicles
0.34
0.35
0.35
0.36
0.37
0.38
0.38
0.35
0.32
0.29
0.26
0.22
0.19
0.16
0.13
0.10
0.06
0.03
Fugitives
0.30
0.25
0.19
0.14
0.09
0.05
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
Offsite Vehicles
0.12
0.11
0.11
0.11
0.11
0.11
0.11
0.10
0.09
0.08
0.07
0.06
0.05
0.04
0.04
0.03
0.02
0.01
Total
0.75
0.71
0.66
0.61
0.57
0.53
0.49
0.45
0.41
0.37
0.33
0.29
0.25
0.20
0.16
0.12
0.08
0.04
Maximum Annual
0.75
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4.0
ANSWERS TO AIR QUALITY DATA REQUESTS
ESA Data Requests #15 - #24 dated 26 July 2012 are addressed below. Question 15: Baseline air pollutant and greenhouse gas emission estimates relative to the Refinery components that would be affected by the Project. Response: Baseline emissions are not provided, as all sources of emissions associated with the Project would be new (i.e., construction, boiler, propane process units, propane storage, and new loading rack). For locomotive emissions, no new locomotive trips would be required; additional railcars would be used for the increase in propane production, which results in an incremental increase in the emissions from the existing locomotive trips due to the additional load. Question 16: Air pollutant and greenhouse gas emissions estimates associated with operations of the Project. Response: All emission estimates are presented in this Air Quality Supplement, the Greenhouse Gas Supplement, and the BAAQMD Permit Application. Detailed emissions calculations are provided in Attachment 1 to this Air Quality Supplement. Question 17: Recent health risk assessment(s) for the facility (preferably for the proposed project but if not available anything related to it). Response: A health risk assessment for the proposed project will be included in the Public Health Supplement. Question 18: Recent risk management plan (RMP). This was sent hard copy mail August 3, 2012. Question 19: Available air quality and meteorology sampling and measurement data summaries (last 5 years) for the Refinery. Response: Submitted on August 3, 2012. Question 20: Source emissions test data for sources that would be affected by the Project; include exhaust stack parameters such as height and diameter, and fuel/material throughput levels.
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Response: All emission estimates are presented in this Air Quality Supplement, with more details in the BAAQMD Permit Application. Stack parameters are provided in the BAAQMD Permit Application and modeling files that are part of the Public Health Supplement. Question 21: Facility drawings/maps showing source locations, property/fence line, and nearby sensitive receptors (e.g., residential/schools). Response: This information will be included in the health risk assessment analysis that is part of the BAAQMD Permit Application and the Public Health Supplement. Question 22: Title V operating permit for applicable sources, and/or annual emissions inventories for the past five years for the applicable sources. Response: Submitted on August 15, 2012. Question 23. Air pollutant emissions estimates for project demolition and construction activities. Response: These emission estimates are provided in this Air Quality Supplement. Question 24. Details of the odor complaints received by the Refinery over the last 5 years. Response: Submitted on August 1, 2012.
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5.0
REFERENCES
Association of American Railroads. 2012. The Environmental Benefits of Moving Freight by Rail. June. http://www.aar.org/~/media/aar/Background-Papers/TheEnvironmental-Benefits-of-Rail.ashx . Bay Area Air Quality Management District (BAAQMD). 2011. California Environmental Quality Act Air Quality Guidelines. December. California Air Pollution Control Officers Association (CAPCOA)/California Air Resources Board (CARB). 1999. California Implementation Guidelines for Estimating Mass Emissions from Fugitive Hydrocarbon Leaks at Petroleum Facilities. http://www.arb.ca.gov/fugitive/fugitive.htm. California Air Resources Board (CARB). 2012. EMFAC2011 On-Road Mobile Source Emissions Model. Available at http://www.arb.ca.gov/msei/msei.htm Climate Registry. 2012. Default Emission Factors, Released: January 6, 2012. http://www.theclimateregistry.org/downloads/2012/01/2012Climate-Registry-Default-Emissions-Factors.pdf Sierra Research. 2004. Revised Inventory Guidance for Locomotive Emissions. Prepared for Southeastern States Air Resource Managers, Inc. Report No. SR2006-04-01. http://www.metro4sesarm.org/pubs/railroad/FinalGuidance.pdf. USEPA. 2009. Emission Factors for Locomotives. Office of Transportation and Air Quality. April. Report number EPA-420-F-09025. USEPA. 1998. AP-42, Chapter 1.4, Natural Gas Combustion. July. U.S. Environmental Protection Agency (USEPA). 1995. AP-42 Compilation of Air Pollutant Emission Factors, Volume 1, Fifth Edition. January (and subsequent supplements).
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Phillips 66 Propane Recovery Project Final Environmental Impact Report
October 2013
Appendix A Air Quality and Greenhouse Gas Emissions Documentation
APPENDIX A.2
Greenhouse Gas Supplement
Phillips 66 Propane Recovery Project Final Environmental Impact Report
November 2013
Phillips 66 Propane Recovery Project Final Environmental Impact Report
October 2013
GREENHOUSE GAS SUPPLEMENT
Rodeo Refinery Rodeo, California
Rodeo Propane Recovery Project Greenhouse Gas Supplement
November 2012
TABLE OF CONTENTS
LIST OF TABLES
i
1.0
INTRODUCTION
1
2.0
CURRENT SITEWIDE GHG EMISSIONS
2
3.0
GHG EMISSION CHANGES
3
3.1
OPERATIONS 3.1.1 New Boiler 3.1.2 Natural Gas Added to Refinery Fuel Gas 3.1.3 Mobile Sources 3.1.4 Indirect 3.1.5 Total Operational GHG
3 3 3 4 5 6
3.2
CONSTRUCTION
7
4.0
REFERENCES
9
LIST OF TABLES Table 1
Reported GHG Emissions 2008 through 2010
2
Table 2
Mobile Source GHG Emissions
5
Table 3
Total Annual GHG Emissions During Operations
7
Table 4
Estimated GHG Emissions During Construction
8
i
1.0
INTRODUCTION
Greenhouse gases (GHG) emissions are generally quantified in terms of carbon dioxide equivalent (CO2e) and include gases such as carbon dioxide (CO2), methane (CH4), nitrous oxide (N2O), hydrofluorocarbons (HFC), perfluorocarbons (PFC), and sulfur hexafluoride (SF6). The impact on global warming on a per mass basis differs among these gases. For example, while methane and nitrous oxide have a larger potential for heating the earth’s atmosphere, because CO2 is emitted in larger quantities globally, CO2 is the largest contributor to global warming. The proposed project will increase GHG emissions through increase combustion of fuels during construction and operation. During construction, operation of equipment, trucks, and vehicles will generate GHG emissions. After construction, the combustion of fuels in a new boiler and increased use of locomotives, and commuter vehicles will result in GHG emissions. In addition, electricity will be used during construction and operations resulting in indirect emissions of GHG from power plants supplying the electricity. This GHG Supplement document discusses the change in GHG emissions associated with the Propane Recovery Project proposed by Phillips 66 Company ("Phillips 66") at its Rodeo Refinery in Rodeo, California. This document first presents baseline GHG emissions and then discusses potential changes in GHG emission from construction and operation of the proposed project, addressing the GHG portion of ESA data request #16 dated 26 July 2012.
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2.0
CURRENT SITEWIDE GHG EMISSIONS
The refinery currently emits GHG from various combustion equipment and processes. The refinery reports GHG emissions from non-mobile sources under the California Air Resources Board (CARB) Mandatory GHG Reporting Rule (CARB, 2012a). The emissions reported to CARB are summarized in Table 1 below. Table 1
Reported GHG Emissions 2008 through 2010 Inventory Year
Reported CO2e (metric tons)
2008
1,888,895
2009
1,873,464
2010
1,638,946
Source: CARB, 2012b
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3.0
GHG EMISSION CHANGES
GHG emissions from operations and construction of the proposed project are discussed below.
3.1
OPERATIONS As part of the proposed project, new equipment will be installed and existing equipment will be modified. In addition, the proposed project will increase railcar use and worker vehicle trips during operations. Electricity use will also increase. As will be discussed below, all these activities will result in GHG emissions.
3.1.1
New Boiler A new steam boiler that will burn refinery fuel gas and natural gas will be installed to generate additional steam needed to recover propane and butane from the refinery fuel gas. The boiler is expected to be designed with a maximum heat input rating of 140 million British thermal units per hour (MMBtu/hr). No other fuel burning equipment will be installed or otherwise modified that would directly increase GHG from fuel combustion (Section 3.1.3 will address GHG emissions from increased electricity use). The estimated annual GHG emissions associated with running the new boiler at a full capacity is 67,133 metric tons of CO2e1 assuming a worse-case scenario of burning refinery fuel gas at maximum capacity throughout the year. This emission estimate is based on burning 1,226,000 MMBtu of refinery fuel gas in one year. In reality, the boiler is not expected to run at full capacity all year. In fact, the expectation is that conservation measures will eventually be implemented that would reduce the amount of steam the boiler needs to produce for the proposed project. The CO2e estimate from the boiler provides part of the information requested in ESA Data Request #16.
3.1.2
Natural Gas Added to Refinery Fuel Gas The refinery will add natural gas to the refinery fuel gas to make up for the lost heat content resulting from the removal of propane and butane and thereby meet the heat load demands of other process unit operations.
1
Emissions are based on emission factors from AP-42 Chapter 1.4, Table 1.4-2 (USEPA, 1998)
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As part of the proposed project, the refinery expects to purchase an additional 1275 MMBtu per hour of natural gas to supplement the refinery fuel gas. Assuming, on average, 1275 MMBtu per hour is added 24 hours a day, 365 days a year, the total natural gas added would be 11,169,000 MMBtu per year. Since this addition of natural gas makes up for the propane and butane being removed, the overall heat load demands at the refinery met by refinery fuel gas is not expected to increase. In fact, by having the flexibility to adjust the amount of supplemental natural gas added to the refinery fuel gas during periods of lower than normal refinery fuel gas consumption, Phillips 66 will be able to better balance refinery fuel gas production versus consumption at the refinery. As a result, the proposed project will result in less flaring. In addition, on a unit energy basis (per MMBtu), propane and butane generate more CO2 than natural gas. In particular, on average in the United States, natural gas has a CO2 emission rate of about 53.02 kg CO2 per MMBtu. In contrast, on average, propane and butane have a CO2 emission rate of about 61.46 kg CO2 per MMBtu and 65.15 kg CO2 per MMBtu2, respectively. So if the same amount of energy in the form of natural gas is added to the refinery fuel gas as is removed in the form of propane and butane, less GHG will eventually be emitted when the refinery fuel gas is burned. This will result in a net reduction of approximately 166,483MT per year of CO2e. 3.1.3
Mobile Sources The existing butane loading rack facility will be modified so that the facility can accommodate loading of propane. As a result of this modification, the loading capacity for butane and propane will be increased from 16 rail cars per day to 24 rail cars per day. On an average basis, up to 12 new rail cars will be used per day over the current baseline use. This will result in an increase in GHG emissions associated with the combustion of diesel in the locomotives pulling the rail cars. In addition, two new workers are expected to be hired (out of the existing 600 workers at the refinery) which will slightly increase the number of commuter trips to and from the refinery. The key parameters used to develop GHG emissions are summarized below.
2
Emission factors from CARB GHG Mandatory Reporting Rule (CARB, 2012a)
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PHILLIPS66/0167855/ 11/8/12
The train travels from the California and Arizona border to the Richmond Yard with empty rail cars following a Union Pacific route (659 miles).
The train travels from the Richmond Yard to the refinery (12 miles) with empty rail cars.
The train then travels back to the Richmond Yard (12 miles) and then the Arizona border (659 miles) with full rail cars.
The train spends one hour in rail car switching activities at the refinery.
Two new commuters with a round trip commute of 19 miles per day.
The estimated increase in GHG emissions associated with these mobile sources is summarized in Table 2 below. This table provides part of the information requested in ESA Data Request #16. Additional details regarding the basis for the emission estimates can be found in Attachment 1 to the Rodeo Propane Recovery Project Air Quality Supplement, August 2012. Table 2
Mobile Source GHG Emissions CO2e (metric tons per year) Locomotives
5,366
Commuter Vehicles Total
4.3 5,370
For vehicles, CO2 emission factors from CARB EMFAC2011 (CARB, 2011) based on calendar year 2015, and CH4 and N2O emission factors from Table 13.4 of The Climate Registry GHG reporting guidance(TCR, 2012). For vehicle CO2 factors, accounting for light duty auto driven in Contra Costa. Emission factor for Locomotives from EPA-420-F-09-025 (USEPA, 2009)
3.1.4
Indirect As part of the proposed project, Phillips 66 will install new equipment and modify existing processes that will increase electricity use. On the other hand, some existing processes will be changed such that less electricity is consumed. As described in the Energy Supplement, the net impact is an estimated increase in average power demand of about 1.28 MW. Assuming this demand is constant all year round, 11,213 MWh of ERM
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PHILLIPS66/0167855/ 11/8/12
additional electricity would be consumed during the operation of the proposed project. GHG emissions associated with electricity consumption occur at power plants. Based on a PG&E specific GHG emission factor of 391 lb CO2 per MWh projected for 2015 (PG&E, 2011), and CH4 and N2O emission factors of 0.02839 lb/MWh and 0.00623 lb/MWh, respectively, from a Climate Registry GHG reporting guidance 3, GHG emissions from electricity consumption are estimated to be 2,002 metric tons CO2e4. 3.1.5
Total Operational GHG Based on the above analysis, the total annual GHG emission increases and reductions from the project are summarized in Table 3. The net impact of the proposed project is to reduce overall GHG emissions. This table provides part of the information requested in ESA Data Request #16.
3
Data is based on 2007 Emissions & Generation Resource Integrated Database (eGRID) data for the California region (TCR, 2012)
4
Value does not include transmission losses which is consistent with the TCR reporting protocol (TCR, 2008) for reporters who do no own or operate the transmission lines.
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Table 3
Total Annual GHG Emissions During Operations CO2e (metric tons per year) 67,133
New Boiler
-166,620
Combustion of Natural Gas in Lieu of Recovered Propane and Butane Indirect Mobile Sources
5,370
Indirect Electricity
2,002 -91,968
Total
3.2
CONSTRUCTION The construction of the proposed project will require the use of construction equipment and trucks to deliver material and haul away debris. In addition, construction workers will travel by car to and from the site in their vehicles. During these activities, electricity will be used to power some equipment, resulting in indirect GHG emissions at power plants generating the electricity. The following key parameters were used to estimate GHG emissions associated with these construction activities:
22 construction work days per month.
20 material delivery truck trips (diesel fueled) per day traveling 14.6 miles per round trip5.
11 debris trucks trips (diesel fueled) per day traveling 40 miles per round trip5.
366 worker commuter trips (gasoline fueled) per day traveling 19 miles per round trip5 with the trip rate based on a vehicle occupancy of 1.1.
Average electricity consumption of 44 megawatt-hours (MWh) per month.
5
Trip lengths based on defaults contained in the California Emissions Estimator Model (CalEEMod) v2011.11 , Appendix A (under Section 4.5) and Appendix D (Table 4.2 for Contra Costa County) (SCAQMD, 2011).
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Based on these parameters, the estimated GHG emissions during construction are summarized in Table 4 below. Table 4 provides the information requested in ESA Data Request #23. For the truck and vehicle emissions, the monthly emissions are assumed to be constant each month except for the debris truck hauling, which is assumed to occur over the first three months of construction. The presented monthly and annual emissions for construction equipment represent peak emissions. Additional details regarding the type of equipment assumed operating during construction and on the construction emissions calculations can be found in Attachment 1 to the Rodeo Propane Recovery Project Air Quality Supplement. Table 4
Estimated GHG Emissions During Construction Monthly CO2e (metric tons)
Annual CO2e (metric tons)
Over 18 Months CO2e (metric tons)
58 (peak)
683 (peak)
963
Material Delivery Trucks
11.2
134
201
Debris Hauling Trucks
17.0
51.1
51.1
Commuter Vehicles
48.5
582
873
Electricity
8
94
141
143
1544
2229
Sources Construction Equipment
Total
Notes: For trucks and vehicles, CO2 emission factors from CARB EMFAC2011 (CARB, 2011) based on calendar year 2014, and CH4 and N2O emission factors from Table 13.4 of The Climate Registry GHG reporting guidance(TCR, 2012). For construction equipment CO2e emission factors from OFFROAD2007. For the truck and vehicle CO2 factors, accounting for trucks treated as “heavyheavy duty trucks” (gross vehicle weight greater than 33,000 pounds) and for light duty auto driven in Contra Costa.
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4.0
REFERENCES
California Air Resources Board (CARB), 2011. Emission Factor Model EMFAC2011 On-Road Mobile Source Emissions Model. Available at http://www.arb.ca.gov/msei/modeling.htm CARB, 2012a. Regulation for the Mandatory Reporting of Greenhouse Gas Emissions, Title 17, California Code of Regulations (CCR), Sections 95100-95157). Effective January 1, 2012. CARB, 2012b. Mandatory GHG Reporting-Reported Emissions website, http://www.arb.ca.gov/cc/reporting/ghg-rep/reported_data/ghgreports.htm, last accessed August 20, 2012. PG&E, 2011. Greenhouse Gas Emission Factors Info Sheet, dated April 8, 2011. South Coast Air Quality Management District (SCAQMD), 2011. California Emissions Estimator Model (CalEEMod) v2011.1.1. The Climate Registry (TCR), 2012. Climate Registry Default Emission Factors, Released: January 6, 2012. http://www.theclimateregistry.org/downloads/2012/01/2012Climate-Registry-Default-Emissions-Factors.pdf TCR, 2008. General Reporting Protocol, Version 1.1, dated May 2008. United States Environmental Protection Agency (US EPA), 1998. AP-42 Compilation of Air Pollutant Emission Factors, Fifth Edition, Volume 1, Chapter 1.4. July 1998. United States Environmental Protection Agency (USEPA), 1998. AP-42 Compilation of Air Pollutant Emission Factors, Fifth Edition, Volume 1, Chapter 1.4. July 1998. USEPA, 2009. Emission Factors for Locomotives. Report number EPA-420-F09-025. April 2009.
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Appendix A Air Quality and Greenhouse Gas Emissions Documentation
APPENDIX A.3
Public Health Supplement
Phillips 66 Propane Recovery Project Final Environmental Impact Report
November 2013
PUBLICHEALTH HEALTH SUPPLEMENT PUBLIC SUPPLEMENT
Rodeo Refinery Rodeo, California
Rodeo Propane Recovery Project Public Health Supplement
December 2012
TABLE OF CONTENTS LIST OF TABLES
III
LIST OF FIGURES
III
1.0
INTRODUCTION
1
2.0
HAZARD IDENTIFICATION - TAC EMISSIONS FROM PRP OPERATION
2
2.1
TAC EMISSIONS FROM STATIONARY SOURCES
2
2.2
DIESEL PARTICULATE EMISSIONS FROM MOBILE SOURCES
6
3.0
4.0
HEALTH RISK ASSESSMENT PROCESS
8
3.1
HAZARD IDENTIFICATION
8
3.2
EXPOSURE ASSESSMENT 3.2.1 Ground-Level TAC Concentrations 3.2.2 Exposure Durations 3.2.3 Exposure Pathways
8 9 9 10
3.3
RISK CHARACTERIZATION 3.3.1 Cancer Risk 3.3.2 Non-Cancer Health Risk
11 11 14
EXPOSURE ASSESSMENT
16
4.1
AIR DISPERSION MODELING 4.1.1 Model Selection 4.1.2 Source Data 4.1.3 Building Downwash 4.1.4 Meteorological Data 4.1.5 Receptor Locations
16 16 16 17 20 21
4.2
EXPOSURE PATHWAYS AND DURATION
23
5.0
RISK CHARACTERIZATION
24
6.0
HEALTH RISK ASSESSMENT MODELING AND RESULTS
25
7.0
HEALTH RISKS FROM CONSTRUCTION
28
8.0
REFERENCES
29 i
ATTACHMENT 1
TOXIC AIR CONTAMINANT EMISSIONS
ATTACHMENT 2
AERMOD AND HARP FILES (ON CD)
ii
LIST OF TABLES
Table 1
TAC Emissions from the Boiler – Natural Gas Firing
Table 2
TAC Emissions from the Boiler – Refinery Fuel Gas Firing
Table 3
TAC Emissions from Fugitive Components
Table 4
AERMOD Source Parameter Inputs for Dispersion Modeling
Table 5
Dispersion Modeling Options/Parameters for AERMOD
Table 6
Summary of Potential Health Risk from PRP Emissions
LIST OF FIGURES Figure 1
Buildings/Structures and Source Locations
Figure 2
Refinery Meteorological Data Windrose
Figure 3
Maximum Risk Receptors Locations
iii
1.0
INTRODUCTION
This supplemental data document provides information to assist in assessing public health impacts from the proposed operation of the Propane Recovery Project (PRP) at the Phillips 66 Rodeo Refinery (Refinery). This document describes the toxic air contaminant (TAC) emission changes that will result from the PRP operations (Sections 2.1 and 2.2). This document also describes the procedure used to assess public health impacts from the project through a health risk assessment (HRA) (Sections 3.0 through 6.0). A quantitative health risk assessment of the TACs from construction was not performed, as the sources of TACs associated with PRP construction are located farther than 1,000 feet from the nearest sensitive receptor (Section 7.0). This screening criterion is based on the BAAQMD California Environmental Quality Act (CEQA) Guidelines that were adopted by the Bay Area Air Quality Management District (BAAQMD) in June 2010 and updated in May 2011 (BAAQMD 2011). Although some sections of these CEQA Guidelines are the subject of recent legal action, the thresholds and screening criteria are used in this analysis.
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2.0
HAZARD IDENTIFICATION - TAC EMISSIONS FROM PRP OPERATION
This section identifies the stationary and mobile-source TAC emissions associated with the PRP and describes the methodology used to estimate these emissions. The stationary sources of TAC emissions include a propane recovery unit boiler and the connection point leaks in piping. Mobile-source TAC emissions will result from additional rail cars needed for propane/butane transport.
2.1
TAC Emissions from Stationary Sources Stationary sources of TACs for the proposed project include: 1) a new 140 MMBtu/hr steam boiler fired on a combination of natural gas and treated refinery fuel gas with selective catalytic reduction (SCR) and 2) fugitive emissions from component leaks. Hourly TAC emissions from firing natural gas in the boiler were estimated using the emission factors provided in BAAQMD’s Policy: Emission Factors for Toxic Air Contaminants from Miscellaneous Natural Gas Combustion Sources, effective date September 7, 2005 (BAAQMD 2005), the maximum heat input rate of 140 MMBtu/hr, and a high heating value of 1,020 Btu/scf. Similarly, hourly TAC emissions from firing refinery fuel gas in the boiler were estimated using the emission factors provided in the Energy and Environmental Research Corporation (EERC) 14 August 1998 document - Air Toxic Emission Factors for Combustion Sources Using Petroleum Based Fuels, Final Report, Volume II (EERC 1998), and a high heating value of 1340 Btu/scf. Ammonia emissions will occur as a result of ammonia slip from SCR equipment used to control emissions of oxides of nitrogen from the boiler. The emission factor for ammonia was estimated using the equation given below and is based on a BACT limit of 15 ppmv for ammonia slip from SCR, an F-factor of 8,710 scf exhaust/MMBtu at 68 °F and 1 atm pressure, molar volume of 385.3 dry scf/mole of gas at 68 °F and 1 atm pressure, and molecular weight of ammonia.
EF (lb / MMbtu ) = ERM
BACT ( ppmv) 20.9 F − factor × MW × × 6 10 Vmolar 20.9 − O2 % 2
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Annual emissions were estimated assuming 8,760 hours of operation. Estimated TAC emissions from natural gas firing and refinery fuel gas firing are summarized in Tables 1 and 2, respectively. Details of the calculations are shown in Attachment 1. Because estimated TAC emissions from refinery fuel gas firing were higher than those from natural gas firing, the health risk assessment was performed for refinery fuel gas only. Table 1
TAC Emissions from the Boiler – Natural Gas Firing Emission Factor lb/MMscf
lb/MMBtu
Ammonia(1)
6.87E+00
6.73E-03
Emissions Hourly Annual (lb/hr) (lb/yr) 9.42E-01 8.25E+03
71-43-2
Benzene(2)
2.10E-03
2.06E-06
2.88E-04
2.52E+00
50-00-0
Formaldehyde(2)
7.50E-02
7.35E-05
1.03E-02
9.02E+01
108-88-3
Toluene(2)
3.40E-03
3.33E-06
4.67E-04
4.09E+00
CAS Number
Pollutant
7664-41-7
(1) Ammonia from SCR ammonia slip at 15 ppmvd @ 3% O2. (2) BAAQMD Policy: Emission Factors for Toxic Air Contaminants from Miscellaneous Natural Gas Combustion Sources, Effective date September 7, 2005, http://www.baaqmd.gov/~/media/Files/Engineering/policy_and_procedures/TACEmFacfr omNatGasCombustion.ashx
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Table 2
TAC Emissions from the Boiler – Refinery Fuel Gas Firing1
CAS Number
Emission Factor
Pollutant
lb/MMBtu 6.73E-03 2.36E-09 1.55E-09 1.53E-05 5.17E-07 8.50E-07 (0) ND 6.47E-05 3.21E-08 8.96E-08 4.04E-08 (0) ND 2.41E-08 (0) ND 9.88E-07 (0) ND 1.07E-06 1.63E-09 4.21E-06 (0) ND 3.02E-05 3.06E-09 1.08E-08 1.11E-04 (0) ND 1.03E-07 4.89E-06 6.81E-06 1.80E-07 3.13E-07 9.42E-06 1.46E-08 5.63E-06 (0) ND 2.17E-06 2.48E-09 1.96E-08 1.61E-06 (0) ND 1.07E-04 3.73E-05 2.08E-05
Ammonia(2)
Emissions Hourly (lb/hr) 9.42E-01 3.30E-07 2.17E-07 2.14E-03 7.24E-05 1.19E-04 0.00E+00 9.06E-03 4.49E-06 1.25E-05 5.66E-06 0.00E+00 3.37E-06 0.00E+00 1.38E-04 0.00E+00 1.50E-04 2.28E-07 5.89E-04 0.00E+00 4.23E-03 4.28E-07 1.51E-06 1.55E-02 0.00E+00 1.44E-05 6.85E-04 9.53E-04 2.52E-05 4.38E-05 1.32E-03 2.04E-06 7.88E-04 0.00E+00 3.04E-04 3.47E-07 2.74E-06 2.25E-04 0.00E+00 1.50E-02 5.22E-03 2.91E-03
Annual (lb/yr) 8.25E+03 2.89E-03 1.90E-03 1.88E+01 6.34E-01 1.04E+00 0.00E+00 7.93E+01 3.94E-02 1.10E-01 4.95E-02 0.00E+00 2.96E-02 0.00E+00 1.21E+00 0.00E+00 1.31E+00 2.00E-03 5.16E+00 0.00E+00 3.70E+01 3.75E-03 1.32E-02 1.36E+02 0.00E+00 1.26E-01 6.00E+00 8.35E+00 2.21E-01 3.84E-01 1.16E+01 1.79E-02 6.90E+00 0.00E+00 2.66E+00 3.04E-03 2.40E-02 1.97E+00 0.00E+00 1.31E+02 4.57E+01 2.55E+01
7664-41-7 83-32-9 Acenaphthene 208-96-8 Acenaphthylene 75-07-0 Acetaldehyde 7440-36-0 Antimony 7440-38-2 Arsenic 7440-39-3 Barium(3) 71-43-2 Benzene 56-55-3 Benzo(a)anthracene 50-32-8 Benzo(a)pyrene 205-99-2 Benzo(b)fluoranthene 191-24-2 Benzo(g,h,i)perylene(3) 207-08-9 Benzo(k)fluoranthene 7440-41-7 Beryllium(3) 7440-43-9 Cadmium 18540-29-9 Chromium (Hex)(3) 7440-47-3 Chromium (Total) 218-01-9 Chrysene 7440-50-8 Copper 53-70-3 Dibenz(a,h)anthracene(3) 100-41-4 Ethylbenzene 206-44-0 Fluoranthene 86-73-7 Fluorene 50-00-0 Formaldehyde 7783-06-4 Hydrogen Sulfide(3) 193-39-5 Indeno(1,2,3-cd)pyrene 7439-92-1 Lead 7439-96-5 Manganese 7439-97-6 Mercury 91-20-3 Naphthalene 7440-02-0 Nickel 85-01-8 Phenanthrene 108-95-2 Phenol 7723-14-0 Phosphorus(3) 115-07-1 Propylene 129-00-0 Pyrene 7782-49-2 Selenium 7440-22-4 Silver 7440-28-0 Thallium(3) 108-88-3 Toluene 1330-20-7 Xylene (Total) 7440-66-6 Zinc (1) EERC 1998. (2) Ammonia from SCR ammonia slip at 15 ppmvd @ 3% O2. (3) An emission factor of zero has been substituted for non-detect (ND) compounds based on CAPCOA health risk assessment guidelines.
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Fugitive TAC emissions from component leaks were estimated using the speciation profile of refinery fuel gas provided by Phillips 66. Mass fractions of various TACs in the refinery fuel gas were estimated by multiplying their mole (volume) fraction (provided in the speciation profile) by the ratio of the respective TAC’s molecular weight to the molecular weight of the refinery fuel gas. The estimated TAC mass fractions were multiplied by the estimated fugitive Reactive Organic Gases (ROG) emissions to calculate the TAC emissions. Fugitive ROG emissions were estimated based on U.S. Environmental Protection Agency (USEPA) Correlation Equations as presented in Table IV-3a of the February 1999 California Air Pollution Control Officers Association/California Air Resources Board (CAPCOA/CARB) document entitled California Implementation Guidelines for Estimating Mass Emissions of Fugitive Hydrocarbon Leaks at Petroleum Facilities (CAPCOA/CARB 1999). This document is the accepted BAAQMD standard for estimating fugitive emissions. The best available control technology (BACT) determination for fugitive components was used as the screening value (SV) in each Correlation Equation to estimate fugitive ROG emissions. The following equation describes the above methodology for each TAC (x). Annual emissions were estimated assuming an 8,760 hours per year of operation. TAC emissions from component leaks are shown in Table 3. Details of the calculations are shown in Attachment 1. TAC x (lb / hr ) =
Table 3
Mole Fraction x ( ppmv ) MWx × × ROG (lb / hr ) 10 6 MWRFG
TAC Emissions from Fugitive Components Emissions
CAS Number
Pollutant
Mass Fraction(1)
Hourly (lb/hr)
Annual (lb/yr)
---
POC or ROG(2)
1.00E+00
1.05
9163
7783-06-4
Hydrogen sulfide(3)
8.71E-04
9.11E-04
7.98E+00
75-15-0
Carbon disulfide
1.36E-06
1.42E-06
1.24E-02
115-07-1
Propylene
2.57E-02
2.69E-02
2.35E+02
106-99-0
1,3-Butadiene
2.25E-04
2.35E-04
2.06E+00
71-43-2
Benzene
9.97E-04
1.04E-03
9.13E+00
110-54-3
Other C6+(4)
5.38E-02
5.63E-02
4.93E+02
(1) Product of first two terms in equation preceding Table 3. (2) ROG emissions estimated based on U.S. EPA Correlation Equations in Table IV-3a of the CARB/CAPCOA document entitled California Implementation Guidelines for Estimating Mass Emissions of Fugitive Hydrocarbon Leaks at Petroleum Facilities. (3) All total reduced sulfur compounds in RFG were assumed to be hydrogen sulfide. (4) All other C6+ compounds were assumed to be n-Hexane. ERM
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2.2
Diesel Particulate Emissions from Mobile Sources The implementation of the PRP would change the quantity of raw materials and products into and out of the refinery. These materials will be transported by rail. An estimated 12 additional tank cars per day on an annual average basis will be required to ship the propane and butane recovered by PRP. These additional tank cars will increase the load on diesel locomotive engines and the exhaust emissions from the engines. Particulate matter from diesel exhaust is a known carcinogen and therefore considered a TAC. Incremental emission estimates from additional tank cars are presented below. Diesel particulate matter (DPM) emissions, associated with increased locomotive engine load due to the average 12 additional rail cars a day, were calculated using the particulate matter emission factors for locomotives, in grams per gallon of fuel consumed, from the USEPA document – Emission Factors for Locomotives, Technical Highlights, EPA-420F-09-025, April 2009 (USEPA 2009). Emission factors for the year 2015, when the project first becomes operational, were used in the calculation. Quantity of fuel consumed for line haul was estimated from dividing the product of gross weight of additional tank cars hauled and trip length by fuel consumption index in terms of gross ton-miles per gallon. Gross weight hauled includes weight of the freight and tare weight of tank cars. The following equation describes the above methodology. DPM (lb / yr ) = EFPM 10 ×
GW × L FCI × 453.6
where: DPM = Annual average diesel particulate matter emissions EFPM10 = PM10 emission factor for small line haul (g/gallon of fuel) GW = Annual gross weight hauled = Weight of freight + weight of empty tank cars (tons/year) L = length of line source = 2.2 miles FCI = Fuel consumption index = 928 gross ton-miles/gallon of fuel. The entire rail trip will extend from the refinery all the way to the border of California and Mexico or Arizona. However, for the purpose of this HRA, only a 2.2-mile portion of the trip near the refinery was considered and DPM emissions were estimated for this portion of the trip. The 2.2-mile portion of the track selected for modeling, along the Lincoln Highway, ERM PHILLIPS 66/0167855 - 5/30/2013 6
covers the nearby residential receptors and a day-care center that are in the predominant wind direction relative to the railroad track. Annual DPM emissions over the 2.2-mile track were estimated to be 20.26 pounds per year. Details of the calculation are shown in Attachment 1.
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3.0
HEALTH RISK ASSESSMENT PROCESS
An HRA is a three-step process to assess potential public health risk from exposures to environmental contaminants from emission sources. •
First, a hazard identification is performed to determine the pollutants of concern, i.e. TACs, and emissions of TACs are quantified.
•
Second, in the exposure assessment step, ground-level impacts resulting from the transport and dilution of these emissions through the atmosphere are assessed at locations of predicted exposure (or “receptors”) by air dispersion modeling, typically using, as with this health risk assessment, government-developed computer air dispersion models and local weather data.
•
Third, in the risk characterization step, potential human doses of these compounds resulting from the atmospheric transport are calculated, typically using State-approved procedures, as were used here. Potential cancer and non-cancer health risks resulting from the calculated exposures are estimated using dose-response relationships developed from toxicological data.
The procedures used in this HRA are consistent with the California Office of Environmental Health Hazard Assessment (OEHHA) guidance, Air Toxics Hot Spots Program Risk Assessment Guidelines: The Air Toxics Hot Spots Program Guidance Manual for Preparation of Health Risk Assessments (OEHHA 2003), as referenced by the California Air Pollution Control Officers Association (CAPCOA) document, Health Risk Assessments for Proposed Land Use Projects (CAPCOA 2009), for conducting health risk assessments for land use projects.
3.1
HAZARD IDENTIFICATION A description of the emission estimates for TACs from various stationary and mobile sources associated with the project’s operation is included as part of this HRA in Section 2, and details of the calculations are included in Attachment 1.
3.2
EXPOSURE ASSESSMENT The exposure assessment step in the comprehensive HRA involves evaluating three parameters that ultimately go into the estimation of health ERM
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risks. These parameters are: ground-level TAC concentrations, exposure durations, and exposure pathways. 3.2.1
Ground-Level TAC Concentrations Ground-level concentrations of toxic pollutants at various receptors are estimated by running an air dispersion modeling program, such as AERMOD. Details of dispersion modeling are presented in Section 4.1.
3.2.2
Exposure Durations The assessment of cancer risk and chronic non-cancer health effects requires annual-average emissions, while assessment of acute non-cancer health effects requires maximum short-term emissions. Also, for the acute analysis, it is conservatively assumed that all maximum short-term emissions would occur in the same hour. For individuals at off-site residential locations, the cancer risk calculations assume that these individuals never leave these locations for 70 years and that all operations will continue over the 70-year period. At other specific receptor locations, including off-site workers, a continuous 70-year exposure is not appropriate. For these receptors, an exposure time of 8 hours per day and 245 days per year for 40 years is assumed. Use of these exposure durations along with OEHHA-recommended upper-bound exposure pathway parameters (see Section 3.2.3) comprise the most conservative “Tier 1” point-estimate approach in the OEHHA Guidelines. Sensitive receptors refer to those segments of the population most susceptible to poor air quality (i.e., children, the elderly, and those with pre-existing serious health problems affected by air quality). These receptor locations include residential communities, schools, daycare centers, playgrounds, and medical facilities. The potential cancer risk for the non-working, off-site, sensitive populations assumes the standard 70-year residential exposure. Chronic and acute non-cancer health effects are assessed from annual-average and short-term exposure estimates, respectively, without further adjustments from the standard Tier 1 assumptions and, as stated above, it is assumed for the acute analysis that all maximum short-term emissions would occur within the same hour. Furthermore, the non-cancer toxicity factors were established by the CARB and OEHHA to be protective of sensitive members of the population or those undergoing physiological change, which include children and the elderly. Therefore, it is believed that these analyses account for the protection of sensitive individuals.
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3.2.3
Exposure Pathways The inhalation exposure pathway involves the direct inhalation of gaseous and particulate air pollutants. In addition, there is the potential for exposure via non-inhalation pathways due to the deposition of pollutants. Potential non-inhalation exposure pathways include soil ingestion, dermal absorption, mother’s milk, and ingestion of homegrown produce. As discussed in Section 4.1.2, the AERMOD dispersion model (version 09292) is run with a unit emission rate (1 gram per second [g/s]) for all sources to calculate normalized air concentrations (micrograms per cubic meter [µg/m3] per g/s emissions) at each receptor point. The model outputs are then used in conjunction with source-specific emission rates for each TAC as well as toxicity factors to calculate potential health effects. The calculations are performed using the Hotspots Analysis and Reporting Program (HARP) model. The HARP model uses AERMOD dispersion model outputs along with site-specific emissions data and pollutant specific toxicity factors. To enable HARP to utilize the AERMOD output files, the HARP ONRAMP program is used to convert the output information into a HARP-compatible format. The HARP model implements the methodologies described in the OEHHA Guidelines. To estimate airborne concentrations, HARP uses the normalized modeled dilution factor (normalized concentration) for each receptor location from the AERMOD output and multiplies them by pollutant and source-specific emission rates. For estimating non-airborne pollutant concentrations from particulate emissions, HARP first estimates air concentrations for each pollutant (µg/m3) by multiplying particulate pollutant emission rates (g/s) by the maximum normalized concentration, and then uses in the following equation to estimate pollutant deposition rates: Dep = GLC x Dep-rate x 86,400 where: Dep
= deposition on the affected soil area per day (µg/m2/day)
GLC = estimated ground-level air concentrations (µg/m3) Dep-rate = vertical rate of deposition (m/s) The factor of 86,400 is the number of seconds in a day. OEHHA recommends a deposition rate of 0.05 m/s for uncontrolled sources and 0.02 m/s for controlled sources (OEHHA 2003). It would be overly conservative to use an uncontrolled deposition rate for the combustion sources since the particulate matter from these sources are extremely small in size. Therefore, the controlled deposition rate of 0.02 m/s ERM
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(representative of fine particulate matter) is used in these calculations. These deposition estimates are then used in algorithms contained in HARP for the soil ingestion, dermal absorption, mother’s milk, and homegrown produce pathways for the evaluation of the maximally exposed individual at a residential receptor (MEIR). Consistent with OEHHA Guidelines, the maximally exposed individual at an off-site worker receptor (MEIW) is evaluated with only the inhalation, soil ingestion, and dermal absorption pathways.
3.3
RISK CHARACTERIZATION
3.3.1
Cancer Risk Cancer risk is expressed in terms of the increased chances (or probability) of developing cancer as a result of exposure to a carcinogen at any exposure level typically over a lifetime, typically expressed as the increased chances in one million. The calculation procedure for lifetime cancer risk assumes that cancer risk is proportional to concentration at any level of exposure; that is, there is no dose that would result in a zero probability of contracting cancer. This is a conservative assumption for low doses, but consistent with the current OEHHA regulatory approach. The calculated probability (typically expressed as the chances in one million) is always greater than zero when the exposure level is greater than zero. Under CEQA a potential cancer risk of 10 in one million or greater is considered to be a significant impact. Toxicologists for both OEHHA and USEPA have developed cancer slope factors (SFs) for various compounds based on epidemiological studies in humans (when available), or more commonly, from animal studies. Cancer SFs are typically expressed either in terms of inhalation exposure (SFi) or oral (ingestion) exposure (SFo). They represent the potential risk of contracting cancer per daily dose of the chemical (in milligrams of chemical per kilogram of body weight per day [1/(mg/kg-day)]). These factors are sometimes referred to as dose-response relationships. Dose, which is the amount of exposure to a toxin, is estimated for each applicable exposure pathway. For example, the amount of exposure through inhalation pathway is estimated using the following equation: Doseinh =
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C t × DBR × A × EF × ED × 10 −6 AT 11
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where: Ct = Air concentration of toxic substance t (micrograms per cubic meter air, µg/m3). These values were obtained by modeling the emission sources described in Section 4.1 using agency recommended methods. DBR = Daily Breathing Rate (liters of air inhaled per kilogram body weight per day, L/kg-day) Under State guidelines: (”high-end” estimate)
95th percentile DBR = 393 L/kg-day
80th percentile DBR = 302 L/kg-day (for residential receptors per CARB 2003) Off-site worker DBR = 149 L/kg-day (corresponds to 70-kg worker breathing 1.3 m3/hr of air for an 8-hour day) A = Inhalation Absorption Rate = 1 EF = Exposure Frequency (days/year) Under State guidelines, for residential receptors, EF = 350 days/year ED = Exposure Duration (years) Under State guidelines, for residential receptors, ED = 70 years for cancer risk AT = Averaging Time = 25,550 days (i.e., 70 years, for cancer risk) Calculation of dose through the different non-inhalation pathways is detailed in the OEHHA Guidelines. The HARP model was used for these dose calculations.
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In order to characterize total substance risk, the inhalation risk is calculated by multiplying the inhalation dose (mg/kg-day) by the inhalation cancer potency slope factor (SFi). The dermal and oral dose from each relevant exposure pathway is multiplied by the substance-specific oral potency factor (SFo) to give the oral (non-inhalation) cancer risk. The inhalation cancer risk and oral cancer risk are then added to give the multi-pathway cancer risk for that substance. Many facilities will emit multiple carcinogenic substances. If multiple substances are emitted, the cancer risk from each of the individual substances (including multi-pathway and inhalation-only substances) is added to give the (total) multi-pathway cancer risk for the entire facility at the receptor location. Cancer Risk = ∑ (SFit × Doseinh , t
t
+ SFot × ∑ Dosenon −inh , t )
where: t = toxic air contaminant emitted by the source SFit = Inhalation Cancer Potency Slope Factor for substance t (mg/kg-day)-1 Doseinh, t = inhalation dose (mg/kg-day), calculated using equation 2-1 for substance t. SFot = Cancer Potency Slope Factor for substance t for noninhalation pathways (mg/kg-day)-1 Dosenon-inh, t = total dose for non-inhalation pathways (mg/kg-day), such as dermal absorption, soil ingestion, ingestion of mother’s milk, for substance t, using the appropriate OEHHA methods. The HARP model was used to estimate the total cancer risk at each receptor. As described above, HARP currently calculates cancer risk in accordance with the OEHHA 2003 Risk Assessment Guidelines (OEHHA 2003). In June 2009, OEHHA adopted the Technical Support Document for Cancer Potency Factors (OEHHA 2009), which included the incorporation of age sensitivity factors (ASFs) to cancer risk calculations. These ASFs were made part of the BAAQMD’s health risk screening analysis (HRSA) procedures in January 2010 (BAAQMD 2010a). It is believed that the ASFs, or weighting factors, which apply to infants, children, and adolescents, account for increased sensitivities to carcinogens at these ages. For infants, ERM
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it is recommended that a factor of 10 be applied for exposures occurring from the third trimester up to 2 years of age (total of 2.25 years). From after 2 to 16 years of age, an ASF of 3 should be applied. For exposures from after 16 up to age 70, no adjustment factor has been developed or recommended, thus the ASF equals 1 for this period. For 70-year exposure estimates, this total weighting scheme applied to a constant 70-year emission rate results in an overall adjustment factor of 1.7 applied to the 70-year cancer risk predictions from HARP. For 40-year exposures applied to off-site workplaces, all exposed individuals would be above the age of 16, and thus, no further adjustment is made to those HARP predictions. The application of ASFs was done in this health risk assessment. 3.3.2
Non-Cancer Health Risk Chronic toxicity is defined as the adverse biological effects caused by prolonged chemical exposure. These exposures may be continuous or repeated. Chronic effects usually occur at lower exposure levels than acute effects, primarily because of chemical accumulation in the body. Since chemical accumulation to toxic levels typically occurs slowly, symptoms of chronic effects usually do not appear until long after exposure commences. The highest no-effect exposure level is the chronic RfD, which is expressed in terms of mass dose of the chemical per body weight per day (mg/kg-day). Below these thresholds, the body is capable of eliminating or detoxifying the chemicals rapidly enough to prevent accumulation. As with cancer toxicity factors, RfDs are usually provided either in terms of inhalation exposure (RfDi) or oral (ingestion) exposure (RfDo). If exposure is expressed as an airborne concentration, these thresholds are sometimes expressed as reference air concentrations (RfCs). This HRA uses the OEHHA term of REL for RfC. The chronic REL and RfDi for a given chemical are related as follows: REL = (RfDi x AT x 106)/(DBR x EF x ED) where: REL = reference air concentration causing a toxicological response (µg/m3) RfDi = inhalation reference dose causing a toxicological response (mg/kg-day) The other factors are the same as defined in Section 3.3.1. Acute toxicity is defined as adverse biologic effects caused by brief chemical exposures of no more than 24 hours. Acute effects may range from simple ERM
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eye or skin irritation to death. For most chemicals, eye or respiratory irritations are the main symptoms to threshold acute exposures. The air concentration required to produce acute effects is typically higher than levels required in chronic effects because the duration of exposure is shorter. Acute effects usually occur immediately or almost immediately after exposure begins and if the exposure levels are not high enough to cause serious injury or death, complete recovery usually follows soon after exposure ceases. A minimum exposure level is required to cause any acute effect. These threshold exposure levels (RfCs or RELs) correspond to levels that manifest milder acute health effects such as eye irritation or simple respiratory discomfort. Non-cancer health effects of an inhaled air toxic are measured by the hazard index, the ratio of the reported concentration of an air toxic compound to an acceptable or “reference” exposure level (REL). For noninhalation pathways, hazard indices are calculated as the ratio of calculated doses to acceptable or reference doses (RfDs). If the reported concentration or dose of a given chemical is less than its REL or RfD, then the hazard index will be less than 1.0. If more than one chemical is considered, it is assumed that multiple subthreshold exposures could result in an adverse health effect for a given target organ. Thus, chemical-specific hazard indices are summed for a given target organ. Typically, for a given set of chemicals, hazard indices are summed for each organ system. Hazard indices can be calculated both on a chronic toxicity and acute toxicity basis. For any organ system, a total hazard index exceeding 1.0 indicates a potential significant health effect. The HRA for proposed project operations analyzes cancer, chronic noncancer, and acute health impacts from the sources identified in Section 2.0.
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4.0
EXPOSURE ASSESSMENT
An exposure assessment was conducted using dispersion modeling to simulate the transport of pollutants to locations of predicted exposure (or “receptors”). This section describes the dispersion modeling conducted for this HRA, including exposure assumptions and receptor locations.
4.1
AIR DISPERSION MODELING
4.1.1
Model Selection The dispersion modeling was performed using the American Meteorological Society/ Environmental Protection Agency Regional Modeling System (AERMOD) developed by the American Meteorological Society/ Environmental Protection Agency Regulatory Model Improvement Committee (AERMIC). AERMOD incorporates air dispersion for both surface and elevated sources and for areas with either simple and/or complex terrain. In addition to the dispersion portion, the AERMOD modeling system includes two additional regulatory components: a meteorological data preprocessor (AERMET) and a terrain data preprocessor (AERMAP). Attachment 2 contains electronic input and output files from the dispersion modeling runs. The modeling was performed using the calm winds processing routine. The AERMOD dispersion model can simulate the transport of emissions from multiple sources including point sources, area sources, and volume sources. The model requires specific inputs for each source type as discussed below.
4.1.2
Source Data TAC emissions sources for this analysis have been characterized as point (boiler stack), area (fugitive component leaks), and line sources divided into separated volume sources (locomotive). Table 4 summarizes the source parameters input to the model. Note that each source was modeled by AERMOD with a unit emission rate (1 gram per second [g/s]) to calculate “normalized” air concentrations (micrograms per cubic meter [µg/m3] per g/s emissions) at each receptor point. This allows incorporation of source-specific emission rates to the “normalized” air concentrations to calculate ground-level concentrations, which was performed using the HARP model. ERM
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Table 4
AERMOD Source Parameter Inputs for Dispersion Modeling Locomotive Line Haul - Line Source (As Separated Volume Source) Source X-Y Coordinates UTM NAD 83 System Track Length Considered for Modeling 2.2 miles/trip Length of the Line Source, LRS 11,405 ft Width of the Line Source, W (Width of the three tracks) 37.04 ft Total DPM Emission Rate for Line Source 20.26 lb/year Line source represented by separated volume sources, Elevated Source Type source not on or adjacent to a building Length of the Side of the Line/Volume Source = W 37.04 ft Spacing of Separated Volume Source Along Line (c/c) 74.08 ft Starting Location Offset Half Volume Width Release Height 45.8 ft Initial Lateral Dimension (SYINIT) = 2W/2.15 34.46 ft Initial Vertical Dimension (SZINIT) = Release Height/4.3 10.64 Number of Volume Sources Generated by BEEST Model 156 volume sources/line Emission Rate Per Volume Source (Used for dispersion 1 g/s/volume source modeling) Fugitive Emissions - Area Source Source X-Y Coordinates UTM NAD 83 System East-West side length 230 ft North-South side length 215 ft Source Area 49450 sq. ft Area source, Elevated source not on Source Type or adjacent to a building Release Height = Vertical Dimension 0 ft Emission Rate 1 g/s New Boiler - Point Source Source X-Y Coordinates UTM NAD 83 System Release Height 120 ft Release Temperature 300 °F Exit Velocity 15 ft/s Stack Diameter 7 ft Emission Rate 1 g/s
4.1.3
Building Downwash When point sources are located near or on buildings or structures, the dispersion of the plume can be influenced. Under certain wind speeds, the wake produced on the lee side of the building can cause the plume to be pulled toward the ground near the building, resulting in higher concentrations close to the building. These effects are called building downwash.
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The effects of building downwash have been considered in this modeling analysis. The USEPA provides specific guidance to determine whether or not a building potentially affects pollutant dispersion. According to that guidance, if a structure is located within a certain distance from the emission source (stack), downwash effects must be considered. Stack heights that minimize downwash effects are designated good engineering practice (GEP) stack heights. The GEP formula height is defined as: Hs = Hb+ 1.5Lb where: Hs = GEP formula height Hb = Building height Lb = The lesser building dimension of the height, length, or width. The emission stack in the PRP is less than GEP formula height and thus was considered in the downwash analysis. Because of the complexity of the stack/building relationships, the analysis included all buildings that could potentially influence the point source. Figure 1 illustrates the buildings and source locations included in the downwash analysis. The Building Profile Input Program Prime (BPIP-Prime) software program calculates the GEP formula heights and direction-specific building dimensions for input into the AERMOD model. BPIP-Prime requires the input of building/structure corner coordinates and point-source coordinates and heights. The NAD 83 UTM coordinate system was used to identify source and building/structure locations. The AERMOD model uses BPIP-Prime outputs as input for calculating the aerodynamic building downwash from multiple buildings.
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Figure 1: Buildings/Structures and Source Locations
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4.1.4
Meteorological Data Onsite surface meteorological data are available from the Refinery. AERMET was used to process the meteorological data. AERMET requires that land use around the Refinery be analyzed to derive surface parameters including surface roughness, Bowen ratio, and albedo by 360-degree sector. Five years of AERMET processed data (2005, 2007, 2008, 2009, and 2010) were used to perform the AERMOD modeling. BAAQMD supplied the processed onsite meteorological data in the Integrated Surface Hourly (ISH) (DS-3505) format, Oakland Radiosonde Data (RAOB) data in the FSL format, and a table of surface moisture conditions by month concurrent with the period of the meteorological data. Figure 2 illustrates the predominant wind directions and wind speeds for the Refinery meteorological station. Figure 2: Refinery Meteorological Data Windrose
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4.1.5
Receptor Locations Receptors were placed at approximately 20-meter increments along the Phillips 66 property boundary. Additional receptors were located at approximately 100-meter increments to a distance of approximately 4,500 meters (4.5 kilometer), at approximately 250-meter increments to a distance of approximately 8 kilometers, at approximately 500-meter increments to a distance of approximately 14 kilometers, and at approximately 1000-meter increments to a distance of approximately 25 kilometers. Receptor locations are shown in Figure 1. Receptors were identified using NAD 83 UTM coordinates, and receptor elevations were taken from National Elevation Data (NED) obtained from the United States Geological Survey. The NED data were processed using AERMAP to obtain elevations and hill heights for receptors and elevations for sources and buildings. Table 5 summarizes the AERMOD parameters selected for dispersion modeling for this HRA.
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Table 5
Dispersion Modeling Options/Parameters for AERMOD Feature/Parameter
Option/Value Selected
Control Pathway Pollutant Id
Toxics
Averaging Period Options
1-hour (1) and Period (P)
Flagpoles
None
Half Life/ Decay
None
File Options
Run, No Echo (No other options selected)
AER Regulatory Status
Default
Output Type (Unrestricted Options)
Concentration
Debug Options
None selected
AER Urban Option
No urban area
AER Gas Deposition Parameters
Use default reference parameters for gas dry deposition
Source Pathway – Described above for each source Receptor Pathway Receptor Type
Discrete Cartesian
Partition Option (Xpress/Local)
Default (no partition)
East (X), North (Y) Coordinates
UTM NAD 83 system (See Discussion in Section 4.1.5)
Elevation
NED processed by AERMAP
Terrain Max
NED processed by AERMAP
Flagpole
Not selected
Meteorology Pathway Meteorological Input data
*.SFC file – AERMET preprocessed meteorological data for 5 years
Select Days
Process entire year
Other Met Options
None selected
Terrain Pathway Elevation Units in Terrain Grid File
Meters
Other Terrain Options
None selected
Boundary Pathway Fenceline
East (X), North (Y) Coordinates in UTM NAD 83 system
Buildings
Tier height and X-Y coordinates of corners in UTM NAD 83 system. Base elevation provided by NED processed by AERMAP
Tanks
X-Y coordinates of center in UTM NAD 83 system, tank diameter, and tank height. Base elevation provided by NED processed by AERMAP
Output Pathway Highest Value at Each Receptor
For 1-hr averaging period – 1st highest value
Plot File
Write master graphics file
Other File Options
None selected
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4.2
EXPOSURE PATHWAYS AND DURATION As noted in Section 3.2, the exposure pathways for residential receptors included in this assessment were:
•
Inhalation;
•
Dermal (skin) absorption;
•
Ingestion of soil with deposited pollutants;
•
Exposure to pollutants potentially in mother’s milk; and
•
Exposure due to the consumption of homegrown produce.
The exposure pathways for worker receptors include: •
Inhalation;
•
Dermal (skin) absorption; and
•
Ingestion of soil with deposited pollutants.
For sensitive and residential receptors, a 70-year exposure duration was assumed. For off-site worker receptors, an exposure time of 8 hours per day, 5 days per week and 49 weeks per year for 40 years was assumed.
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5.0
RISK CHARACTERIZATION
For each exposure pathway noted above, the dose of each chemical, in milligrams of chemical per kilogram of body weight per day (mg/kg-day), was calculated pursuant to the OEHHA Guidelines using the Hotspots Analysis and Reporting Program (HARP), Version 1.4f. The Tier 1 assessment assumes a continuous, 70-year exposure for longterm health risks to determine the location for the maximally exposed individual at an existing residential receptor (MEIR). The location for the maximally exposed individual at an existing worker (occupational) receptor (MEIW) was calculated using an adjusted exposure period consistent with the OEHHA Guidelines, as described in Section 4.2. Acute health effects were calculated using a maximum hourly concentration. Chronic health effects were calculated based on a continuous exposure for an annual period. The Tier 1 analysis combines the 70-year exposure period with a standard point-estimate approach using upper-bound exposure pathway parameters recommended in the OEHHA Guidelines. The Tier 1 analysis performed for this HRA calculates cancer risk with the derived (adjusted) method, consistent with the CARB Interim Risk Management Policy (CARB 2003). Of the 42 chemicals evaluated in this HRA, 17 were evaluated for cancer risk, 23 were evaluated for potential chronic non-cancer health effects, and 13 were evaluated for potential acute non-cancer health effects.
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6.0
HEALTH RISK ASSESSMENT MODELING AND RESULTS
Estimated health risks from the proposed PRP operation are summarized in Table 6 and the locations presented in Figure 3. Table 6
Summary of Potential Health Risk from PRP Emissions Cancer Risk (per million), (Receptor Location)
Chronic Hazard Index, (Receptor Location)
Acute Hazard Index, (Receptor Location)
Maximum Exposed Individual Residential (MEIR) – Between San Pablo Ave and Old County Road
1.528 (566104E, 4211597N)
0.0809 (566104E, 4211597N)
0.0259 (566104E, 4211597N)
Maximum Exposed Individual Worker (MEIW)
0.283 (565804E, 4211497N)
0.0889 (565804E, 4211497N)
0.0506 (566104E, 4211297N)
Maximum Sensitive Receptor – Day Care Center1
0.305 (564504E, 4210397N)
0.00165 (564504E, 4210397N)
0.0158 (564504E, 4210397N)
Type of Estimated Health Impact
1
Conservatively represents child exposure at a day care with a 70-year cancer risk.
The cancer risk for the maximally exposed individual residence (MEIR) is 1.528 per million and occurs at the residential community located between San Pablo Avenue and Old County Road. The cancer risk for the maximally exposed individual worker (MEIW) is 0.283 per million near the corner of 4th Street and B Street and to north of the facility boundary. The source that contributes the most to the modeled cancer risk at the MEIR is the refinery fuel gas-fired steam boiler. The contribution to the MEIR risk is 1.20 per million. Since this source contribution to risk is greater than 1 per million, Toxic Best Available Control Technology (TBACT) is required for the new steam boiler, per BAAQMD Regulation 25-301. None of the other sources contributing to the total MEIR cancer risk exceeded 1 per million. The emission estimates for the steam boiler were based on reasonably available factors and assuming 100 percent refinery fuel gas. In reality, the boiler would be fired on a combination of refinery fuel gas and natural gas to achieve the lowest possible emissions. The TACs that contribute the most to the modeled cancer risk are arsenic and benzo(a)pyrene. Both arsenic and benzo(a)pyrene are emitted by the boiler (the combustion source). The chronic hazard index for the respiratory system is highest impacted organ system at the MEIR and MEIW. The chronic hazard index at the ERM
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MEIW is predicted at 0.0889 near the corner of 4th Street and B Street and to north of the facility boundary. The chronic hazard index for the MEIR is 0.0809 and occurs at the residential community located between San Pablo Avenue and Old County Road. The acute hazard index is 0.0259 at the MEIR and 0.0506 at the MEIW. To address the potential for a one-hour offsite exposure higher than at the MEIR or MEIW, the point of maximum impact (PMI) for the acute hazard index was estimated at 0.0588, located at the fence line between the refinery and the Nu-Star Terminal.
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Figure 3: Maximum Risk Receptor Locations
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7.0
HEALTH RISKS FROM CONSTRUCTION
A quantitative health risk assessment of the TACs from PRP construction was not performed, as the PRP construction site is located farther than 1,000 feet from the nearest sensitive receptor. BAAQMD’s Screening Tables for Air Toxics Evaluation During Construction (BAAQMD 2010b) present a screening approach to conduct initial evaluations of potential health risks from exposure to TACs, such as DPM, generated during construction activities. As noted above, this screening criterion is based on the BAAQMD CEQA Guidelines that were adopted in June 2010 and updated in May 2011. Although some sections of these CEQA Guidelines are the subject of recent legal action, the thresholds and screening criteria are used in this analysis. The screening tables provide the minimum offset distance required between the fence line of a construction site and a nearby sensitive receptor to ensure that cancer and non-cancer risks associated with the project are less than significant per the BAAQMD’s significance thresholds. The minimum offset distance is based on the type (residential, commercial, or industrial) and the size of the project (square footage or acreage of construction). These screening tables were used to evaluate the health risks of TAC emissions from PRP’s construction. The construction of PRP will cover an area of approximately 2.6 acres, requiring a minimum offset distance 100 meters (328 feet) for an industrial project. This construction area is a part of the existing refinery and is surrounded by other refinery areas. The nearest sensitive and residential receptors are located farther than 328 feet from the refinery’s property boundary and farther than 1,000 feet from the actual construction area. Therefore, it can be concluded that the health risk impacts associated with PRP’s construction would be less than significant relative to the 2010/2011 BAAQMD CEQA Guidelines.
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8.0
REFERENCES
Bay Area Air Quality Management District (BAAQMD). 2011. California Environmental Quality Act Air Quality Guidelines. May. BAAQMD. 2010a. Air Toxics NSR Program Health Risk Screening Analysis (HRSA) Guidelines. January. BAAQMD. 2010b. Screening Tables for Air Toxics Evaluation During Construction. May. BAAQMD. 2005. Policy: Emission Factors for Toxic Air Contaminants from Miscellaneous Natural Gas Combustion Sources, Effective date: September 7, 2005. http://www.baaqmd.gov/~/media/Files/Engineering/policy_and_pr ocedures/TACEmFacfromNatGasCombustion.ashx California Air Pollution Control Officers Association (CAPCOA). 2009. Health Risk Assessments for Proposed Land Use Projects. July. CAPCOA/California Air Resources Board (CARB). 1999. California Implementation Guidelines for Estimating Mass Emissions from Fugitive Hydrocarbon Leaks at Petroleum Facilities. http://www.arb.ca.gov/fugitive/fugitive.htm. California Air Resources Board (CARB). 2003. Air Resources Board Recommended Interim Risk Management Policy for Inhalation-Based Residential Cancer Risk. October 9. http://www.arb.ca.gov/toxics/harp/docs/rmpolicy.PDF California Environmental Protection Agency, Office of Environmental Health Hazard Assessment (OEHHA). 2009. Technical Support Document for Cancer Potency Factors. June. California Environmental Protection Agency, Office of Environmental Health Hazard Assessment (OEHHA). 2003. Air Toxics Hot Spots Program Guidance Manual for Preparation of Health Risk Assessments. August. Energy and Environmental Research Corporation (EERC). 1998. Air Toxic Emission Factors for Combustion Sources Using Petroleum Based Fuels, Final Report, Volume II. August 14. ERM
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Sierra Research. 2004. Revised Inventory Guidance for Locomotive Emissions. Prepared for Southeastern States Air Resource Managers, Inc. Report No. SR2006-04-01. http://www.metro4sesarm.org/pubs/railroad/FinalGuidance.pdf. USEPA. 2009. Emission Factors for Locomotives. Office of Transportation and Air Quality. April. Report number EPA-420-F-09-025.
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Attachment 1 Toxic Air Contaminant Emissions
Attachment 2 AERMOD and HARP Files (on CD)
Appendix A Air Quality and Greenhouse Gas Emissions Documentation
APPENDIX A.4
BAAQMD Authority to Construct and Significant Revision to Major Facility Review Permit Application
Phillips 66 Propane Recovery Project Final Environmental Impact Report
November 2013
Rodeo Propane Recovery Project Prepared for: Phillips 66 Company
BAAQMD Authority to Construct and Significant Revision to Major Facility Review Permit Application Rodeo Refinery Rodeo, California February 2013 www.erm.com
Delivering sustainable solutions in a more competitive world.
Phillips 66 Company
Rodeo Propane Recovery Project BAAQMD Authority to Construct and Significant Revision to Major Facility Review Permit Application Phillips 66 Refinery Rodeo, California BAAQMD Facility No. A0016 February 2013 Project No. 0167855
Environmental Resources Management 1277 Treat Boulevard Suite 500 Walnut Creek, CA 94597 T: (925) 946-0455 F: (925) 946-9968
TABLE OF CONTENTS LIST OF TABLES
iv
LIST OF FIGURES
iv
LIST OF APPENDICES
v
LIST OF ACRONYMS
vi
1.0
INTRODUCTION
1
1.1 1.2 1.3 1.4 1.5
Facility Contact Information Project Overview Project Components Project Schedule Application Summary
1 1 2 2 2
2.0
FACILITY AND PROJECT DESCRIPTION
4
2.1 2.2
Facility Description Project Description
4 5
2.2.1 2.2.2 2.2.3 2.2.4 2.2.5 2.2.6
Refinery Fuel Gas Hydrotreating Refinery Fuel Gas LPG Recovery Unit and Associated Propane Treatment Propane Storage Butane Storage Railcar Loading Modification Associated Auxiliary Equipment Additions or Changes
5 6 6 6 6 7
2.3 2.4
Exempt Sources Sources Requiring ATC and Title V Operating Permits
7 8
3.0
EMISSION ESTIMATES
9
3.1
Boiler Emissions
9
3.1.1 3.1.2 3.1.3
Criteria Pollutant Emissions TAC Emissions Greenhouse Gas Emissions
9 11 13
3.2
Fugitive Component Emissions
13
3.2.1 3.2.2 3.2.3
POC Emissions TAC Emissions GHG Emissions
13 14 15
3.3
Transportation Emissions
15
3.3.1 3.3.2
Rail Shipments On-road Emissions
15 17
3.4
Fuel Gas Sulfur Emission Reduction Credits
17
ii
4.0
APPLICABLE REGULATIONS
18
4.1
BAAQMD Rules and Regulations
18
4.1.1 4.1.2
Regulation 1 – General Provisions and Definitions Regulation 2 – Permits
18 18
4.1.2.1 4.1.2.2 4.1.2.3 4.1.2.4
Rule 2-1 – General Requirements Rule 2-2 – New Source Review Rule 2-5 – New Source Review of Toxic Air Contaminants Rule 2-6 – Major Facility Review
18 19 23 26
4.1.3 4.1.4 4.1.5 4.1.6
Regulation 3 – Fees Regulation 6 – Particulate Matter and Visible Emissions Regulation 7 – Odorous Substances Regulation 8 – Organic Compounds
26 26 27 27
4.1.6.1 4.1.6.2 4.1.6.3 4.1.6.4 4.1.6.5
Rule 8-5 – Storage of Organic Liquids Rule 8-6 – Organic Liquid Bulk Terminals and Bulk Plants Rule 8-10 – Process Vessel Depressurization Rule 8-18 – Equipment Leaks Rule 8-28 – Episodic Releases from Pressure Relief Valves at Petroleum Refineries
4.1.7
Regulation 9 – Inorganic gaseous Pollutants
4.1.7.1 4.1.7.2 4.1.7.3
Rule 9-1 – Sulfur Dioxide Rule 9-2 – Hydrogen Sulfide Rule 9-10 – NOx and CO from Boilers, Steam Generators and Process Heaters in
4.1.8 4.1.9
Regulation 10 – Standards of Performance for New Stationary Sources Rule 11-12 – National Emission Standard for Benzene Emissions
28 29
4.2 4.3
California Environmental Quality Act Federal Rules and Regulations
29 29
4.3.1 4.3.2 4.3.3
40 CFR 52.21 – Prevention of Significant Deterioration of Air Quality 29 40 CFR 60 Subpart A – General Provisions 29 40 CFR 60 Subpart Db—Standards of Performance for Industrial-Commercial-Institutional Steam Generating Units 29 40 CFR 60 Subpart Ja—Standards of Performance for Petroleum Refineries for Which Construction, Reconstruction, or Modification Commenced After May 14, 2007 30 40 CFR 60 Subpart GGGa – Equipment Leaks of VOC in Petroleum Refineries for Which Construction, Reconstruction, or Modification Commenced After November 7, 2006 30 40 CFR 61 Subpart A – General Provisions 30 40 CFR 61 Subpart FF – Benzene Waste Operations NESHAP 30 40 CFR 63 Subpart A – General Provisions 31 40 CFR 63 Subpart CC – National Emission Standards for Petroleum Refineries 31 40 CFR 63 Subpart DDDDD—NESHAPS for Industrial, Commercial, and Institutional Boilers and Process Heaters 31
4.3.4 4.3.5 4.3.6 4.3.7 4.3.8 4.3.9 4.3.10
27 27 27 27 and Chemical Plants 28
28 28 28 Petroleum Refineries 28
5.0
ESTIMATED PERMIT FEES
32
6.0
REFERENCES
33
iii
LIST OF TABLES Table 3-1
Summary of PRP Emissions
Table 3-2.a
Criteria Pollutant Emissions from Natural Gas Combustion in Boiler
10
Table 3-2.b
Criteria Pollutant Emissions from RFG Combustion in Boiler
11
Table 3-3.a
TAC Emissions from Natural Gas Combustion in Boiler
11
Table 3-3.b
TAC Emissions from RFG Combustion in Boiler
12
Table 3-4
Fugitive Component Count, Emission Factors and POC Emissions
14
Table 3-5
TAC Emissions form Fugitive Components
15
Table 3-6
Locomotive Emissions
16
Table 3-7
Baseline Total Sulfur Content and SO2 Emissions for U233 RFG
17
Table 4-1
BACT Determination for Boiler
19
Table 4-2
BACT Determination for Fugitive Components
20
Table 4-3
Emission offsets
21
Table 4-4
Total Project Emissions for PSD Applicability
21
Table 4-5
Hazardous Air Pollutant Threshold Evaluation
22
Table 4-6
PRP TAC Emissions Compared to BAAQMD Trigger Levels
24
Table 4-7
Summary of Potential Health Risks from PRP Emissions
25
Table 5-1
Estimated PRP BAAQMD Permit Fees
32
LIST OF FIGURES Figure 2-1
Site Location Map
Figure 2-2
Aerial Map of the Facility
Figure 2-3
Site Plan on USGS Topographic Quadrangle Map
Figure 2-4
Location of Proposed Project Units
Figure 2-5
Flow Diagram of Existing Processes
iv
9
LIST OF APPENDICES APPENDIX A – EMISSIONS CALCULATIONS •
Attachment A-1 – Boiler Criteria Pollutant and GHG Emissions
•
Attachment A-2 – Boiler TAC Emissions
•
Attachment A-3 – Fugitive Component POC Emissions
•
Attachment A-4 – Fugitive Component TAC Emissions
•
Attachment A-5 – Locomotive Emissions
•
Attachment A-6 – On-road Vehicle Emissions
•
Attachment A-7 – Daily U233 Fuel Gas Data
APPENDIX B – BAAQMD PERMIT APPLICATION FORMS •
Attachment B-1 – Authority to Construct Forms
•
Attachment B-2 – Title V Permit Revision Forms
APPENDIX C – HEALTH RISK SCREENING ASSESSMENT •
Attachment C-1 – BAAQMD HRSA Form
•
Attachment C-2 – AERMOD and HARP Modeling Input and Output Files (on CD)
v
LIST OF ACRONYMS ATC
Authority to Construct
BAAQMD
Bay Area Air Quality Management District
BACT
Best Available Control Technology
Bbl
barrel
Btu
British thermal units
BWON
Benzene Waste Operations NESHAP
CARB
California Air Resources Board
CEQA
California Environmental Quality Act
CFR
Code of Federal Regulations
CO
carbon monoxide
CO2e
carbon dioxide equivalent
EIR
Environmental Impact Report
ERC
Emission reduction credit
°F
degrees Fahrenheit
GHG
greenhouse gas
H2S
hydrogen sulfide
HAP
hazardous air pollutant
HARP
Hot Spots Analysis and Reporting Program
HRSA
Health Risk Screening Assessment
LDAR
Leak Detection and Repair
M
thousand
MACT
Maximum Achievable Control Technology
MM
million
MMBtu/hr
million British thermal units per hour
NESHAP
National Emission Standards for Hazardous Air Pollutants
NOx
oxides of nitrogen
NPOC
non-precursor organic compound
OEHHA
Office of Environmental Health Hazard Assessment
PG&E
Pacific Gas and Electric Company
PM
particulate matter
PM10
particulate matter with aerodynamic diameters less than 10 micrometers
PM2.5
particulate matter with aerodynamic diameters less than 2.5 micrometers vi
POC
precursor organic compound
PSD
Prevention of Significant Deterioration
psi
per square inch
psia
pounds per square inch absolute
PTE
Potential to Emit
RFG
refinery fuel gas
ROG
reactive organic gases
RVP
Reid Vapor Pressure
SO2
sulfur dioxide
TAC
toxic air contaminant
TOG
total organic gases
ULSD
ultra-low sulfur diesel
USEPA
United States Environmental Protection Agency
VOC
volatile organic compound
vii
1.0
INTRODUCTION Phillips 66 Company, formerly known as ConocoPhillips, owns and operates an oil refinery located in Rodeo, California. Phillips 66 is proposing the Propane Recovery Project (PRP or “project”). The project will require a Bay Area Air Quality Management District (BAAQMD) Authority to Construct (ATC) and significant permit revisions to the Major Facility Review (Title V) Permit issued to the ConocoPhillips Company – Rodeo Refinery (Refinery), formerly the San Francisco Refinery (Facility # A0016) in Rodeo, California. The plant will be referred to as the Rodeo Refinery hereafter. The purpose of this document and its appendices is to provide information to the BAAQMD in support of the PRP and issuance of an ATC and revised Title V Permit. The project will also require a land use permit under the Contra Costa County Department of Conservation and Development. Approval of the land use permit will require compliance with the California Environmental Quality Act (CEQA), including preparation of an Environmental Impact Report (EIR). An application for a land use permit was been submitted to Contra Costa County on June 21, 2012 (ERM, 2012) and the County will act as lead agency for the preparation of the EIR.
1.1
Facility Contact Information Name/Address:
Phillips 66 Company 1380 San Pablo Avenue, Rodeo, California 94572-1299
BAAQMD Facility No.: A0016 Facility Contact:
1.2
Brent Eastep Environmental Engineer Phone: 510-245-4672 Fax: (510) 245-4512 e-mail:
[email protected]
Project Overview The primary objective of this project is to recover propane and butane from refinery fuel gas (RFG) and other process streams. The project will require modifying existing facilities and adding limited new facilities to recover propane and butane, to store propane and ship propane and butane by rail for sale. The project will involve hydrotreating a portion of the RFG, resulting in a reduction in the amount of sulfur compounds in the fuel gas, and ultimately, SO2 emissions to atmosphere from the refinery combustion sources. Phillips 66 is requesting emission reduction credits (ERCs) for the SO2 emission reductions. The propane recovery process will also result in an increase in the volume of butane that is currently recovered by the refinery. Most refineries recover liquid propane and butane for product sales. At the Rodeo refinery, only a portion of the butane is recovered and shipped by rail for sale. In the summer, up to 9,000 barrels per day are shipped by rail. The remaining propane and butane are used as fuel in the RFG system. The propane and butane removed from the
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RFG will be replaced with additional purchases of Pacific Gas & Electric Company (PG&E) natural gas to provide the heat input for the refinery processes. The project will be constructed on existing refinery property that is zoned as heavy industrial use, and the project is a permitted use within the heavy industrial zone. This proposal is a discretionary project that is not mandated by government regulation.
1.3
Project Components The proposed project involves adding and modifying processing and ancillary equipment at existing process units within the Phillips 66 Rodeo Refinery. These changes include the following: •
Refinery Fuel Gas Hydrotreating: A portion of the RFG contains sulfur compounds which are not removed by diglycolamine (DGA) treating. A new hydrotreater will be installed upstream of the Propane Recovery Unit (discussed below) and will improve propane product quality and decrease sulfur content in RFG. The hydrotreating unit will include new hydrotreater, reactors, and ancillary equipment, such as pumps, compressors, and valves.
•
LPG (Liquefied Petroleum Gas) Recovery Unit: New fractionation columns will be installed to recover propane and butane from the refinery fuel gas streams. Heat would be provided by steam and would involve the addition of a new steam boiler rated at approximately 140 million British thermal units per hour (MMBtu/hr). This boiler will be fired on a combination of natural gas and treated refinery fuel gas.
•
Propane Storage and Treatment: The recovered propane will be stored in six new pressurized storage tanks. A new propane treatment unit, consisting of amine and sodium hydroxide contactors and propane dryer, will be added to remove any remaining impurities in the propane prior to rail loading for delivery.
•
Railcar Loading Modification: Existing butane railcar operations will be modified to include propane loading. A new propane loading rack will be installed along with two new rail spurs.
•
Additions and modifications to ancillary facilities such as pumps, heat exchangers, instrumentation, utilities, and piping.
These additions and modifications would be located at several locations within the developed, active 495-acre area of Rodeo Refinery (See Figure 2-4).
1.4
Project Schedule Construction is currently scheduled to begin in June 2014 after all required permits are received. Startup would occur after the completion of construction, which is estimated to take approximately 12 months.
1.5
Application Summary The application and its attached appendices provide initial supporting information for the BAAQMD to evaluate the PRP. The remainder of this document is organized as follows:
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•
Section 2.0 (Facility and Project Description) provides an overview of the facility and presents the various elements of the project, including descriptions of project components;
•
Section 3.0 (Emissions Estimates) provides a summary of project emissions from various project components;
•
Section 4.0 (Applicable Regulations) addresses compliance with applicable BAAQMD and federal regulatory requirements;
•
Section 5.0 (Estimated Permit Fees) provides an estimate of BAAQMD New Source Review and Major Facility Review Permit fees;
•
Section 6.0 (References);
•
Appendix A – Emission Estimates;
•
Appendix B – BAAQMD Permit Application Forms; and
•
Appendix C – Health Risk Assessment.
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2.0 2.1
FACILITY AND PROJECT DESCRIPTION Facility Description The Phillips 66 Rodeo Refinery is located in unincorporated Contra Costa County, near the town of Rodeo, as shown on Figure 2-1. The refinery encompasses a total of 1,100 acres of land, consisting of the 495-acre active area of the refinery, where all its facilities and equipment are located, and another 600 acres of undeveloped areas. It is bordered by the Nustar Terminal to the north, and an undeveloped area to the east. To the south, beyond a 300- to 600-foot undeveloped area (property maintained as buffer areas between the active or developed portion of the refinery and adjacent land uses), is the Bayo Vista residential area. San Pablo Bay borders the refinery to the west. Interstate Highway 80 (I-80) and San Pablo Avenue run north-south through the refinery’s property. The property is zoned Heavy Industrial. Land uses to the northeast of the refinery are a combination of industrial and open space. To the east is primarily open space, and a combination of residential, light commercial, and light industrial uses are found to the south and southwest. As stated above, the Nustar Terminal (a fuel distribution terminal) lies to the north and San Pablo Bay to the west. The nearest sensitive receptor is a day-care facility in the Bayo Vista residential area, near the southern property boundary, south of the undeveloped buffer zone. Figures 2-2 and 2- 3 show an aerial and topography of the existing Phillips 66 Rodeo Refinery. The refinery consists of refining processes and support units that produce fuels, sulfur, and petroleum coke. The refinery’s principal activity is fuels manufacturing, wherein the facility converts crude oil and other feedstock into gasoline, jet fuel, diesel, and industrial fuels. Elements of the proposed project will be located at several locations within the 495acre developed active area of the refinery (see Figure 2-4). The project will be constructed on existing refinery property that is zoned as heavy industrial use, and the project is a permitted use within the heavy industrial zone. The Rodeo Refinery is designed and operated to refine a variety of domestic and foreign crude oils, such as heavy crudes from Central California and Canada as well as medium crude oils, such as Alaskan North Slope and Escalante. The crude oil is made into usable products such as gasoline, jet fuel, diesel fuel, sulfur, and petroleum coke. Electrical power, fuel gas, and steam are also created during the refining process. Crude oil is brought to the refinery via pipeline and marine tanker. Tankers dock at the refinery’s Marine Terminal, located at the northwestern edge of the facility. Numerous chemicals, materials, and utilities are required to produce useful products from the crude oil. Some chemicals, such as hydrogen, are produced at Rodeo Refinery or supplied by Air Liquide, which operates a Hydrogen Production Plant adjacent to the Refinery. Other feedstock, chemicals, and materials are purchased and transported to the facility. The refinery generates its own steam, fuel gas, and electricity, and purchases other resources, such as natural gas and water. PG&E supplies natural gas and electricity to the Rodeo Refinery. The East Bay Municipal Utilities District (EBMUD) supplies water. Figure 2-5 is an overall block flow diagram showing the Refinery’s existing production processes. Crude oil is sent to distillation units to make the first separation of crude oil into its various components. Additional processing takes place in a number of refinery units including coking, isomerization, hydrocracking, reforming, and blending units.
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The Refinery also operates a wastewater treatment plant for treating refinery-generated wastewater. Major equipment used for processing crude oil into finished products includes distillation columns, storage tanks, reactors, vessels, heaters, boilers, and other ancillary equipment.
2.2
Project Description The primary objective of this project is to recover LPGs (propane and butane) from RFG and other process streams. The LPG recovery process will result in an increase in the volume of butane that is currently recovered by the refinery. In addition, as described in Section 1.3, the project includes hydrotreating enhancements prior to fractionation that will remove more sulfur from feed streams, which will result in lower sulfur content in RFG after recovery of propane and butane. A detailed description of the project components discussed briefly in Section 1.3 is provided below. A simplified block flow diagram is provided in Figure 2-5 showing these project components relative to each other and to existing processes.
2.2.1
Refinery Fuel Gas Hydrotreating Current Operation The Unit 233 Fuel Gas Treatment Center removes H2S and other sulfur compounds from the process gas prior to its use as Refinery Fuel Gas in heaters, boilers and gas turbines. Refinery sour gases flow through collection headers to the fuel gas treatment system where an amine solution (DGA) is used to remove H2S and other sulfur compounds. Butane can be added to the Refinery Fuel Gas to increase the heat content. When the refinery produced fuel gases are insufficient to meet refinery heater firing demands, natural gas from PG&E is automatically added on pressure control. The DGA solution, however, is not effective at removing some sulfur compounds which are present in certain fuel gas streams. A portion of the treated Refinery Fuel Gas from Unit 233 is routed to the Merichem Unit for further sulfur removal. The Merichem Unit uses a caustic treating process to remove additional sulfur compounds from the Refinery Fuel Gas. The treated Refinery Fuel Gas from the Merichem Unit is used as fuel at three heaters added as part of the Ultra-Low Sulfur Diesel and Clean Fuels Expansion Projects to meet more strict fuel gas sulfur limits. Proposed Changes As shown in Figure 2-5, certain streams that contain sulfur compounds which are not removed by DGA treatment will be hydrotreated prior to processing at the LPG Recovery Unit as part of the proposed project. Hydrotreating will remove the sulfur compounds from the light hydrocarbon gases, which will not only clean and improve the quality of the propane and butane products, but will also reduce the sulfur in the remaining light hydrocarbon gases that become part of the refinery’s fuel gas system. Due to the amount of hydrogen present in the existing gas streams sent to the newly proposed Hydrotreater, no additional hydrogen will be necessary for the hydrotreating process. All necessary hydrogen is already present in the gas streams being hydrotreated. Therefore, there will be no impact on the existing refinery hydrogen plants.
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2.2.2
Refinery Fuel Gas LPG Recovery Unit and Associated Propane Treatment Proposed Changes A number of process vessels and equipment would be added to recover LPG (propane and butane) from the existing refinery fuel gas stream. The fractionation facilities would primarily be added at existing Process Unit 240. The process would require a small increase in energy consumption. Heat required by the process would be provided by steam from a new 140 MMBtu/hr steam boiler. This boiler will be fired on a combination of natural gas and treated refinery fuel gas. The project would be designed to recover approximately 4,200 barrels per day (bpd) of propane and 3,800 bpd of additional butane. Natural gas consumption would increase to replace the propane and butane recovered from the RFG. The additional natural gas would be purchased from PG&E. To meet propane product specifications, treatment facilities that use amines and sodium hydroxide would be added to remove any remaining impurities in the propane prior to rail loading for delivery.
2.2.3
Propane Storage Proposed Changes Six pressure tanks designed for storage of liquefied petroleum gases would be added. The combined (total) storage capacity of the vessels would be 15,000 bbls of propane. As shown in Figure 2-4, the propane storage tanks will be installed in a tank farm located west of San Pablo Avenue. This location allows for shorter piping runs and is further away from sensitive receptors, ignition sources, and public roadways compared to alternative sites. In addition, this location has access to key utilities such as fire water, steam, process sewers, and refinery flare gas system.
2.2.4
Butane Storage Current Operation The refinery currently has four butane storage spheres (Tank 300, 201, 302, and 833). Proposed Changes No new butane storage will be needed because the existing butane storage capacity will be sufficient to handle the increase in butane recovery.
2.2.5
Railcar Loading Modification Current Operation The refinery currently has loading racks on the western shore line of the refinery that can load butane into up to a maximum of 16 railcars per day. In particular, there are two Butane Loading Racks located at the Marine Terminal Complex. In the summer, 8 to 12 railcars (up to 9,000 barrels) of butane are typically loaded on any given day. In the winter, 3 to 4 railcars (2,300 to 3,000 bbl) are loaded per month. The average number of railcars loaded for the past three years is 4 railcars per day. ERM
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Proposed Changes The proposed project will add a new, two-sided loading rack and increase the overall amount of propane and butane that could be loaded. The new loading rack will be added to the existing butane railcar loading rack. This new loading facility would be designed to load a maximum of 20 additional railcars per day. The total maximum daily propane and butane loading capacity after the project would be 24 cars per day. On an annual average basis, the loading facility will be able to load an additional 12 railcars per day, resulting in a total of 16 railcars per day when added to the baseline. The existing butane loading capacity will be sufficient to accommodate the proposed increase in recovered butane. As part of this loading modification, two new rail spurs would be added with the capacity to hold 4 railcars on each spur. The new loading rack will be positioned between the two rail spurs.
2.2.6
Associated Auxiliary Equipment Additions or Changes Proposed Changes Additional piping would be needed outside the battery limits of the various process units. This additional piping consists of new lines or tie-ins to existing lines outside of the battery limit of the process units. These include new rundown lines needed to send products to storage and interconnecting lines between process units. Relief lines or blowdown tie-ins outside of the process units also are needed to bring individual plant relief loads to the existing relief system.
2.3
Exempt Sources Sources of negligible POC emissions for the proposed project include propane treatment unit, pressurized propane storage tanks, and propane and butane loading racks. Propane and butane will be treated, stored and hauled under pressure as liquefied petroleum gas (LPG). Pressure vessels are equipped with a pressure/vacuum vent that is set to prevent venting loss from boiling and breathing loss from daily temperature or barometric pressure changes. High-pressure storage tanks (higher than 15 psig), such as those used for storing LPG, can be operated so that virtually no evaporative or working losses occur. As a result, POC emissions from these processes/sources are expected to be negligible. These de minimis sources are also exempt from BAAQMD permit requirements. Pursuant to Rule 2-1-123.3.1, containers, reservoirs, tanks, or loading equipment used exclusively for storage or loading of liquefied gases are exempt from permitting requirements of Rules 2-1-301 and 2-1-302. Because the emissions from these exempt sources are expected to be negligible and because no appropriate methodologies are available to estimate emissions from pressurized vessels, emissions from these sources were not estimated for the purpose of this application. Cooling demands would be met with air cooling to the extent practical to reduce consumption of cooling water. The once-through non-contact cooling system, in which salt water is used in a couple of heat exchangers, may be used to cool the streams that require cooling below 130 °F. There will be no emissions from the cooling system. Nevertheless, the facility will comply with any applicable administrative, monitoring, and recordkeeping requirements for these exempt sources.
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2.4
Sources Requiring ATC and Title V Operating Permits Sources of substantial or quantifiable emissions for the proposed project include: 1.
Combustion emissions from one 140 MMBtu/hr boiler;
2.
Fugitive POC emissions from components in hydrocarbon service such valves, flanges, connectors, pumps, and compressors;
3.
Combustion emissions from locomotives
All stationary sources listed above will be subject to BAAQMD ATC and Title V operating permit requirements of Rules 2-1-301 and 2-1-302.1. Pursuant to Rule 2-1123.3.1, containers, reservoirs, tanks, or loading equipment used exclusively for storage or loading of liquefied gases are exempt from permitting requirements of Rules 2-1-301 and 2-1-302. Motor vehicles and non-road engines, such as locomotives, are exempt from permitting requirements of Rules 2-1-301 and 2-1-302, pursuant to the exemption criteria set forth in sections 2-1-113.1.3 and 2-1-114.2.4, respectively. Motor vehicles and non-road engines are also exempt from Title V permit requirements pursuant to Rules 2-6-112 and 2-6-114, respectively. However, criteria pollutant emissions from locomotives were estimated and included pursuant to Regulation 2-2-215.1.
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3.0
EMISSION ESTIMATES Emissions were estimated for all quantifiable emissions sources listed above in Section 2.4. Hourly, maximum daily, and average annual emissions from these sources were estimated to determine BAAQMD permitting requirements, including BACT, emission offsets, and PSD requirements. Daily mass emissions for stationary sources were estimated based on a 24-hours-per-day operation and average annual mass emissions were calculated based on a 24-hours-per-day and 365-days-per-year operation. Emissions from mobile sources were estimated based on number of daily trips and trip length. A summary of PRP emissions is presented in Table 3-1. Emissions from the Propane Recovery Unit Boiler are the maximum of those occurring due to natural gas or RFG combustion for respective pollutants. Calculation details are included in Appendix A.
Table 3-1
Summary of PRP Emissions Emissions (tons/year) Source Propane Recovery Unit Boiler Fugitive Components Locomotive
NOx
CO
PM10
PM2.5
SO2
POC
3.72
4.53
4.57
4.57
7.60
3.31
---
---
---
---
---
4.58
10.17
1.80
0.26
0.25
0.01
0.49
RFG Hydrotreating
-7.61
Total Incremental PRP Emissions
3.1
Boiler Emissions
3.1.1
Criteria Pollutant Emissions
13.89
6.34
4.83
4.82
0.0
8.38
The propane and butane recovery unit will require a new steam boiler rated at 140 MMBtu/hr of heat input. This boiler will be fired on a combination of natural gas and treated refinery fuel gas. The boiler is subject to BACT requirements per BAAQMD Rule 2-2-301 (Refer to Section 4.1.2). Controlled emissions for NOx and CO were estimated by converting the proposed limits of 5 ppmv NOx and 10 ppmv CO, both at 3%O2 dry (3-hour average), to emission factors in units of lb/MMBtu using the equation given below. NOx and CO emission factors are based on the use of an F-factor of 8,710 scf exhaust/MMBtu, molar volume (Vmolar) of 385.3 dry scf/mole of gas at 68 °F and 1 atm pressure, and molecular weight (MW) of the pollutant.
EF (lb / MMbtu ) =
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20.9 F − factor BACT ( ppmv) × MW × × 6 Vmolar 10 20.9 − O2 %
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Emission factors for PM10 and POC were obtained from AP-42, Chapter 1.4, Natural Gas Combustion. As suggested in the footnotes of Table 1.4-2, AP-42, Chapter 1.4, Natural Gas Combustion, a heating value of 1,020 Btu/scf for natural gas was used to convert emission factors from the units of lb/MMscf to lb/MMBtu and PM2.5 emissions were assumed to be equal to PM10 emissions. SO2 emission factor for natural gas combustion was also obtained from AP-42, Chapter 1.4, Natural Gas Combustion. SO2 emissions from treated RFG combustion are based on the proposed BACT limit of less than 100 ppmvd of total sulfur. SO2 emission factor for RFG combustion was calculated using the molecular weight of sulfur and SO2, molar volume of 385.3 dry scf/mole of gas at 68 °F and 1 atm pressure, and average higher heating value (HHV) of 1,340 Btu/scf for RFG in the following equation.
MWSO 2 1 1 106 Btu TS ( ppm) × MWS × × × × SO2 (lb / MMbtu ) = 106 MWS Vm HHV MMBtu Hourly mass emission rates for the boiler were determined by multiplying the “pounds per MMBtu” emission factor by the rated maximum heat input of the boiler. Daily mass emissions were estimated based on a 24-hours-per-day operation and average annual mass emissions were calculated based on a 24-hours-per-day and 365-days-per-year operation. Estimated emissions from natural gas combustion and RFG combustion are summarized in Tables 3-2.a and 3-2.b, respectively.
Table 3-2.a
Criteria Pollutant Emissions from Natural Gas Combustion in Boiler Emission Factor Pollutants
Emissions
lb/MMscf
lb/MMBtu
Hourly (lb/hr)
Daily (lb/day)
Annual (tons/yr)
NOx
(5 ppm)
0.0061
0.85
20.4
3.72
CO
(10 ppm)
0.0074
1.03
25
4.53
PM101
7.6
0.0075
1.04
25.0
4.57
PM2.52
7.6
0.0075
1.04
25.0
4.57
SO2
0.6
0.0006
0.08
1.98
0.36
5.5
0.0054
0.75
18.1
3.31
POC 1. 2.
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PM10 emissions factor = Condensable PM (5.7 lb/MMscf) + Filterable PM (1.9 bl/MMscf) PM2.5 was assumed to be equal to PM10. Per AP-42, Chapter 1.4, Natural Gas Combustion, Table 1.4-2 footnote - All PM (total, condensible, and filterable) is assumed to be less than 1.0 micrometer in diameter. Therefore, the PM emission factors presented here may be used to estimate PM10, PM2.5 or PM1 emissions.
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Table 3-2.b
Criteria Pollutant Emissions from RFG Combustion in Boiler Emission Factor Pollutants
lb/MMscf
lb/MMBtu
Hourly (lb/hr)
Daily (lb/day)
Annual (tons/yr)
NOx
(5 ppm)
0.0061
0.85
20.4
3.72
CO
(10 ppm)
0.0074
1.03
25
4.53
PM101
7.6
0.0057
0.79
19.1
3.48
PM2.52
7.6
0.0057
0.79
19.1
3.48
SO23
100 ppm TRS
0.0124
1.74
41.65
7.60
5.5
0.0041
0.57
13.8
2.52
POC 1. 2.
3.
3.1.2
Emissions
PM10 emissions factor = Condensable PM (5.7 lb/MMscf) + Filterable PM (1.9 bl/MMscf) PM2.5 was assumed to be equal to PM10. Per AP-42, Chapter 1.4, Natural Gas Combustion, Table 1.4-2 footnote - All PM (total, condensible, and filterable) is assumed to be less than 1.0 micrometer in diameter. Therefore, the PM emission factors presented here may be used to estimate PM10, PM2.5 or PM1 emissions. SO2 emission factor (lb/MMBtu) = TRS (ppm) x MW SO2 / (Vmolar x HVRFG), where MWSO2 = 64 lb/lb-mole Vmolar = 385.3 dscf/mole HVRFG = 1,340 Btu/scf
TAC Emissions TAC emissions from the natural gas combustion in the boiler were estimated using the emission factors provided in BAAQMD Policy: Emission Factors for Toxic Air Contaminants from Miscellaneous Natural Gas Combustion Sources, Effective date September 7, 2005. Ammonia emissions, due to ammonia slip from SCR at 15 ppmv, were also estimated using the methodology described in Section 3.1.1 for NOx and CO. Hourly mass emission rates for the boiler were determined by multiplying the “pounds per MMBtu” emission factor by the rated maximum heat input of the boiler. Average annual mass emissions were calculated based on a 24-hours-per-day and 365-days-peryear operation. Estimated TAC emissions from natural gas combustion are summarized in Table 3-3.a.
Table 3-3.a
TAC Emissions from Natural Gas Combustion in Boiler Emission Factor
Emissions Hourly Annual (lb/hr) (lb/year)
CAS Number
Pollutant
7664-41-7
Ammonia1
6.87E+00
6.73E-03
9.42E-01
8.25E+03
71-43-2
Benzene2
2.10E-03
2.06E-06
2.88E-04
2.52E+00
50-00-0
Formaldehyde2
7.50E-02
7.35E-05
1.03E-02
9.02E+01
3.40E-03
3.33E-06
4.67E-04
4.09E+00
108-88-3
2
Toluene
lb/MMscf
lb/MMBtu
1. Ammonia from SCR ammonia slip at 15 ppmvd @ 3% O2 2. BAAQMD Policy: Emission Factors for Toxic Air Contaminants from Miscellaneous Natural Gas Combustion Sources, Effective date September 7, 2005, http://www.baaqmd.gov/~/media/Files/Engineering/policy_and_procedures/TACEmFacfromNatGasCombusti on.ashx
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TAC emissions from the RFG combustion in the boiler were estimated using the emission factors provided in Appendix B of EERC August 14, 1998 document - Air Toxic Emission Factors for Combustion Sources Using Petroleum Based Fuels, Final Report, Vol. II. Ammonia emissions, due to ammonia slip from SCR at 15 ppmv, were estimated using the methodology described in Section 3.1.1 for NOx and CO. Hourly mass emission rates for the boiler were determined by multiplying the “pounds per MMBtu” emission factor by the rated maximum heat input of the boiler. Average annual mass emissions were calculated based on a 24-hours-per-day and 365-days-peryear operation. Estimated TAC emissions from RFG combustion are summarized in Table 3-3.b.
Table 3-3.b
TAC Emissions from RFG Combustion in Boiler
CAS Number
Emission Factor1
Pollutant 2
Emissions
lb/MMBtu
Hourly (lb/hr)
Annual (lb/year)
7664-41-7
Ammonia
6.73E-03
9.42E-01
8.25E+03
83-32-9
Acenaphthene
2.36E-09
3.30E-07
2.89E-03
208-96-8
Acenaphthylene
1.55E-09
2.17E-07
1.90E-03
75-07-0
Acetaldehyde
1.53E-05
2.14E-03
1.88E+01
7440-36-0
Antimony
5.17E-07
7.24E-05
6.34E-01
7440-38-2
Arsenic
8.50E-07
1.19E-04
1.04E+00
(0) ND
0.00E+00
0.00E+00
7440-39-3
Barium
3
71-43-2
Benzene
6.47E-05
9.06E-03
7.93E+01
56-55-3
Benzo(a)anthracene
3.21E-08
4.49E-06
3.94E-02
50-32-8
Benzo(a)pyrene
8.96E-08
1.25E-05
1.10E-01
205-99-2
Benzo(b)fluoranthene
4.04E-08
5.66E-06
4.95E-02
3
191-24-2
Benzo(g,h,i)perylene
(0) ND
0.00E+00
0.00E+00
207-08-9
Benzo(k)fluoranthene
2.41E-08
3.37E-06
2.96E-02
(0) ND
0.00E+00
0.00E+00
9.88E-07
1.38E-04
1.21E+00
3
7440-41-7
Beryllium
7440-43-9
Cadmium 3
18540-29-9
Chromium (Hex)
(0) ND
0.00E+00
0.00E+00
7440-47-3
Chromium (Total)
1.07E-06
1.50E-04
1.31E+00
218-01-9
Chrysene
1.63E-09
2.28E-07
2.00E-03
7440-50-8
Copper
4.21E-06
5.89E-04
5.16E+00
(0) ND
0.00E+00
0.00E+00
3
53-70-3 100-41-4
Dibenz(a,h)anthracene Ethylbenzene
3.02E-05
4.23E-03
3.70E+01
206-44-0
Fluoranthene
3.06E-09
4.28E-07
3.75E-03
86-73-7
Fluorene
1.08E-08
1.51E-06
1.32E-02
50-00-0
Formaldehyde
1.11E-04
1.55E-02
1.36E+02
3
7783-06-4
Hydrogen Sulfide
(0) ND
0.00E+00
0.00E+00
193-39-5
Indeno(1,2,3-cd)pyrene
1.03E-07
1.44E-05
1.26E-01
7439-92-1
Lead
4.89E-06
6.85E-04
6.00E+00
7439-96-5
Manganese
6.81E-06
9.53E-04
8.35E+00
7439-97-6
Mercury
1.80E-07
2.52E-05
2.21E-01
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CAS Number
Emission Factor1
Pollutant
Emissions
lb/MMBtu
Hourly (lb/hr)
Annual (lb/year)
91-20-3
Naphthalene
3.13E-07
4.38E-05
3.84E-01
7440-02-0
Nickel
9.42E-06
1.32E-03
1.16E+01
85-01-8
Phenanthrene
1.46E-08
2.04E-06
1.79E-02
108-95-2
Phenol
5.63E-06
7.88E-04
6.90E+00
3
7723-14-0 115-07-1
Phosphorus
(0) ND
0.00E+00
0.00E+00
Propylene
2.17E-06
3.04E-04
2.66E+00
129-00-0
Pyrene
2.48E-09
3.47E-07
3.04E-03
7782-49-2
Selenium
1.96E-08
2.74E-06
2.40E-02
7440-22-4
Silver
1.61E-06
2.25E-04
1.97E+00
(0) ND
0.00E+00
0.00E+00
3
7440-28-0
Thallium
108-88-3 1330-20-7
Toluene
1.07E-04
1.50E-02
1.31E+02
Xylene (Total)
3.73E-05
5.22E-03
4.57E+01
7440-66-6
Zinc
2.08E-05
2.91E-03
2.55E+01
1. Emission factors for TAC other than ammonia were obtained from Appendix B of EERC August 14, 1998 document "Air Toxic Emission Factors for Combustion Sources Using Petroleum Based Fuels, Final Report, Vol. II". 2. Ammonia from SCR ammonia slip at 15 ppmvd @ 3% O2 3. Emission factors presented in the EERC document for these compounds were all based entirely on non-detect analytical values, therefore an emission factor of zero has been substituted based on CAPCOA health risk assessment guidelines.
3.1.3
Greenhouse Gas Emissions Combustion of natural gas or RFG in the boiler will result in greenhouse gas (GHG) emissions of carbon dioxide (CO2), methane (CH4), and nitrous oxide (N2O). Emissions of these GHGs were estimated by multiplying the heat input rate of the boiler with the respective emission factors for natural gas and RFG combustion. GHG emissions for natural gas combustion were obtained from AP-42, Chapter 1.4, Natural Gas Combustion. GHG emissions for RFG combustion were obtained from obtained from the Compendium of Greenhouse Gas Emissions Methodologies for the Oil and Natural Gas Industry, Tables 4-3 and 4-6, (API 2009). CO2 equivalent (CO2e) emissions were calculated as the sum of the product of particular GHG emissions and its respective global warming potential. The CO2e emissions from natural has combustion in the boiler were estimated to be 72,580 tons per year. The CO2e emissions from RFG combustion in the boiler were estimated to be 74,014 tons per year. Calculation details are included in Appendix A.
3.2
Fugitive Component Emissions
3.2.1
POC Emissions New process equipment associated with the PRP will emit fugitive POC from various components including valves, flanges, connectors, pumps, and compressors. The number of new fugitive components for the PRP is estimated based on pre-design drawing handcount, comparison to existing units, Phillips 66 experience in construction of similar ERM
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units, and other estimation techniques. Table 3-4 provides an estimated fugitive component count, combined for all the process units of the PRP. These component counts were used to estimate fugitive POC and TAC emissions from the proposed PRP. There will not be any new open-ended lines for sampling or other purposes. Fugitive POC emissions were estimated based on U.S. EPA Correlation Equations as presented in Table IV-3a of the February 1999 California Air Resources Board/California Air Pollution Control Officers Association (CARB/CAPCOA) document entitled California Implementation Guidelines for Estimating Mass Emissions of Fugitive Hydrocarbon Leaks at Petroleum Facilities (CARB/CAPCOA, 1999). The screening values used for valves, flanges, connectors, pump, and compressors and the corresponding correlation equations are shown in Table 3-4. The screening value (SV) in each Correlation Equation is consistent with the maximum leak rate allowed under the BAAQMD guidelines as a “BACT-1” level. Table 3-4 also displays resulting emission factors in kg/hr per source. Using the Correlation Equation approach and screening values, the resulting emission factors for each component type are the same for each type of service (gas, light liquid, and heavy liquid). Table 3-4 summarizes the total fugitive component POC emissions for all of the process units. Calculation details can be found in Appendix A.
Table 3-4
Fugitive Component Count, Emission Factors and POC Emissions
Correlation Equation
Screening Value, SV1 (ppmv)
Emission Factor (kg/hr/ source)
Component Count
Hourly POC (lb/hr)
Daily POC (lb/day)
Annual POC (tons/yr)
Valves/All
2.27E-6*(SV)^0.747
100
7.1E-05
2,810
0.44
10.5
1.92
Connectors/All
1.53E-6*(SV)^0.736
100
4.5E-05
5,620
0.56
13.5
2.46
Pump Seals/All
5.07E-5*(SV)^0.622
100
8.9E-04
16
0.03
0.75
0.14
Component Type/Service
Other2 (PRVs + 8.69E-6(SV)^0.642 100 1.7E-04 44 0.02 0.39 0.07 Compressors)/All Total - All ------8,490 1.05 25.1 4.58 Components 1. Screening Values are consistent with the maximum allowed leak rate by BAAQMD guidelines for BACT. 2. The “other” component type includes instruments, loading arms, pressure relief valves, vents, compressors, dump lever arms, diaphragms, drains, hatches, meters, and polished rods stuffing boxes. This “others” component type should be applied for any component type other than connectors, flanges, open-ended lines, pumps, or valves.
3.2.2
TAC Emissions Fugitive TAC emissions from component leaks were estimated using the speciation profile of refinery fuel gas provided by Phillips 66. Mass fractions of various TACs in the refinery fuel gas were estimated by multiplying their mole (volume) fraction (provided in the speciation profile) by the ratio of the respective TAC’s molecular weight to the molecular weight of the refinery fuel gas. The estimated TAC mass fractions were multiplied by the estimated fugitive POC emissions to calculate the TAC emissions. The following equation describes the above methodology for each TAC (x). Annual emissions were estimated assuming an 8,760 hours per year of operation. TAC emissions from component leaks are shown in Table 3-5. Details of the calculations are shown in Appendix A.
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TAC x (lb / hr ) = Table 3-5
Mole Fraction x ( ppmv) MWx × × POC (lb / hr ) MWRFG 10 6
TAC Emissions form Fugitive Components Emissions CAS Number ---
Pollutant POC or ROG2 3
Mass Fraction1
Hourly (lb/hr)
Annual (lb/yr)
1.00E+00
1.05
9163
7783-06-4
Hydrogen Sulfide
8.71E-04
9.11E-04
7.98E+00
75-15-0
Carbon disulfide
1.36E-06
1.42E-06
1.24E-02
115-07-1
Propylene
2.57E-02
2.69E-02
2.35E+02
106-99-0
1,3-Butadiene
2.25E-04
2.35E-04
2.06E+00
71-43-2
Benzene
9.97E-04
1.04E-03
9.13E+00
5.38E-02
5.63E-02
4.93E+02
110-54-3
4
Other C6+
1. Product of first two terms in equation preceding Table 3-5. 2. POC emissions estimated based on U.S. EPA Correlation Equations in Table IV-3a of the CARB/CAPCOA document entitled California Implementation Guidelines for Estimating Mass Emissions of Fugitive Hydrocarbon Leaks at Petroleum Facilities. 3. All total reduced sulfur compounds in RFG were assumed to be hydrogen sulfide. 4. All other C6+ compounds were assumed to be n-Hexane.
3.2.3
GHG Emissions All POC emissions from fugitive components were conservatively assumed to be methane. The POC emissions were multiplied by the global warming potential of methane (21) to estimate CO2e emission. Estimated CO2e emissions from fugitive components are equal to 96 tons per year.
3.3
Transportation Emissions Additional propane and butane recovered after the implementation of the proposed project will be transported by railcars. Rail traffic will increase by an average of 12 railcars per day (on an annual average basis) and a maximum of 20 railcars per day (on a maximum daily basis). Worker commute traffic will increase by 2 trips per day. Incremental emission estimates from additional railcars and vehicle trips required for this project are presented below.
3.3.1
Rail Shipments An estimated 12 additional railcars per day on an annual average basis will be required to ship the propane and butane recovered by PRP, resulting in a total of 16 railcars when added to the annual average baseline. On any given day, the maximum number of additional railcars could increase by 20, resulting in a total of 24 railcars when added to the baseline. Emissions associated with increased locomotive engine load due to these additional railcars on existing train trips were calculated within the BAAQMD for the purpose of estimating offset requirements. Criteria pollutant emission factors for locomotives, in grams per gallon fuel consumed, were obtained from the EPA document – Emission Factors for Locomotives, Technical Highlights, EPA-420-F-09-025, April 2009. Emission factors for the year 2015, when the ERM
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project first becomes operational, were used in the calculation. Emissions were estimated for three types of locomotive operation – switching, small-line haul, and large-line haul. Switching involves use of low power locomotive engines to shuttle loaded and unloaded railcars within the facility. Small-line haul also involves use of low power locomotive engines to haul short trains between the facility and the rail yard. It was assumed that the railcars from the Rodeo refinery will be hauled to the Richmond Rail Yard, where they would be combined with other railcars to form a longer train. Large-line haul involves use of high power locomotive engines to haul long trains over long distances. Large-line hauling was assumed from Richmond Rail Yard to the BAAQMD border. Quantity of fuel consumed for line haul was estimated by dividing the product of gross weight hauled and track length by a fuel consumption index in terms of gross ton-miles per gallon, as derived from Union Pacific (UP) and Burlington Northern Santa Fe (BNSF) data. Gross weight hauled includes weight of the compressed gas freight and tare weight of railcars. For the total track length travelled within the BAAQMD, 50% of the trains are assumed to travel on the UP routing and 50% on the BNSF routing. The lengths of the UP and BNSF routes from the Refinery to the southern and eastern borders of the BAAQMD, respectively, were measured using Google Earth. Track length between the facility and Richmond Rail Yard was also measured using Google Earth. To account for switching emissions, one hour of activity per day at the Phillips Refinery was assumed. The following equation describes the above methodology.
Emissionsi (lb / yr ) = EFi , x ×
GW × Lx FCI × 453.6
where: i = Any pollutant x = operation mode (large-line haul or small-line haul) EFi = Emission factor of pollutant i for x mode of operation (g/gallon of fuel) GW = Annual gross weight hauled = Weight of freight + weight of empty tank cars (tons/year) L = Average Track Length for x mode of operation (miles) FCI = Fuel consumption index = 928 gross ton-miles/gallon of fuel. Table 3-6 presents a summary of locomotive emissions. Detailed emissions calculation is provided in Appendix A.
Table 3-6
Locomotive Emissions Emissions (tons/year) Track Segment
Operation Type
CO
ROG
NOx
SOx
PM10
PM2.5
Phillips 66 to Richmond Yard
Small-Line Haul
0.24
0.13
2.46
0.001
0.06
0.05
Richmond Yard to BAAQMD Border
Large-Line Haul
1.52
0.34
7.39
0.005
0.19
0.19
Switch
0.04
0.02
0.33
0.0001
0.01
0.01
1.80
0.49
10.17
0.01
0.26
0.25
Phillips 66 Total Emissions
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3.3.2
On-road Emissions As a result of the PRP, the number of worker commute trips will increase by 2 trips per day. Motor vehicles do not require an ATC and PTO. Fugitive dust emissions from additional worker commute traffic were estimated as explained below. Most of the vehicle travel will occur on paved roads. Fugitive paved road dust emissions due to these additional motor vehicle trips were estimated using the predictive emission factor equation and defaults provided in AP-42, Chapter 13.2.1, Paved Roads. Default oneway trip length of 9.5 miles for Commercial-Work (C-W) trip for BAAQMD/SF Air Basin/Contra Cost County from CalEEMod was used as the trip length for estimating emissions from additional worker commute related to the project. It is estimated that fugitive PM10 emissions will increase by 0.01 lbs/day (0.002 tons/year). Fugitive PM2.5 emissions will increase by 0.003 lbs/day (0.001 tons/year). Calculations are shown in Appendix A.
3.4
Fuel Gas Sulfur Emission Reduction Credits The combustion of post-project RFG along with supplemental PG&E natural gas in other refinery operations will result in lower refinery-wide SO2 emissions. Hydrotreating would reduce the total sulfur in post-project RFG and decrease SO2 emissions by at least half, resulting in an SO2 emissions decrease of at least 180 tons per year. This is based on average SO2 emissions to atmosphere of 360 tons per year from the combustion of Unit 233 refinery fuel gas for the 3-year baseline period from December 2009 to November 2012. The current baseline SO2 emissions and total sulfur in RFG are shown in Table 3-7 below. Data for daily total sulfur content and usage for Unit 233 RFG over the baseline period is provided in Appendix A. Philips 66 requests 174.7 tons per year of SO2 emission reduction credits (ERCs) for this reduction. Of this amount, 7.61 tpy will be used to offset project SO2 increases so that there will be no net increase in SO2 emissions from the project (see Table 3-1). The remaining 167.1 tpy of SO2 (174.7 tpy minus 7.61 tpy) will be banked as ERCs. This amount is based on taking a new limit on annual average total sulfur concentration in the fuel gas of 200 ppm. Post project refinery fuel gas combustion mass emissions of SO2 would be 185 tpy, which is a 174.7 tpy reduction from the 3-year baseline.
Table 3-7
Baseline Total Sulfur Content and SO2 Emissions for U233 RFG U233 Fuel Gas (Baseline) Period
SO2 (tpy)
Total S (ppm)
RFG Usage (MMscf/day)
Dec '09 - Nov '10
408.8
405.5
33.0
Dec '10 - Nov '11
341.4
370.4
29.3
Dec '11 - Nov '12
329.0
399.4
27.1
3-year Average Dec '09 - Nov '12
359.7
391.8
29.8
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4.0
APPLICABLE REGULATIONS Prior to issuance of an ATC, the BAAQMD must determine that the proposed project will comply with applicable air quality rules and regulations, including both BAAQMD and federal requirements. This section presents a discussion of each applicable air quality requirement and documentation that the PRP complies with all requirements.
4.1
BAAQMD Rules and Regulations
4.1.1
Regulation 1 – General Provisions and Definitions Section 1-301 of Regulation 1 prohibits discharge from any source such quantities of air contaminants or other material that cause injury, detriment, nuisance, or annoyance to any considerable number of persons or the public; or that endangers the comfort, repose, health or safety of any such person or the public; or that causes or has a natural tendency to cause injury or damage to business or property. The PRP will be operated in accordance with all federal and BAAQMD rules and regulations, and is not expected to cause a public nuisance.
4.1.2
Regulation 2 – Permits
4.1.2.1
Rule 2-1 – General Requirements
4.1.2.1.a
Section 2-1-123 – Exemption, Liquid Storage and Loading Equipment Pursuant to Rule 2-1-123.3.1, containers, reservoirs, tanks or loading equipment used exclusively for storage or loading of liquefied gases are exempt from BAAQMD’s permit requirements, provided the sources do not require permitting pursuant to Section 2-1319. Therefore, as noted above in Section 2.3, propane treatment unit, pressurized propane storage tanks, and propane and butane loading racks will be exempt from the BAAQMD’s permit requirements.
4.1.2.1.b
Section 2-1-301 – Authority to Construct Unless otherwise exempted, an ATC must be obtained from the BAAQMD prior to building, modifying, or replacing any emissions unit or control device. Some of the equipment of the proposed PRP will emit regulated air contaminants and is not exempt under any of the sections of Regulation 2-1. Therefore, this equipment is subject to the requirements of Section 2-1-301 to obtain an ATC from the BAAQMD prior to implementation of this project. ATC permit forms for the PRP are presented in Appendix B, Attachment B-1, in accordance with Section 2-1-402.
4.1.2.1.c
Section 2-1-302 – Permit to Operate In accordance with Section 2-1-302, a Permit to Operate must be obtained from the BAAQMD prior to using or operating any article, machine, equipment, or other contrivance, the use of which may cause, reduce or control emissions of air contaminants. After construction of any equipment associated with the proposed project is complete in accordance with the ATC, Phillips 66 will notify the BAAQMD that it is ready to commence operation. Operation of the proposed project will only commence once Phillips 66 has received a Permit to Operate or a temporary authorization to operate the project in accordance with the ATC.
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4.1.2.1.d
Section 2-1-412 – Public Notice, Schools Section 2-1-412 requires public notice if the new or modified source is located within 1,000 feet of any K-12 school. The proposed sources will be installed within the existing refinery boundaries and are not within 1,000 feet of any school.
4.1.2.2
Rule 2-2 – New Source Review BAAQMD Rule 2-2, New Source Review, applies to all new and modified sources that are subject to ATC requirements. The proposed project is potentially subject to several sections of Rule 2-2.
4.1.2.2.a
Section 2-2-301 – Best Available Control Technology Section 2-2-301 requires that BACT be used to control emissions from any new source with the potential to emit 10 pounds per day or more of NPOCs or POCs, NOx, SO2, PM10, or CO. BACT is pollutant and source specific. POC, NOx, CO, and PM10 emissions from the proposed boiler and POC emissions from fugitive components trigger BACT requirements. Table 4-1 shows the BACT determinations for the proposed boiler. BACT was determined based on the BAAQMD BACT guideline 17.3.1 for boilers with more than 50 MMBtu/hr heat input and the BACT determination for a previously permitted heater (S-45) for the Clean Fuels Expansion Project (CFEP).
Table 4-1
BACT Determination for Boiler Pollutant
BACT
Technology
Reference
NOx
5 ppmv @ 3% O2 (3hr average)
Low-NOx burner and SCR
BAAQMD BACT Determination for S45 heater for CFEP Project U246 (Application 13424)
CO
10 ppmv @ 3% O2 (3hr average)
Good combustion practices in conjunction with SCR system or ultra low Nox burners and FGR
BAAQMD BACT Determination for S45 heater for CFEP Project U246 (Application 13424)
PM10
7.6 lb/MMscf
Use of pipeline quality natural gas/Fuel Selection
AP-42, Chapter 1.4, Natural Gas Combustion
POC
5.5 lb/MMscf
Good combustion practices
AP-42, Chapter 1.4, Natural Gas Combustion
NH3
15 ppmv @ 3% O2 (8hr average)
SO2
100 ppmvd total sulfur in RFG or use of pipeline quality natural gas
BAAQMD BACT Determination for S45 heater for CFEP Project U246 (Application 13424) Use of pipeline quality natural gas/treated RFG
BAAQMD BACT Determination for S45 heater for CFEP Project U246 (Application 13424)
BACT limits proposed for fugitive components are shown in Table 4-2. In addition to the BACT limits, these components will also be subject to BAAQMD approved inspection and maintenance program. After construction of the proposed units associated with the PRP, an actual count of fugitive components will be conducted when the new components are added to the Phillips 66’s LDAR program. This information will be provided to the BAAQMD to
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determine if any adjustments are needed for compliance with applicable requirements (i.e., a possible change in the quantity of required emission offsets).
Table 4-2 Component Type
BACT Determination for Fugitive Components Leak Definition
Technology
Reference
Valves
100 ppm expressed as methane
Bellows Valves; Diaphragm Valves; Quarter Turn Valves; Live Loaded Valves; or Other Low-Emission Valves
BACT(2) Guideline 136.1, Condition 23725 Title V Permit
Connectors
100 ppm expressed as methane
Graphitic Gaskets
BACT(2) Guideline 78.1, Condition 23725 Title V Permit
Flanges
100 ppm expressed as methane
Graphitic Gaskets
BACT(2) Guideline 78.1, Condition 23725 Title V Permit
Pumps
100 ppm expressed as methane
Double Mechanical Seals w/ Barrier Fluid; Magnetically Coupled Pumps; Canned Pumps; Magnetic Fluid Sealing Technology; or Gas Seal System Vented to Thermal Oxidizer or Other BAAQMD Approved Control Device;
BACT(1) Guideline 137.1, Condition 23725 Title V Permit
Compressors
100 ppm expressed as methane
Double Mechanical Seals w/ Barrier Fluid; or Gas Seal System Vented to a Thermal Oxidizer or Other BAAQMD Approved Control Device;
BACT(1) Guideline 48B.1, Condition 23725 Title V Permit
Vent to fuel gas recovery system, furnace, or flare with a recovery/destruction efficiency>98%
BACT(2) Guideline 135.1, Condition 23725 Title V Permit
Pressure Relief Devices
4.1.2.2.b
Section 2-2-302 and 2-2-303 – Project Emission Offsets In accordance with Section 2-2-302, POC and/or NOx emission offsets must be provided for a new or modified source at a facility that emits or will be permitted to emit 35 tons per year or more, on a pollutant specific basis, of POCs or NOx (minus any contemporaneous emission reduction credits) at a 1.15 to 1.0 ratio. The Phillips 66 Rodeo Refinery emits in excess of 35 tons per year of POCs and NOx. Pursuant to Section 2-2-303, PM10 and/or SO2 emission offsets must be provided for a new or modified source of PM10 or SO2 located at a Major Facility, which will result in a cumulative increase minus any contemporaneous emission reduction credits at the facility, for that pollutant, in excess of 1.0 ton per year. Emission offsets must be provided for the emission from the new or modified source and any pre-existing cumulative increase minus any onsite contemporaneous emission reduction credits, at a 1.0:1.0 ratio. The Phillips 66 Rodeo Refinery is a Major Facility and the net emission increase for PM10 and SO2 will be in excess of 1.0 tons per year. For new and modified sources, emission increases must be calculated in accordance with Sections 2-2-604 and 2-2-605. BAAQMD regulations do not require offsets for CO emissions. BAAQMD offset requirements are summarized in Table 4-3.
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Table 4-3
4.1.2.2.c
Emission offsets
Pollutant
Project Emission Increase (tons/year)
Offset Ratio
Required Offsets (tons/yr)
NOx
13.9
1.15
16.0
POC
8.38
1.15
9.6
PM10
4.8
1
4.8
SO2
0.0
1
0.0
CO
6.3
Not required
Not required
Section 2-2-304 through 2-2-306 – PSD Requirement The Phillips 66 Rodeo refinery is a major source under PSD. In order to determine whether the proposed PRP modifications are significant, an accounting of emission increases is compared to PSD significance levels for each criteria pollutant. Emissions from cargo carriers are not considered as part of the facility emissions when determining applicability of PSD per Section 2-2-215.2. Table 4-4 summarizes these emissions and compares the total for each criteria pollutant to the PSD significance levels. This comparison shows that the significance levels are not exceeded for any of the regulated pollutants.
Table 4-4
4.1.2.2.d
Total Project Emissions for PSD Applicability
Pollutant
Project Emission Increases (tons/year)
PSD Applicability Significance Thresholds (tons/year)
PSD Major Modification (Yes/No)
NOx
3.7
40
No
POC
7.9
40
No
PM10
4.6
15
No
SO2
0.0
40
No
CO
4.5
100
No
Section 2-2-317 – Maximum Achievable Control Technology Requirement In accordance with Section 2-2-317, the Air Pollution Control Officer shall not issue an ATC for a new or modified source at a Major Facility of hazardous air pollutants (HAPs) unless the source will meet Best Available Control Technology for Toxics (TBACT), except as provided in Section 2-2-114. Section 2-2-114 allows an exemption from Section 2-2-317 when the combined increase in PTE from all related sources in a proposed construction or modification is less than 10 tons per year of any HAP and less than 25 tons per year of any combination of HAPs. As shown in Table 4-5, the increase in HAP emissions from the PRP equipment is less than 10 tons per year of any HAP and less than 25 tons per year of all HAPs combined. Therefore, TBACT is not required for the PRP emission sources pursuant to Section 2-2-317.
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Table 4-5
Hazardous Air Pollutant Threshold Evaluation
Hazardous Air Pollutant
CAS Number
Net Project Emissions (tons per year)
HAP Threshold (tons per year)
HAP Threshold Exceeded? (Yes/No)
1,3-Butadiene
106-99-0
1.03E-03
10
No
Acenaphthene
83-32-9
1.45E-06
10
No
Acenaphthylene
208-96-8
9.50E-07
10
No
Acetaldehyde
75-07-0
9.38E-03
10
No
Ammonia
7664-41-7
4.13E+00
10
No
Antimony
7440-36-0
3.17E-04
10
No
Arsenic
7440-38-2
5.21E-04
10
No
Barium
7440-39-3
0.00E+00
10
No
Benzene
71-43-2
4.42E-02
10
No
Benzo(a)anthracene
56-55-3
1.97E-05
10
No
Benzo(a)pyrene
50-32-8
5.49E-05
10
No
Benzo(b)fluoranthene
205-99-2
2.48E-05
10
No
Benzo(g,h,i)perylene
191-24-2
0.00E+00
10
No
Benzo(k)fluoranthene
207-08-9
1.48E-05
10
No
Beryllium
7440-41-7
0.00E+00
10
No
Cadmium
7440-43-9
6.06E-04
10
No
Carbon disulfide
75-15-0
6.21E-06
10
No
Chromium (Hex)
18540-29-9
0.00E+00
10
No
Chromium (Total)
7440-47-3
6.56E-04
10
No
Chrysene
218-01-9
1.00E-06
10
No
Copper
7440-50-8
2.58E-03
10
No
Dibenz(a,h)anthracene
53-70-3
0.00E+00
10
No
Diesel Particulate Matter
99-0-1
1.97E+00
10
No
Ethylbenzene
100-41-4
1.85E-02
10
No
Fluoranthene
206-44-0
1.88E-06
10
No
Fluorene
86-73-7
6.62E-06
10
No
Formaldehyde
50-00-0
6.81E-02
10
No
Hydrogen Sulfide
7783-06-4
3.99E-03
10
No
Indeno(1,2,3-cd)pyrene
193-39-5
6.32E-05
10
No
Lead
7439-92-1
3.00E-03
10
No
Manganese
7439-96-5
4.18E-03
10
No
Mercury
7439-97-6
1.10E-04
10
No
Naphthalene
91-20-3
1.92E-04
10
No
Nickel
7440-02-0
5.78E-03
10
No
n-Hexane
110-54-3
2.47E-01
10
No
Phenanthrene
85-01-8
8.95E-06
10
No
Phenol
108-95-2
3.45E-03
10
No
Phosphorus
7723-14-0
0.00E+00
10
No
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Hazardous Air Pollutant
CAS Number
Net Project Emissions (tons per year)
HAP Threshold (tons per year)
HAP Threshold Exceeded? (Yes/No)
Propylene
115-07-1
1.19E-01
10
No
Pyrene
129-00-0
1.52E-06
10
No
Selenium
7782-49-2
1.20E-05
10
No
Silver
7440-22-4
9.87E-04
10
No
Thallium
7440-28-0
0.00E+00
10
No
Toluene
108-88-3
1.04E-01
10
No
Xylene (Total)
1330-20-7
3.81E-02
10
No
Zinc
7440-66-6
1.28E-02
10
No
6.79E+00
25
No
Total HAPs
4.1.2.3
Rule 2-5 – New Source Review of Toxic Air Contaminants In accordance with BAAQMD Regulation 2-5-100, if the project’s emissions of any TAC, which are identified in Table 2-5-1 of Regulation 2, Rule 5, exceed the indicated trigger level, then a detailed risk analysis is required. “Project emissions” include emissions from new sources and increased emissions from modified sources. The rule requires that emissions of all TACs associated with a project be included in the risk analysis if any single TAC exceeds its hourly or annual trigger level. According to BAAQMD Regulation 2-5-216, project emissions must include all approved projects within the 2-year period preceding an application, unless the emissions are demonstrated to be unrelated to those in the application. There are no approved projects within the 2-year period prior to this application that are related to this application. Therefore, no adjustment to project emissions is necessary. Project TAC emissions from the PRP and associated fugitive components are summarized in Tables 4-6. As shown in Table 4-6, hourly TAC emissions are below acute trigger levels. Annual emissions are above the chronic trigger levels for some the toxic pollutant. Due to the exceedance of the chronic trigger level, Phillips 66 prepared a Health Risk Screening Assessment (HRSA) for the boiler, fugitive components, and locomotives. Health risk assessment for mobile sources is not required for the purpose of an air permit application. However, mobile sources must be included in HRSA for CEQA. The HRSA provided in Appendix C, includes risk assessment for diesel particulate matter emitted from locomotives.
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Table 4-6
PRP TAC Emissions Compared to BAAQMD Trigger Levels
Hazardous Air Pollutant
Maximum hourly Emissions (lb/hr)
Acute Trigger Level (lb/hr)
Annual Emissions (lb/year)
Chronic Trigger Level (lb/year)
Trigger Level Exceeded (Yes/No)
1,3-Butadiene
2.35E-04
---
2.06E+00
6.30E-01
Yes
Acenaphthene
3.30E-07
---
2.89E-03
---
No
Acenaphthylene
2.17E-07
---
1.90E-03
---
No
Acetaldehyde
2.14E-03
1.00E+00
1.88E+01
3.80E+01
No
Ammonia
9.42E-01
7.10E+00
8.25E+03
7.70E+03
Yes
Antimony
7.24E-05
---
6.34E-01
---
No
Arsenic
1.19E-04
4.40E-04
1.04E+00
7.20E-03
Yes
Barium
0.00E+00
---
0.00E+00
---
No
Benzene
1.01E-02
2.90E+00
8.85E+01
3.80E+00
Yes
Benzo(a)anthracene
4.49E-06
---
3.94E-02
---
No
Benzo(a)pyrene
1.25E-05
---
1.10E-01
6.90E-03
Yes
Benzo(b)fluoranthene
5.66E-06
---
4.95E-02
---
No
Benzo(g,h,i)perylene
0.00E+00
---
0.00E+00
---
No
Benzo(k)fluoranthene
3.37E-06
---
2.96E-02
---
No
Beryllium
0.00E+00
---
0.00E+00
4.70E-02
No
Cadmium
1.38E-04
---
1.21E+00
2.60E-02
Yes
Carbon disulfide
1.42E-06
1.40E+01
1.24E-02
3.10E+04
No
Chromium (Hex)
0.00E+00
---
0.00E+00
7.70E-04
No
Chromium (Total)
1.50E-04
---
1.31E+00
7.70E-04
Yes
Chrysene
2.28E-07
---
2.00E-03
---
No
Copper
5.89E-04
2.20E-01
5.16E+00
---
No
Dibenz(a,h)anthracene
0.00E+00
---
0.00E+00
---
No
---
2.03E+01
3.40E-01
Yes
Diesel Particulate Matter Ethylbenzene
4.23E-03
---
3.70E+01
4.30E+01
No
Fluoranthene
4.28E-07
---
3.75E-03
---
No
Fluorene
1.51E-06
---
1.32E-02
---
No
Formaldehyde
1.55E-02
1.20E-01
1.36E+02
1.80E+01
Yes
Hydrogen Sulfide
9.11E-04
9.30E-02
7.98E+00
3.90E+02
No
Indeno(1,2,3-cd)pyrene
1.44E-05
---
1.26E-01
---
No
Lead
6.85E-04
---
6.00E+00
3.20E+00
Yes
Manganese
9.53E-04
---
8.35E+00
3.50E+00
Yes
Mercury
2.52E-05
1.30E-03
2.21E-01
2.70E-01
No
Naphthalene
4.38E-05
---
3.84E-01
3.20E+00
No
Nickel
1.32E-03
1.30E-02
1.16E+01
4.30E-01
Yes
n-Hexane
5.63E-02
---
4.93E+02
2.70E+05
No
Phenanthrene
2.04E-06
---
1.79E-02
---
No
Phenol
7.88E-04
1.30E+01
6.90E+00
7.70E+03
No
Phosphorus
0.00E+00
---
0.00E+00
---
No
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Hazardous Air Pollutant
Maximum hourly Emissions (lb/hr)
Acute Trigger Level (lb/hr)
Annual Emissions (lb/year)
Chronic Trigger Level (lb/year)
Trigger Level Exceeded (Yes/No)
Propylene
2.72E-02
---
2.38E+02
1.20E+05
No
Pyrene
3.47E-07
---
3.04E-03
---
No
Selenium
2.74E-06
---
2.40E-02
7.70E+02
No
Silver
2.25E-04
---
1.97E+00
---
No
Thallium
0.00E+00
---
0.00E+00
---
No
Toluene
2.38E-02
8.20E+01
2.09E+02
1.20E+04
No
Xylene (Total)
8.69E-03
4.90E+01
7.61E+01
2.70E+04
No
Zinc
2.91E-03
---
2.55E+01
---
No
---
1.34E-01
6.90E-03
Yes
B(a)P-Equivalent
The HRSA was prepared in accordance with BAAQMD Regulation 2, Rule 5. Preparation followed the Office of Environmental Health Hazard Assessment (OEHHA) guidance document “Air Toxics Hot Spots Program Risk Assessment Guidelines” (2003). Risk assessment calculations were conducted using the Hot Spots Analysis and Reporting Program (HARP) software. Table 4-7 presents a summary of the results of this HRSA.
Table 4-7
Summary of Potential Health Risks from PRP Emissions
Type of Estimated Health Impact
Maximum Exposed Individual Residential (MEIR) – Between San Pablo Ave and Old County Road
Cancer Risk (per million), (Receptor Location)
Chronic Hazard Index, (Receptor Location)
Acute Hazard Index, (Receptor Location)
1.528
0.0809
0.0259
(566104E, 4211597N)
(566104E, 4211597N)
(566104E, 4211597N)
Maximum Exposed Individual Worker (MEIW)
0.283
0.0889
0.0506
(565804E, 4211497N)
(565804E, 4211497N)
(566104E, 4211297N)
Maximum Sensitive Receptor – Day Care Center1
0.305
0.00165
0.0158
(564504E, 4210397N)
(564504E, 4210397N)
(564504E, 4210397N)
1
Conservatively represents child exposure at a day care with a 70-year cancer risk.
In 2009, the California Office of Environmental Health Hazard Assessment (OEHHA) adopted the Technical Support Document for Cancer Potency Factors (OEHHA 2009). This document includes updated methodologies for calculating cancer risks associated with project emissions, including the incorporation of age sensitivity factors (ASFs). It is believed that the ASFs, or weighting factors, which apply to infants, children, and adolescents, account for increased sensitivities to carcinogens. For infants, it is recommended that a factor of 10 be applied for exposures occurring from the third trimester up to 2 years of age. From after 2 to 16 years of age, an ASF of 3 should be applied. For exposures from after age 16 up to age 70, no adjustment factor has been developed or recommended, thus the ASF equals 1 for this period. The application of these factors over an assumed 70-year lifetime results in a factor of 1.7 to be applied to the HARP output for 70-year risk. This was done for the MEIR cancer risk reported in Table 4-7.
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For the day care center cancer risk, the 70-year cancer risk from HARP was reported in Table 4-7. This is a conservative calculation for the children at the day care center considering their reduced exposure period (assumed for regulatory purposes to be 9 years versus 70 years), as it overcompensates for the ASFs to be applied for this exposure duration. For adult workers at the day care center, there would be no ASFs applied, and the 70-year exposure time is conservative compared with a 40-year timeframe typically assumed for occupational exposures. The analysis demonstrates that no off-site receptors will have an increased cancer risk in excess of one in one million, or an acute or chronic Health Hazard Index greater than 1.0. The source that contributes the most to the modeled cancer risk at the MEIR is the refinery fuel gas-fired steam boiler. The contribution to the MEIR risk is 1.20 per million. Since this source contribution to risk is greater than 1 per million, Toxic Best Available Control Technology (TBACT) is required for the new steam boiler, per BAAQMD Regulation 2-5-301. None of the other sources contributing to the total MEIR cancer risk exceeded 1 per million. The emission estimates for the steam boiler were based on reasonably available factors and assuming 100 percent refinery fuel gas. In reality, the boiler would be fired on a combination of refinery fuel gas and natural gas to achieve the lowest possible emissions. 4.1.2.4
Rule 2-6 – Major Facility Review The Phillips 66 Rodeo refinery is a major facility and currently holds a Major Facility Review Permit, also referred to as the Title V operating permit. The PRP will require a Significant Permit Revision of the Title V permit in accordance with Regulation 2-6-226. BAAQMD Major Facility Review permit application forms and proposed Title V revisions are presented in Appendix B, Attachment B-2.
4.1.3
Regulation 3 – Fees BAAQMD Regulation 3 specifies the fee structure for projects subject to BAAQMD permitting review. Estimated fees for the proposed project are presented in Section 5.0, including the filing, initial, Permit to Operate, and the Title V permit revision fees.
4.1.4
Regulation 6 – Particulate Matter and Visible Emissions Regulation 6, which restricts the emissions of particulate matter, applies to all stack emission sources and some specific Refinery processes that emit particulate matter. The specific Regulation 6 rules listed below would apply to the propane recovery unit boiler. •
Regulation 6-301 includes the Ringlemann 1 opacity limit, prohibiting particulate emissions that exceed this limit for more than 3 minutes in any hour.
•
Regulation 6-304 limits visible particulate emissions during tube cleaning of combustion equipment.
•
Regulation 6-305 prohibits nuisance fallout of visible particles.
•
Regulation 6-310 sets an emission rate limit of 0.15 grains per dscf of exhaust gas volume.
•
Regulation 6-311 restricts particulate emissions based on process weight rate.
•
The proposed project will comply with all the rules of this regulation.
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4.1.5
Regulation 7 – Odorous Substances BAAQMD Regulation 7 places general limitations on odorous substances and specific emission limitations on certain odorous compounds. This rule becomes applicable only if the BAAQMD receives odor complaints from 10 or more complainants within a 90-day period.
4.1.6
Regulation 8 – Organic Compounds
4.1.6.1
Rule 8-5 – Storage of Organic Liquids Regulation 8, Rule 5, limits emissions of organic compounds from storage tanks. The proposed new propane storage tanks would be subject to this rule. Consistent with the Regulation 8, Rule 5 requirements, up to ten pressure tanks would be added for the storage of liquefied petroleum gases recovered from the proposed PRP. These tanks will be designed and operated to meet the requirements of Regulation 8, Rule 5. The pressure tanks will comply with Regulation 8-5-307 and will be inspected and monitored as required in Sections 8-5-403, 8-5-404 and 8-5-501.
4.1.6.2
Rule 8-6 – Organic Liquid Bulk Terminals and Bulk Plants Pursuant to Section 8-6-117 - Exemption, Liquefied Organic Gases, the requirements of this rule do not apply to transfer operations involving liquefied organic gases such as liquefied petroleum gas (LPG) and halogenated gases. Therefore, the proposed propane/butane loading and transfer operations are not subject to this rule.
4.1.6.3
Rule 8-10 – Process Vessel Depressurization Regulation 8-10 applies to pressurized vessels containing hydrocarbon materials in many process units within the Refinery, such as fractionation columns. The proposed PRP will include new vessels that will be subject to Regulation 8-10 at times when the vessels are depressurized and/or opened during shutdowns or maintenance.
4.1.6.4
Rule 8-18 – Equipment Leaks BAAQMD Regulation 8, Rule 18, specific to equipment leaks, places limits on POC emissions from equipment components such as valves, flanges, connectors, and pumps. This regulation applies to the PRP. The limits on these fugitive POC emissions are specific to each component type. This regulation applies to equipment leaks at most Refinery equipment except for leaks at devices that are regulated by other rules (tank appurtenances, relief devices vented to control systems) and leaks at devices that handle low vapor pressure (initial boiling point greater than 302°F). The regulation states that equipment shall not be used that leaks total organic compounds in excess of 100 ppm, unless the leak has been discovered by the operator, minimized within 24 hours, and repaired within 7 days. For pumps, compressors, and pressure relief devices, this limit is 500 ppm. The Refinery currently operates a leak detection and repair (LDAR) program to comply with these criteria for inspection, repair and subsequent reporting. New fugitive components installed, as part of the proposed PRP, will be included in this LDAR program, and reported as required by Regulation 8-18 to ensure compliance with this rule.
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4.1.6.5
Rule 8-28 – Episodic Releases from Pressure Relief Valves at Petroleum Refineries and Chemical Plants Regulation 8-28-302 requires that any person installing a new refinery source or modifying an existing refinery source that is equipped with at least one pressure relief device in organic compound service must meet all applicable requirements of Regulation 2, Rule 2, including BACT. The new pressure relief devices installed for this project will meet BACT.
4.1.7
Regulation 9 – Inorganic gaseous Pollutants
4.1.7.1
Rule 9-1 – Sulfur Dioxide This Rule establishes a general emission limit of 300 ppm (dry) for SO2 from any source excluding ships, and limits ground level concentrations of SO2 to 0.5 ppm continuously for 3 consecutive minutes or 0.25 ppm averaged over 60 consecutive minutes, or 0.05 ppm averaged over 24 hours, from any source, other than a ship. The refinery demonstrates compliance with these requirements via its ground level monitoring program. Regulation 9-1-313: Sulfur Removal Operations at Petroleum Refineries prohibits operation of a refinery that processes more than 20,000 barrels per day of crude oil unless the refinery removes and recovers 95% of the H2S from the RFG. This requirement applies to the fuel gas treatment and recovery processes. The efficiency of the existing Sulfur Recovery Units at the Phillips 66 Refinery fulfills this requirement and the hydrotreatment unit, proposed as a part of PRP, will further remove H2S from RFG.
4.1.7.2
Rule 9-2 – Hydrogen Sulfide Regulation 9-2-301: Limitations on hydrogen sulfide restricts H2S emissions to levels that will result in ground level concentrations less than or equal to 0.06 ppm, averaged over 3 consecutive minutes or 0.03 ppm, averaged over 60 consecutive minutes, in any 24-hour period. This will apply to fugitive components of the PRP. As the hydrotreatment unit will remove additional H2S from RFG, prior to propane and butane recovery, H2S emissions due to PRP operations at the Refinery are not expected to significantly change the H2S concentration from current levels. Thus, compliance with these limits would not be affected by the proposed PRP.
4.1.7.3
Rule 9-10 – NOx and CO from Boilers, Steam Generators and Process Heaters in Petroleum Refineries This rule limits the emissions of NOx and CO from boilers, steam generators, and process heaters, including CO boilers, in petroleum refineries. The PRP will include a new 140 MMBtu/hr boiler fired with natural gas and equipped with low-NOx burners and an SCR system to minimize emissions. Therefore, pursuant to Section 9-10-110.6, it will not be subject to Regulation 9-10.
4.1.8
Regulation 10 – Standards of Performance for New Stationary Sources Regulation 10 adopts the provisions of 40 CFR 60 by reference. The applicable subparts of 40 CFR 60 are identified in Section 4.3 of this application.
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4.1.9
Rule 11-12 – National Emission Standard for Benzene Emissions Rule 11-12 adopts the provisions of 40 CFR 61 Subpart BB and Subpart FF by reference. The applicability of and compliance with 40 CFR 61 is reviewed in Section 4.3 of this application.
4.2
California Environmental Quality Act CEQA requires a review of potential significant environmental impacts from proposed projects. This project has been determined to be subject to CEQA by Contra Costa County, and will require a Land Use Permit under the Contra Costa County Department of Conservation and Development. Approval of the land use permit will require compliance with CEQA, including the preparation of an EIR. An application for a Land Use Permit was submitted to Contra Costa County on June 21, 2012.
4.3
Federal Rules and Regulations
4.3.1
40 CFR 52.21 – Prevention of Significant Deterioration of Air Quality As previously discussed in Section 4.1.2.2, the PRP is not subject to PSD review, because project emissions increases are not considered to be a “modification” that would exceed “major modification” applicability thresholds for any regulated pollutant listed in Regulation 2-2-304 through 2-2-306 and because emissions from cargo carriers are not subject to PSD applicability review (Regulation 2-2-215.2). Total GHG emissions from the project-related, stationary sources will be 74,110 tons per year CO2e. The project does not require PSD permit under the federal PSD and Title V Operating Permit GHG Tailoring Rule Step 3 and GHG Plantwide Applicability Limits, because the total GHG emissions will be below the GHG significance threshold of 75,000 ton per year CO2e.
4.3.2
40 CFR 60 Subpart A – General Provisions Any source subject to an applicable standard under 40 CFR 60 is also subject to the general provisions of Subpart A. Because the propane recovery unit boiler is subject to 40 CFR 60 Subpart Db, the requirements of Subpart A apply. Subpart A contains requirements for notification of construction or modification and startup, monitoring, recordkeeping and reporting, and performance testing. Phillips 66 will provide notification to the USEPA administrator at least 60 days prior to construction of equipment subject to Subpart Db and notification of startup, as required. Phillips 66 currently complies with the monitoring, recordkeeping, and reporting requirements of Subpart A and will continue to do so following implementation of the proposed project.
4.3.3
40 CFR 60 Subpart Db—Standards of Performance for IndustrialCommercial-Institutional Steam Generating Units This subpart applies to each steam generating unit that commences construction, modification, or reconstruction after June 19, 1984, and that has a heat input capacity from fuels combusted in the steam generating unit of greater than 29 megawatts (MW) (100 MMBtu/hr). Subpart Db specifies emission standards for SO2, PM, and NOx. Subpart Db also specifies performance testing, monitoring, record-keeping, and reporting requirements for the affected unit. The proposed propane recovery unit boiler with a heat input rate of 140 MMbtu/hr will be subject to the requirements of this subpart. ERM
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4.3.4
40 CFR 60 Subpart Ja—Standards of Performance for Petroleum Refineries for Which Construction, Reconstruction, or Modification Commenced After May 14, 2007 The provisions of this subpart apply to fuel gas combustion devices (including process heaters) in petroleum refineries. Pursuant to Section 60.102a (g) (1) of Subpart Ja, all fuel gas combustion devices, except those exempted, must meet the SO2 emissions limitations or H2S content limitations in fuel gas. Section 60.102a (g) (2) specifies NOx emission limits for process heaters with a rated capacity of greater than 40 MMBtu/hr on a higher heating value basis. Pursuant to Section 60.102a (i), for a process heater that meets any of the criteria of paragraphs (i)(1)(i) through (iv) of this subpart, an owner or operator may request approval from the Administrator for a NOx emissions limit which shall apply specifically to that affected facility. Subpart Ja also specifies design, equipment, work practice, or operational standards, performance testing, monitoring, record-keeping, and reporting requirements for the affected unit. The proposed propane recovery unit boiler with a heat input rate of 140 MMBtu/hr will be subject to the requirements of this subpart.
4.3.5
40 CFR 60 Subpart GGGa – Equipment Leaks of VOC in Petroleum Refineries for Which Construction, Reconstruction, or Modification Commenced After November 7, 2006 The PRP involves the addition of new fugitive components (valves, pressure relief valves, flanges or other connectors, and pumps). The new fugitive components would be subject to 40 CFR 60 Subpart GGGa. Fugitive components subject to 40 CFR 60 Subpart GGGa must comply with 40 CFR 60 Subpart VVa (New Source Performance Standards for Equipment Leaks of VOC in the Synthetic Organic Chemicals Manufacturing Industry for Which Construction, Reconstruction, or Modification Commenced After November 7, 2006). Subpart GGGa/VVa includes leak criteria, repair requirements and component monitoring requirements. The Refinery currently operates an LDAR program to comply with both Subpart GGGa/VVa and BAAQMD Regulation 8-18. New fugitive components will be included in this LDAR program, and reported as required by both Regulation 8-18 and in Subpart GGGa/VVa semiannual reports.
4.3.6
40 CFR 61 Subpart A – General Provisions Any source subject to an applicable standard under 40 CFR 61 is also subject to the general provisions of Subpart A. Because the proposed project will be subject to Subpart FF, the requirements of Subpart A apply. The Rodeo refinery currently complies with the monitoring, recordkeeping, and reporting requirements of Subpart A and will continue to do so following implementation of the proposed project.
4.3.7
40 CFR 61 Subpart FF – Benzene Waste Operations NESHAP Commonly referred to as BWON, or the Benzene Waste Operations national emission standards for hazardous air pollutants (NESHAP), 40 CFR 61 Subpart FF applies to chemical manufacturing plants, coke by-product recovery plants, and petroleum refineries. The proposed project will not generate benzene-containing wastes. The only sources of benzene from the proposed project will be fugitive components leaks. Moreover, pursuant to Section 61.340 (c)(1) of this subpart, waste in the form of gases or vapors that is emitted from process fluids is exempt from the requirements of this
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subpart. However, Phillips 66 has in place a BWON program that will ensure continued compliance with this rule.
4.3.8
40 CFR 63 Subpart A – General Provisions Any source subject to an applicable standard under 40 CFR 63 is also subject to the general provisions of Subpart A. Because the proposed project will be subject to Subpart DDDDD, the requirements of Subpart A apply. The Rodeo refinery currently complies with the monitoring, recordkeeping, and reporting requirements of Subpart A and will continue to do so following implementation of the proposed project.
4.3.9
40 CFR 63 Subpart CC – National Emission Standards for Petroleum Refineries Commonly referred to as “Refinery MACT,” Subpart CC applies to petroleum refining process units and related emission sources that emit or have equipment containing or contacting one or more HAPs listed in Subpart CC, and are located in a petroleum refinery that is a major source of HAPs. Subpart CC establishes standards for miscellaneous process vents, storage vessels, wastewater streams and treatment operations, equipment leaks, gasoline loading racks, and marine vessel loading operations. PRP process vessels, storage tanks and fugitive component equipment leaks will be subject to this rule. Equipment leaks subject to Subpart CC and to 40 CFR 60 Subpart GGGa are subject to the overlap for equipment leaks in Subpart CC at 63.640(p)(2). The overlap specifies that equipment leaks subject to Subpart CC that are also subject to 40 CFR 60 Subpart GGGa must comply with Subpart GGGa. Therefore, the new PRP fugitive components will be subject to 40 CFR 60 Subpart GGGa/VVa as discussed in paragraph 4.3.4, and not to 40 CFR 63 Subpart CC.
4.3.10
40 CFR 63 Subpart DDDDD—NESHAPS for Industrial, Commercial, and Institutional Boilers and Process Heaters This subpart establishes national emission limits and work practice standards for HAPs emitted from industrial, commercial, and institutional boilers and process heaters. This subpart also establishes requirements to demonstrate initial and continuous compliance with the emission limits and work practice standards. This subpart will apply to the proposed 140 MMBtu/hr boiler. As the proposed boiler will fire a combination of natural gas and refinery fuel gas, the boiler is a Gas 1 unit, not subject to any emission limit requirements. The boiler is subject to only work practice standards requiring an annual tune-up in-lieu of emission limits. The proposed boiler will comply with the requirements of this subpart.
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5.0
ESTIMATED PERMIT FEES The estimated fees for the ATC application are $43,975. The fees include the filing, initial, permit to operate, and Title V permit revision fee, as shown in Table 5-1.
Table 5-1
Estimated PRP BAAQMD Permit Fees
Units
Filing Fee
Initial Fee
Toxic Risk Screening Fee
PTO Fee
Title V Significant Revision Fee
Toxic Surcharge
Total
Basis
S-New, Boiler 140 MMBtu/hr
1
$416
$7,293
$7,709
$3,645
$1,836
$365
$21,264
Schedule B
A-New, SCR for Boiler
1
$416
$3,647
$3,855
$1,836
$9,754
BAAQMD 3-302.3
Hydrotreating Unit
1
$416
$2,588
$1,292
$1,836
$6,132
Schedule F (G-1)
Propane Recovery Unit
1
$416
$2,588
$1,292
$1,836
$6,132
Schedule F (G-1)
$693
Schedule P
Source
MFR Filing Fee Total
$43,975
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6.0
REFERENCES American Petroleum Institute (API). 2009. Compendium of Greenhouse Gas Emissions Methodologies for the Oil and Natural Gas Industry, Tables 4-3 and 4-6. Bay Area Air Quality Management District (BAAQMD). 2005. Policy: Emission Factors for Toxic Air Contaminants from Miscellaneous Natural Gas Combustion Sources, Effective date September 7, 2005. http://www.baaqmd.gov/~/media/Files/Engineering/policy_and_procedures /TACEmFacfromNatGasCombustion.ashx California Air Pollution Control Officers Association (CAPCOA)/California Air Resources Board (CARB). 1999. California Implementation Guidelines for Estimating Mass Emissions from Fugitive Hydrocarbon Leaks at Petroleum Facilities. http://www.arb.ca.gov/fugitive/fugitive.htm. California Environmental Protection Agency, Office of Environmental Health Hazard Assessment (OEHHA). 2003. Air Toxics Hot Spots Program Risk Assessment Guidelines; The Air Quality Air Toxics Hot Spots Program Guidance Manual for Preparation of Health Risk Assessments. August. California OEHHA. 2009. Technical Support Document for Cancer Potency Factors. May 2009. http://www.oehha.ca.gov/air/hot_spots/2009/TSDCancerPotency.pdf . Accessed February 2013. Energy and Environmental Research Corporation (EERC). 1998. Air Toxic Emission Factors for Combustion Sources Using Petroleum Based Fuels, Final Report, Volume II. August 14. USEPA, 1998. AP-42, Chapter 1.4, Natural Gas Combustion. July. USEPA 2009. Emission Factors for Locomotives, Technical Highlights, EPA-420-F-09-025, April. USEPA 2011. AP-42, Chapter 13.2.1, Paved Roads. January.
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Figures •
Figure 2-1 – Site Location Map
•
Figure 2-2 – Aerial Map of the Facility
•
Figure 2-3 – Site Plan on USGS Topographic Quadrangle Map
•
Figure 2-4 – Location of Proposed Project Units
•
Figure 2-5 – Flow Diagram of Existing Processes
STUDY AREA
1" = 3000'
0
1500'
3000'
6000'
9000'
Figure 1
LEGEND ®
PROPERTY BOUNDARY ERM
.
N SA
BLO PA
AVE
80
Figure 2 LEGEND PROPERTY BOUNDARY © ERM
LEGEND PROPERTY BOUNDARY References: U.S.G.S. 7.5 Minute Series (Topographic) Quadrangle, Mare Island Version: 1981; Current: 1980 Benicia Version: 1980; Current: 1980
.
N SA
BLO PA
AVE
80
Figure 3
ERM
500 feet
Figure 4 Locations of Site Modifications Phillips 66 Rodeo, California
PG&E Natural Gas
RFG to Refinery Fuel Gas System
Lean Amine
LS - RFG-B to H2 Plt Fuel
Flare Recovery / OA Compressors
U-233 Fuel Gas Treating U-200 / U215 S-RFG
Spent Amine
RFG to SPP Gas Turbines
Amine Treating
MP-30 S-RFG
LS – RFG System
Lean Amine
U-200 / U-215 Fuel Gas Hydrotreating
RFG Propane Recovery Unit + Amine Treating
U-215 Butane U-246 / 250 Naphtha
Spent Amine
Propane Storage / Loading Butane Storage / Loading Naphtha to Blending
U-240 / 244 / 248 S-RFG U-246 S-RFG MP-30 S-RFG U-240 D-301 S-RFG Lean Amine
U-240 Fuel Gas Treating Amine Treating
Spent Amine
RFG-A to H2 Plt Feed
Figure 7 Proposed Refinery Fuel Gas System Block Flow Diagram Phillips 66 Rodeo, California
Appendix A Operational Emissions Calculations •
Attachment A-1 – Boiler Criteria Pollutant and GHG Emissions
•
Attachment A-2 – Boiler TAC Emissions
•
Attachment A-3 – Fugitive Component POC Emissions
•
Attachment A-4 – Fugitive Component TAC Emissions
•
Attachment A-5 – Locomotive Emissions
•
Attachment A-6 – On-road Vehicle Emissions
•
Attachment A-7 – Daily U233 Fuel Gas Data
Attachment A-1 Boiler Criteria Pollutant and GHG Emissions
Boiler Criteria Pollutant and GHG Emissions from Natural Gas Firing Fuel High Heating Value of NG (btu/scf)1 Heat Input Rating (Mmbtu/hr) Operating Time (hours/year) Operating Time (hours/day) Load Factor 1. AP-42 Chapter 1.4, Natural Gas Combustion
Pollutant
Natural Gas (NG) 1020 140 8760 24 1
BACT
Technology
Reference
NOx
5 ppmv @ 3% O2 (3-hr average)
Low-NOx burner and SCR
BAAQMD BACT Determination for S-45 heater for CFEP Project U246 (Application 13424)
CO
10 ppmv @ 3% O2 (3-hr average)
Good combustion practice in conjunction with SCR system or ultra low Nox burners and FGR
BAAQMD BACT Determination for S-45 heater for CFEP Project U246 (Application 13424)
PM10
7.6 lb/MMscf
Use of natural gas and/or RFG
AP-42, Chapter 1.4, Natural Gas Combustion
POC
5.5 lb/MMscf
Good combustion practice
AP-42, Chapter 1.4, Natural Gas Combustion
NH3
15 ppmv @ 3% O2 (8-hr average)
SO2
BAAQMD BACT Determination for S-45 heater for CFEP Project U246 (Application 13424)
Not Required. Use of pipeline quality natural gas is BACT(2) for SO2 per BAAQMD BACT Guideline 17.3.1, BACT(2) for boilers with ≥ 50 MMBtu/hr heat input
Boiler Criteria Pollutant and GHG Emissions from Natural Gas Firing Emission Factor Pollutants
lb/MMscf
Emissions lb/MMbtu
Hourly (lb/hr)
Daily (lb/day)
--0.0061 0.85 20.4 NOx1 1 --0.0074 1.03 25 CO 7.6 0.0075 1.04 25.0 PM (total)2 5.7 0.0056 0.78 18.8 PM (condensable)2 1.9 0.0019 0.26 6.26 PM (filterable)2 2 0.6 0.0006 0.08 1.98 SO2 11 0.0108 1.51 36.2 TOC2 2 5.5 0.0054 0.75 18.1 POC 120,000 118 16,471 395,294 CO22 2.3 0.0023 0.32 7.58 CH42 2 2.2 0.0022 0.30 7.25 N2O 16,571 397,700 CO2e3 Note: 1. Controlled NOx emissions per BACT of 5 ppmv NOx @ 3% O2 (3-hr average). Based on BACT determination for S-45 Heater from Clean Fuels Expansion Project. Controlled CO emissions per BACT of 10 ppmv CO @ 3% O2 (3-hr average). Based on BACT determination for S-45 Heater from Clean Fuels Expansion Project. 2. Emission factors obtained from AP-42, Chapter 1.4, Table 1.4-2 3. CO2e Emissions = CO2 Emissions + CH4 Emission x GWP (21) + N2O Emissions x GWP (310)
Annual (tons/yr) 3.72 4.53 4.57 3.43 1.14 0.36 6.61 3.31 72,141 1.38 1.32 72,580
Boiler Criteria Pollutant and GHG Emissions from Natural Gas Firing Tool to convert from ppm to lb/MMBtu Equation:
lb / MMbtu =
ppm 20 .9 Fd × × MW × 10 E 6 20 .9 − O2% Vm
Based on EPA Method 19 Where
Pollutant = NOx
Pollutant = CO
ppm = stack gas concentration at O2% O2% = percent oxygen Fd = F factor = 8710 dscf/MMBtu for natural gas MW = molecular weight of pollutant (46 lb/mole for NO2 and 28 lb/mole for CO) Vm = molar volume = 385.3 dscf/mole @ 68 °F and 1 atm
ppm O2% MW (lb/mole) Fd (dscf/MMBtu) Vm (dscf/mole) lb/MMBtu
Value 5 input 3 input 46 constant 8710 constant 385.3 constant @ 68 °F and 1 atm. 0.0061 results
ppm O2% MW (lb/mole) Fd (dscf/MMBtu) Vm (dscf/mole) lb/MMBtu
Value 10 input 3 input 28 constant 8710 constant 385.3 constant 0.0074 results
Boiler Criteria Pollutant and GHG Emissions from RFG Firing Fuel Refinery Fuel Gas 1340 High Heating Value of RFG (btu/scf)1 Heat Input Rating (Mmbtu/hr) 140 Operating Time (hours/year) 8760 Operating Time (hours/day) 24 Load Factor 1 1. Phillips 66 3-year average used for CFEP project
Pollutant
BACT
Technology
Reference
NOx
5 ppmv @ 3% O2 (3-hr average)
Low-NOx burner and SCR
BAAQMD BACT Determination for S-45 heater for CFEP Project U246 (Application 13424)
CO
10 ppmv @ 3% O2 (3-hr average)
Good combustion practice in conjunction with SCR system or ultra low Nox burners and FGR
BAAQMD BACT Determination for S-45 heater for CFEP Project U246 (Application 13424)
PM10
7.6 lb/MMscf
Use of natural gas and/or RFG
AP-42, Chapter 1.4, Natural Gas Combustion
POC
5.5 lb/MMscf
Good combustion practice
AP-42, Chapter 1.4, Natural Gas Combustion
NH3
15 ppmv @ 3% O2 (8-hr average)
SO2
100 ppmv total sulfur in RFG
BAAQMD BACT Determination for S-45 heater for CFEP Project U246 (Application 13424) Use of RFG
BAAQMD BACT Determination for S-45 heater for CFEP Project U246 (Application 13424)
Emission Factor Pollutants
Emissions
lb/MMscf
lb/MMbtu
Hourly (lb/hr)
Daily (lb/day)
Annual (tons/yr)
NOx1 CO1 PM (total)2 PM (condensable)2 PM (filterable)2 SO21
----7.6 5.7 1.9 --11 5.5 ---
0.0061 0.0074 0.0057 0.0043 0.0014 0.0124 0.0082 0.0041 120.59
0.85 1.03 0.79 0.60 0.20 1.74 1.15 0.57 16,883
20.4 25 19.1 14.3 4.76 41.65 27.6 13.8 405,192
3.72 4.53 3.48 2.61 0.87 7.60 5.03 2.52 73,947
CH43
---
0.0021
0.29
7.04
1.28
N2O
---
0.0002
TOC2 POC2 CO23 3
CO2e4
0.03
0.70
0.13
16,898
405,557
74,014
Boiler Criteria Pollutant and GHG Emissions from RFG Firing Note: 1. NOx emissions per BACT of 5 ppmv NOx @ 3% O2 (3-hr average). Based on BACT determination for S-45 Heater from Clean Fuels Expansion Project. CO emissions per BACT of 10 ppmv CO @ 3% O2 (3-hr average). Based on BACT determination for S-45 Heater from Clean Fuels Expansion Project. SO2 emission factor based on total sulfur content of 100 ppmv 2. Emission factors obtained from AP-42, Chapter 1.4, Table 1.4-2 3. CO2, CH4 and N2O emission factors from API Compendium of Greenhouse Gas Emissions Methodologies for the Oil and Natural Gas Industry, Tables 4-3 and 4-6, August 2009 4. CO2e Emissions = CO2 Emissions + CH4 Emission x GWP (21) + N2O Emissions x GWP (310)
Tool to convert from ppm to lb/MMBtu Equation:
lb / MMbtu =
ppm 20 .9 Fd × × MW × 10 E 6 20 .9 − O 2% Vm
Based on EPA Method 19 Where
ppm = stack gas concentration at O2% O2% = percent oxygen Fd = F factor = 8710 dscf/MMBtu for natural gas MW = molecular weight of pollutant (46 lb/mole for NO2 and 28 lb/mole for CO) Vm = molar volume = 385.3 dscf/mole @ 68 °F and 1 atm
ppm O2% MW (lb/mole) Fd (dscf/MMBtu) Vm (dscf/mole) lb/MMBtu
Value 5 input 3 input 46 constant 8710 constant 385.3 constant @ 68 °F and 1 atm. 0.0061 results
ppm O2% MW (lb/mole) Fd (dscf/MMBtu) Vm (dscf/mole) lb/MMBtu
Value 10 input 3 input 28 constant 8710 constant 385.3 constant 0.0074 results
Pollutant = NOx
Pollutant = CO
Pollutant = SOx ppm MW (lb/mole) Vm (dscf/mole) lb/MMBtu
Value 100 input 64 constant 385.3 constant @ 68 °F and 1 atm. 0.0124 results
Attachment A-2 Boiler TAC Emissions
Boiler TAC Emissions From Natural Gas Fuel High Heating Value of NG (btu/scf) Heat Input Rating (Mmbtu/hr) Operating Time (hours/year) Operating Time (hours/day) Load Factor CAS Number
Natural Gas (NG) 1020 140 8760 24 1 Pollutant
7664-41-7 Ammonia1 71-43-2 Benzene2 50-00-0 Formaldehyde2 108-88-3 Toluene2 1. Ammonia from SCR ammonia slip at 15 ppmvd @ 3% O2
Emission Factor lb/MMscf 6.87E+00 2.10E-03 7.50E-02 3.40E-03
lb/MMBtu 6.73E-03 2.06E-06 7.35E-05 3.33E-06
Emissions Hourly (lb/hr) Annual (lb/year) 9.42E-01 8.25E+03 2.88E-04 2.52E+00 1.03E-02 9.02E+01 4.67E-04 4.09E+00
2. BAAQMD Policy: Emission Factors for Toxic Air Contaminants from Miscellaneous Natural Gas Combustion Sources, Effective date September 7, 2005, http://www.baaqmd.gov/~/media/Files/Engineering/policy_and_procedures/TACEmFacfromNatGasCombustion.ashx Emission Factor Calculation for Ammonia Equation:
lb / MMbtu =
ppm 20 .9 Fd × × MW × Vm 10 E 6 20 .9 − O2%
Based on EPA Method 19 Where
Pollutant = NH3 ppm O2% MW (lb/mole) Fd (dscf/MMBtu) Vm (dscf/mole) lb/MMBtu
ppm = stack gas concentration at O2% O2% = percent oxygen Fd = F factor = 8710 dscf/MMBtu for natural gas MW = molecular weight of pollutant (46 lb/mole for NO2 and 28 lb/mole for CO) Vm = molar volume = 385.3 dscf/mole @ 68 °F and 1 atm Value 15 input 3 input 17 constant 8710 constant 385.3 constant @ 68 °F and 1 atm. 0.0067 results
Boiler TAC Emissions From Refinery Fuel Fuel High Heating Value of NG (btu/scf) Heat Input Rating (Mmbtu/hr) Operating Time (hours/year) Operating Time (hours/day) Load Factor
Refinery Fuel Gas 1340 140 8760 24 1
Emissions Emission Factor(1) lb/MMBtu Hourly (lb/hr) Annual (lb/year) (2) 7664-41-7 6.73E-03 9.42E-01 8.25E+03 Ammonia 2.36E-09 83-32-9 Acenaphthene 3.30E-07 2.89E-03 1.55E-09 208-96-8 Acenaphthylene 2.17E-07 1.90E-03 1.53E-05 75-07-0 Acetaldehyde 2.14E-03 1.88E+01 5.17E-07 7440-36-0 Antimony 7.24E-05 6.34E-01 8.50E-07 7440-38-2 Arsenic 1.19E-04 1.04E+00 (0) ND 0.00E+00 0.00E+00 7440-39-3 Barium(3) 6.47E-05 71-43-2 Benzene 9.06E-03 7.93E+01 3.21E-08 56-55-3 Benzo(a)anthracene 4.49E-06 3.94E-02 8.96E-08 50-32-8 Benzo(a)pyrene 1.25E-05 1.10E-01 4.04E-08 205-99-2 Benzo(b)fluoranthene 5.66E-06 4.95E-02 (3) (0) ND 0.00E+00 0.00E+00 191-24-2 Benzo(g,h,i)perylene 2.41E-08 207-08-9 Benzo(k)fluoranthene 3.37E-06 2.96E-02 (3) (0) ND 0.00E+00 0.00E+00 7440-41-7 Beryllium 9.88E-07 7440-43-9 Cadmium 1.38E-04 1.21E+00 (3) (0) ND 0.00E+00 0.00E+00 18540-29-9 Chromium (Hex) 1.07E-06 7440-47-3 Chromium (Total) 1.50E-04 1.31E+00 1.63E-09 218-01-9 Chrysene 2.28E-07 2.00E-03 4.21E-06 7440-50-8 Copper 5.89E-04 5.16E+00 (3) (0) ND 0.00E+00 0.00E+00 53-70-3 Dibenz(a,h)anthracene 3.02E-05 100-41-4 Ethylbenzene 4.23E-03 3.70E+01 3.06E-09 206-44-0 Fluoranthene 4.28E-07 3.75E-03 1.08E-08 86-73-7 Fluorene 1.51E-06 1.32E-02 1.11E-04 50-00-0 Formaldehyde 1.55E-02 1.36E+02 (0) ND 0.00E+00 0.00E+00 7783-06-4 Hydrogen Sulfide(3) 1.03E-07 193-39-5 Indeno(1,2,3-cd)pyrene 1.44E-05 1.26E-01 4.89E-06 7439-92-1 Lead 6.85E-04 6.00E+00 6.81E-06 7439-96-5 Manganese 9.53E-04 8.35E+00 1.80E-07 7439-97-6 Mercury 2.52E-05 2.21E-01 3.13E-07 91-20-3 Naphthalene 4.38E-05 3.84E-01 9.42E-06 7440-02-0 Nickel 1.32E-03 1.16E+01 1.46E-08 85-01-8 Phenanthrene 2.04E-06 1.79E-02 5.63E-06 108-95-2 Phenol 7.88E-04 6.90E+00 (0) ND 0.00E+00 0.00E+00 7723-14-0 Phosphorus(3) 2.17E-06 115-07-1 Propylene 3.04E-04 2.66E+00 2.48E-09 129-00-0 Pyrene 3.47E-07 3.04E-03 1.96E-08 7782-49-2 Selenium 2.74E-06 2.40E-02 1.61E-06 7440-22-4 Silver 2.25E-04 1.97E+00 (3) (0) ND 0.00E+00 0.00E+00 7440-28-0 Thallium 1.07E-04 108-88-3 Toluene 1.50E-02 1.31E+02 3.73E-05 1330-20-7 Xylene (Total) 5.22E-03 4.57E+01 2.08E-05 7440-66-6 Zinc 2.91E-03 2.55E+01 (1) Emission factors for TAC other than ammonia were obtained from Appendix B of EERC August 14, 1998 document "Air Toxic Emission Factors for Combustion Sources Using Petroleum Based Fuels, Final Report, Vol. II" (2) Ammonia from SCR ammonia slip at 15 ppmvd @ 3% O2. Emission Factor calculated as explained be CAS Number
Pollutant
(3) Emission factors presented in the EERC document for these compounds were all based entirely on non-detect analytical values, therefore an emission factor of zero has been substituted based on CAPCOA health risk assessment guidelines. Emission Factor Calculation for Ammonia Equation:
lb / MMbtu =
ppm 20 .9 Fd × × MW × 10 E 6 20 .9 − O2% Vm
Based on EPA Method 19 Where
Pollutant = NH3 ppm O2% MW (lb/mole) Fd (dscf/MMBtu) Vm (dscf/mole) lb/MMBtu
ppm = stack gas concentration at O2% O2% = percent oxygen Fd = F factor = 8710 dscf/MMBtu for natural gas MW = molecular weight of pollutant (46 lb/mole for NO2 and 28 lb/mole for CO) Vm = molar volume = 385.3 dscf/mole @ 68 °F and 1 atm Value 15 input 3 input 17 constant 8710 constant 385.3 constant @ 68 °F and 1 atm. 0.0067 results
Attachment A-3 Fugitive Component POC Emissions
Fugitive Component POC Emissions BACT Limit
Technology
Reference
Valves
100 ppm expressed as methane measured using EPA Reference Method 21
Bellows Valves; Diaphragm Valves; Quarter Turn Valves; Live Loaded Valves; or Other Low-Emission Valves; Each with BAAQMD Approved Inspection and Maintenance
BACT(2) Guideline 136.1, Condition 23725 Title V Permit
Connectors
100 ppm expressed as methane measured using EPA Reference Method 21
Graphitic Gaskets and BAAQMD Approved Inspection and Maintenance
BACT(2) Guideline 78.1, Condition 23725 Title V Permit
100 ppm expressed as methane measured using EPA Reference Method 21
Double Mechanical Seals w/ Barrier Fluid; Magnetically Coupled Pumps; Canned Pumps; Magnetic Fluid Sealing Technology; or Gas Seal System Vented to Thermal Oxidizer or Other BAAQMD Approved Control Device; all w/BAAQMD Approved Quarterly Inspection and Maintenance Program
BACT(1) Guideline 137.1, Condition 23725 Title V Permit
100 ppm expressed as methane measured using EPA Reference Method 21
Double Mechanical Seals w/ Barrier Fluid; or Gas Seal System Vented to a Thermal Oxidizer or Other BAAQMD Approved Control Device; all w/ BAAQMD Approved Quarterly Inspection and Maintenance Program
BACT(1) Guideline 48B.1, Condition 23725 Title V Permit
Vent to fuel gas recovery system, furnace, or flare with a recovery/destruction efficiency>98%
BACT(2) Guideline 135.1, Condition 23725 Title V Permit
Component Type/Service
Pumps
Compressors
Pressure Relief Devices
Fugitive POC Emissions
Component Type/Service Valves/All Connectors/All Pump Seals/All
Correlation Equation 2.27E-6*(SV)^0.747 1.53E-6*(SV)^0.736 5.07E-5*(SV)^0.622 8.69E-6(SV)^0.642 ---
1
Screening Value, SV (ppmv)
Resulting Emission Factor (kg/hr/source)
Component Count
Hourly POC (lb/hr)
Daily POC (lb/day)4
Annual POC 5 (tons/yr)
100 100 100 100 ---
7.1E-05 4.5E-05 8.9E-04 1.7E-04 ---
2,810 5,620 16 44 8,490
0.44 0.56 0.03 0.02 1.05
10.5 13.5 0.75 0.39 25.1
1.92 2.46 0.14 0.07 4.58
2
Other(3)/All Total - All Components Note: 1. California Implementation Guidelines for Estimating Mass Emissions of Fugitive Hydrocarbon Leaks at Petroleum Facilities, February 1999. 2. Screening Values assumed to be proposed BACT emission limits
3. The “other” component type includes instruments, loading arms, pressure relief valves, vents, compressors, dump lever arms, diaphragms, drains, hatches, meters, and polished rods stuffing boxes. This “others” component type should be applied for any component type other than connectors, flanges, open-ended lines, pumps, or valves. 4. Daily emissions based on 24-hours-per-day operation 5. Annual emissions based on 8,760-hours-per-year operation (24 hr per day x 365 days per year)
Attachment A-4 Fugitive Component TAC Emissions
Refinery Fuel Gas Speciation Profile Form Approved 03/28/2011 OMB Control No. 2060-0657 Approval Expires 03/31/2014
Fuel Gas Data General source Assign a description, e.g., mix unique ID for Enter start date drum for X,Y,Z units; mix each test drum for fuel gas system report 1; etc.
Instruction:
Process Throughput or Production Rate
Field:
Molecular Wt Mass Fraction
Enter the fuel gas flow rate or usage rates from measurement data, company records, or engineering analyses. Use 1 atm and 60°F as standard conditions.
Facility ID Number
Fuel gas mix drum ID
CA5A0280
Unit 233
CA5A0280
Unit 233
CA5A0280
Unit 233
Molecular Weight of RFG
General Description
mix drum for fuel gas system mix drum for fuel gas system mix drum for fuel gas system 21.75
Standard Dry Standard Actual Fuel Gas Flow Fuel Gas Flow Fuel Gas Flow Rate Rate Rate (acfm) (scfm) (dscfm)
Test Report ID
Test Date (mm/dd/yyyy)
Run Number
11045.2
08/15/2011
Run 1
3,826.83
20,011.19
19,811.08
11045.2
08/17/2011
Run 2
3,747.39
20,394.04
20,210.49
11045.2
08/17/2011
Run 3
4,036.96
21,014.92
20,783.76
(per Brent's email)
Production comment
Refinery Fuel Gas Speciation Profil Form Approved 03/28/2011 OMB Control No. 2060-0657 Approval Expires 03/31/2014
Fuel Gas Data
Enter the fuel gas higher heating value (HHV) content and general composition data
Instruction:
CAS No. >>
Field:
Molecular Wt Mass Fraction
1333-74-0
630-08-0
124-38-9
7727-37-9
7782-44-7
Facility ID Number
HHV (Btu/scf)
Moisture Content (vol%)
Hydrogen (vol%, dry basis)
Carbon monoxide (vol%, dry basis)
Carbon dioxide (vol%, dry basis)
Nitrogen (vol%, dry basis)
Oxygen (vol%, dry basis)
CA5A0280
1323.33
1.00
29.44
0.43
0.11
2.03
0.43
CA5A0280
1335.42
0.90
29.49
0.44
0.11
2.39
0.44
CA5A0280
1320.85
1.10
29.44
0.43
0.11
2.03
0.43
18.0153
2.014
28.01
44.01
28.0134
32
0.008282897
0.027274137
0.005531228
0.002225793
0.027678106
0.006319147
Molecular W
Refinery Fuel Gas Speciation Profil Form Approved 03/28/2011 OMB Control No. 2060-0657 Approval Expires 03/31/2014
Assume all TRS is H2S
Fuel Gas Data
Enter the sulfur compound composition data
Instruction:
CAS No. >>
7783-06-4
463-58-1
75-15-0
74-82-8
74-84-0
74-85-1
74-86-2
74-98-6
115-07-1
463-49-0
106-97-8
75-28-5
Facility ID Number
TRS (ppmvd)
Hydrogen sulfide (ppmvd)
Carbonyl sulfide (ppmvd)
Carbon disulfide (ppmvd)
Methane (ppmvd)
Ethane (ppmvd)
Ethylene (ppmvd)
Acetylene (ppmvd)
Propane (ppmvd)
Propylene (ppmvd)
Propadiene (ppmvd)
n-Butane (ppmvd)
Isobutane (ppmvd)
CA5A0280
505.56
8.370
29.50
0.344
285,832.00
115,500.66
6,783.18
0.53
113,270.53
13,323.18
0.53
50,774.64
35,532.76
CA5A0280
571.99
12.300
30.60
0.459
275,316.91
113,347.86
6,775.19
0.54
114,580.81
13,684.23
0.54
54,365.84
34,297.09
CA5A0280
551.55
18.300
32.70
0.359
278,916.27
123,708.52
6,628.30
0.54
124,396.66
12,803.23
0.54
47,143.31
28,321.31
34.0809
34.0809
60.07
76.139
16.04
30.07
28.05
26.04
44.1
42.08
40.065
58.12
58.12
0.0009
0.0000
0.0001
0.00000136
0.2065
0.1625
0.0087
0.0000
0.2381
0.0257
0.0000
0.1356
0.0874
Field:
Molecular Wt Mass Fraction
Molecular W
Refinery Fuel Gas Speciation Profil Form Approved 03/28/2011 OMB Control No. 2060-0657 Approval Expires 03/31/2014
Fuel Gas Data
Enter the organic compound composition data
Instruction:
Field:
Facility ID Number
Molecular Wt Mass Fraction
106-98-9
107-01-7
115-11-7
1-Butene (ppmvd)
2-Butene (ppmvd)
Isobutene (ppmvd)
590-19-2
106-99-0
1,2-Butadiene 1,3-Butadiene (ppmvd) (ppmvd)
109-66-0 n-Pentane (ppmvd)
78-78-4
287-92-3
2Cyclopentane Methylbutane (ppmvd) (ppmvd)
109-67-1
627-20-3
646-04-8
563-46-2
563-45-1
513-35-9
1-Pentene (ppmvd)
Cis-2-pentene (ppmvd)
Trans-2pentene (ppmvd)
2-Methyl-1butene (ppmvd)
3-Methyl-1butene (ppmvd)
2-Methyl-2butene (ppmvd)
CA5A0280
3,845.93
3,281.74
4,959.40
0.53
90.87
6,159.25
8,323.26
603.66
840.43
239.12
487.41
603.66
364.76
700.72
CA5A0280
4,218.99
3,561.71
4,991.62
0.54
92.39
7,002.63
9,746.00
685.57
958.71
277.82
562.60
694.28
414.61
810.72
CA5A0280
3,651.76
3,012.08
3,904.83
0.54
88.31
5,850.78
7,771.96
579.37
813.06
253.07
479.22
581.52
358.61
685.98
Molecular W
56.106
56.106
56.106
54.091
54.091
72.15
72.15
70.1
70.13
70.13
70.13
70.13
70.13
70.13
0.0101
0.0085
0.0119
0.0000
0.0002
0.0210
0.0286
0.0020
0.0028
0.0008
0.0016
0.0020
0.0012
0.0024
Refinery Fuel Gas Speciation Profil Form Approved 03/28/2011 OMB Control No. 2060-0657 Approval Expires 03/31/2014
Assume n-Hexane
Fuel Gas Data
Instruction:
142-29-0
591-95-7
1574-41-0
2004-70-8
591-93-5
591-96-8
598-25-4
Facility ID Number
Cylcopentene (ppmvd)
1,2Pentadiene (ppmvd)
1-cis-3Pentadiene (ppmvd)
1-trans-3Pentadiene (ppmvd)
1,4Pentadiene (ppmvd)
2,3-Pentadiene (ppmvd)
3-Methyl-1,2butadiene (ppmvd)
CA5A0280
121.48
19.09
159.13
40.64
6.29
N/A
10.24
26.66
N/A
257.25
12,947.76
CA5A0280
138.75
23.61
170.52
46.90
7.73
N/A
11.64
31.45
N/A
292.29
14,456.86
CA5A0280
130.41
21.54
178.12
43.18
6.57
N/A
11.42
28.32
N/A
283.22
13,355.67
Field:
Molecular Wt Mass Fraction
Molecular W
78-79-5
542-92-7
2-Methyl-1,3Cyclopentadie butadiene ne (ppmvd) (ppmvd)
71-43-2
110-54-3
Benzene (ppmvd)
other C6+ (ppmvd)
68.12
68.12
68.12
68.12
68.12
68.12
68.12
68.12
66.10114
78.11
86.18
0.0004
0.0001
0.0005
0.0001
0.0000
0.0000
0.0000
0.0001
0.0000
0.000997
0.0538
Toxic Emissions from Component Leaks CAS Number
Pollutant
--7783-06-4 463-58-1 75-15-0 74-82-8 74-84-0 74-85-1 74-86-2 74-98-6 115-07-1 463-49-0 106-97-8 75-28-5 106-98-9 107-01-7 115-11-7 590-19-2 106-99-0 109-66-0 78-78-4 287-92-3 109-67-1 627-20-3 646-04-8 563-46-2 563-45-1 513-35-9 142-29-0 591-95-7 1574-41-0 2004-70-8 591-93-5 598-25-4 78-79-5 71-43-2 110-54-3
POC or ROG
Mass Fraction
1,2
Hydrogen sulfide Carbonyl sulfide
Carbon disulfide1 Methane Ethane Ethylene Acetylene Propane Propylene1 Propadiene n-Butane Isobutane 1-Butene 2-Butene Isobutene 1,2-Butadiene 1,3-Butadiene1 n-Pentane 2-Methylbutane Cyclopentane 1-Pentene Cis-2-pentene Trans-2-pentene 2-Methyl-1-butene 3-Methyl-1-butene 2-Methyl-2-butene Cylcopentene 1,2-Pentadiene 1-cis-3-Pentadiene 1-trans-3-Pentadiene 1,4-Pentadiene 3-Methyl-1,2-butadiene 2-Methyl-1,3-butadiene Benzene1 Other C6+1,3
1.00E+00 8.71E-04 8.54E-05 1.36E-06 2.07E-01 1.62E-01 8.68E-03 6.43E-07 2.38E-01 2.57E-02 9.89E-07 1.36E-01 8.74E-02 1.01E-02 8.47E-03 1.19E-02 1.34E-06 2.25E-04 2.10E-02 2.86E-02 2.01E-03 2.81E-03 8.28E-04 1.64E-03 2.02E-03 1.22E-03 2.36E-03 4.08E-04 6.71E-05 5.30E-04 1.36E-04 2.15E-05 3.48E-05 9.02E-05 9.97E-04 5.38E-02
1. Toxic Air Contaminant 2. All TRS is assumed to consist of H2S 3. Other C6+ fractions are all assumed to be n-Hexane
Emissions Annual Hourly (lb/hr) (lb/year) 1.05 9163 9.11E-04 7.98E+00 8.94E-05 7.83E-01 1.42E-06 1.24E-02 2.16E-01 1.89E+03 1.70E-01 1.49E+03 9.08E-03 7.95E+01 6.72E-07 5.89E-03 2.49E-01 2.18E+03 2.69E-02 2.35E+02 1.03E-06 9.06E-03 1.42E-01 1.24E+03 9.14E-02 8.01E+02 1.05E-02 9.23E+01 8.86E-03 7.77E+01 1.25E-02 1.09E+02 1.40E-06 1.23E-02 2.35E-04 2.06E+00 2.20E-02 1.93E+02 2.99E-02 2.62E+02 2.10E-03 1.84E+01 2.94E-03 2.57E+01 8.66E-04 7.58E+00 1.72E-03 1.51E+01 2.11E-03 1.85E+01 1.28E-03 1.12E+01 2.47E-03 2.16E+01 4.27E-04 3.74E+00 7.02E-05 6.15E-01 5.54E-04 4.86E+00 1.43E-04 1.25E+00 2.25E-05 1.97E-01 3.64E-05 3.19E-01 9.44E-05 8.27E-01 1.04E-03 9.13E+00 5.63E-02 4.93E+02
Attachment A-5 Locomotive Emissions
Parameter Additional LPG to be Transported due to Project Weight of Empty Tank Car Average Additional Daily Tank Car due to Project Average Additional Annual Number of Tank Car due to Project Average Total Annual Weight of Empty Tank Car Annual Average Gross Weight Hauled Assuming the Facility is Serviced Once daily Therefore Average Daily Number of Railcars per Train Total Track Length from Phillips66 to Richmond Yard Total Track Length in California Total Track Length in BAAQMD
Year 2015 Annual Locomotive Criteria Pollutant and GHG Emissions and Fuel Consumption Value Unit Reference 276,599 short tons/year Based on Project Description 50.4 short tons/car http://www.americanrailcar.com/pdf/RailcarManufacturing/TA-Pressure-33600.pdf 12 Cars/day Based on Project Description 4380 Cars/year Based on 365 days/year operation 220,752 short tons/year 497,351 short tons/year Freight Weight + Tare Weight 1 train/day 12 Cars/train 12 miles Google Earth - Phillips66 to Richmond Yard 659 miles Google Maps - Average of Union Pacific route and BNSF route to CA-AZ border Google Earth - Average of Richmond Yard to Southern BAAQMD boundary (south of Gilroy) on Union 67 miles Pacific route and Eastern BAAQMD boundary on BNSF route
Conversion Factors 928 Gross ton-miles/gal 15 ppmw 3200 g/gal
Fuel Consumption Index (Gross Weight - Locomotive Weight) Sulfur Content of Fuel Density of Diesel Number of Locomotives required at Phillips66 Switching Time at Phillips66 Average Train Size
1 per train 1 hr 30 cars/train
Fuel Consumed during Yard Operation
9.4 gal/hr/locomotive
Operation Type Large Line Haul Switch Small Line Haul
CO 26.624 27.816 23.296
Calculated based on methodology from http://www.metro4-sesarm.org/pubs/railroad/FinalGuidance.pdf California Diesel Fuel Standard Emission Factors for Locomotives, EPA-420-F-09-025, April 2009 Assumption Assumption Assumption Revised Inventory Guidance for Locomotive Emissions, Sierra Research, pg 14, footnote 2, June 2004, http://www.metro4-sesarm.org/pubs/railroad/FinalGuidance.pdf
Year 2015 Locomotive Emission Factors (g/gal fuel)1 POC Nox Sox 6.0021 129 0.096 13.2678 215 0.096 12.3201 240 0.096
PM2.5 3.3 4.7 5.3
CO2e1,2 10314 10314 10314
CO 0.24 1.52 1.76
Year 2015 Annual Line Haul Emissions (Within BAAQMD) Emissions (tons/year) ROG NOx SOx 0.13 2.46 0.001 0.34 7.39 0.005 0.47 9.84 0.006
PM10 0.06 0.19 0.25
PM2.5 0.05 0.19 0.24
CO 0.04 0.04
Year 2015 Annual Switching Emissions (Within BAAQMD) Emissions (tons/year) ROG NOx SOx 0.02 0.33 0.00 0.02 0.33 0.0001
PM10 0.01 0.01
PM2.5 0.01 0.01
PM10 3.4 4.8 5.5
1. Emission Factors for Locomotives, EPA-420-F-09-025, April 2009
Track Phillips66 to Richmond Yard Richmond Yard to BAAQMD Border Total Line Haul Emissions
Track Phillips66 Total Switch Emissions
Operation Type Small Line Haul Large Line Haul
Operation Type Switch
Attachment A-6 On-road Vehicle Emissions
Year 2015 On-road Vehicle Criteria Pollutant and GHG Emissions and Fuel Consumption Parameters Particle Size Multiplier (k) - lb/VMT Silt Loading (sL) - g/m2 Average Fleet Weight (W) - tons Emission Factor 1. AP-42, Section 13.2.1, January 2011
Vehicle Type Commuter Vehicles
Paved Road Dust Emission Factor1 PM10 0.0022 0.03 2.2 2.02E-04
PM2.5 0.00054 0.03 2.2 4.96E-05
Vehicle Class
Fuel Type
LDA
GAS
CO
ROG
NOx
3.91E-03
3.91E-04
3.40E-04
Emission Factors (lb/mi)1 Fugitive Exhaust SOx PM10 PM102 7.79E-06 5.24E-06 3.01E-04
Diesel PM 0.00E+00
Exhaust PM2.5 4.78E-06
Fugitive PM2.52 8.88E-05
Notes: 1. The emission factors, except fugitive emissions from entrained road dust, were compiled by running the California Air Resources Board's EMFAC2011 Emission Model and dividing calculated daily emissions by daily vehicle-miles-traveled. All the emission factors account for the emissions from start, running and idling exhaust. In addition, the VOC emission factors take into account diurnal, hot soak, running and resting emissions. 2. Fugitive PM10 and PM2.5 emission factors take into account tire and brake wear and entrained paved road dust.
Vehicle Type Commuter Vehicles Total
Number of Trips
Round Trip Length1
trips/day
mile/round-trip
CO
ROG
2
19
1.48E-01 1.48E-01
1.49E-02 1.49E-02
1
Daily Emission Within BAAQMD (lb/day) Exhaust Fugitive NOx SOx PM10 PM10 1.29E-02 2.96E-04 1.99E-04 1.14E-02 1.29E-02 2.96E-04 1.99E-04 1.14E-02
Diesel PM 0.00E+00 0.00E+00
Exhaust PM2.5 1.82E-04 1.82E-04
Fugitive PM2.5 3.37E-03 3.37E-03
Annual Emissions Within BAAQMD (tons/year) Exhaust Fugitive Exhaust Fugitive trips/year mile/round-trip CO ROG NOx SOx Diesel PM PM10 PM10 PM2.5 PM2.5 2.71E-02 2.71E-03 2.36E-03 5.40E-05 3.63E-05 2.09E-03 0.00E+00 3.31E-05 6.16E-04 730 19 Commuter Vehicles 2.71E-02 2.71E-03 2.36E-03 5.40E-05 3.63E-05 2.09E-03 0.00E+00 3.31E-05 6.16E-04 Total 1. Trip length for propane trucks within BAAQMD = Average of Distance from Rodeo, CA to the southern border of Air District (via Hwys 80W, 880S, and 101 S) and Distance from Rodeo, CA to the eastern border of Air District (via Hwy 4) Round trip length for commuter vehicles = 2 x Default one -way trip length of Commercial-Work (C-W) trip for BAAQMD/SF Air Basin/Contra Cost County from CalEEMod Number of Trips
Vehicle Type
Round Trip Length
Attachment A-7 Daily U233 Fuel Gas Data
DATE 1/1/2009 1/2/2009 1/3/2009 1/4/2009 1/5/2009 1/6/2009 1/7/2009 1/8/2009 1/9/2009 1/10/2009 1/11/2009 1/12/2009 1/13/2009 1/14/2009 1/15/2009 1/16/2009 1/17/2009 1/18/2009 1/19/2009 1/20/2009 1/21/2009 1/22/2009 1/23/2009 1/24/2009 1/25/2009 1/26/2009 1/27/2009 1/28/2009 1/29/2009 1/30/2009 1/31/2009 2/1/2009 2/2/2009 2/3/2009 2/4/2009 2/5/2009 2/6/2009 2/7/2009 2/8/2009 2/9/2009 2/10/2009 2/11/2009 2/12/2009 2/13/2009 2/14/2009 2/15/2009 2/16/2009 2/17/2009 2/18/2009 2/19/2009 2/20/2009 2/21/2009 2/22/2009 2/23/2009 2/24/2009 2/25/2009 2/26/2009 2/27/2009 2/28/2009 3/1/2009 3/2/2009 3/3/2009 3/4/2009 3/5/2009 3/6/2009 3/7/2009 3/8/2009 3/9/2009
U233 FG
U233 Total S
U233 FG SO2
MSCFD 36,424 35,533 36,013 35,013 35,133 35,162 36,438 36,114 35,737 35,381 34,445 33,907 34,348 35,624 36,061 36,715 36,823 32,963 32,132 33,395 32,368 32,765 33,833 35,622 36,994 35,268 34,667 34,025 33,793 33,527 33,817 33,276 32,918 31,799 30,532 31,341 31,541 32,050 32,440 32,521 32,485 31,750 33,553 34,433 33,545 33,810 34,462 35,806 35,297 36,933 37,503 38,282 39,774 39,470 36,443 33,406 33,616 36,151 33,562 36,386 33,550 32,106 32,612 32,071 29,664 28,452 28,035 28,322
ppm 272.3 270.2 313.1 324.2 310.4 302.3 282.3 305.3 283.6 321.8 302.8 304.3 306.1 317.0 283.7 261.2 272.5 380.5 370.0 296.5 304.8 309.8 327.0 280.8 256.1 284.0 340.9 326.5 313.0 321.3 335.6 333.8 352.5 386.6 428.0 383.3 298.4 308.2 304.5 359.9 320.8 342.8 358.9 313.9 355.5 333.3 324.9 283.9 260.9 284.1 335.7 359.3 297.3 269.6 276.8 287.0 278.4 197.1 280.2 277.3 277.4 249.6 246.1 317.9 301.0 296.3 258.3 258.0
lb/d 1,648 1,595 1,873 1,885 1,811 1,766 1,708 1,831 1,684 1,891 1,733 1,714 1,747 1,876 1,700 1,593 1,667 2,083 1,975 1,645 1,639 1,686 1,838 1,662 1,574 1,664 1,963 1,846 1,757 1,789 1,885 1,845 1,928 2,042 2,171 1,996 1,563 1,641 1,641 1,944 1,731 1,808 2,000 1,795 1,981 1,872 1,860 1,688 1,530 1,743 2,091 2,285 1,964 1,768 1,675 1,592 1,554 1,184 1,562 1,676 1,546 1,331 1,333 1,693 1,483 1,400 1,203 1,214
DATE 3/10/2009 3/11/2009 3/12/2009 3/13/2009 3/14/2009 3/15/2009 3/16/2009 3/17/2009 3/18/2009 3/19/2009 3/20/2009 3/21/2009 3/22/2009 3/23/2009 3/24/2009 3/25/2009 3/26/2009 3/27/2009 3/28/2009 3/29/2009 3/30/2009 3/31/2009 4/1/2009 4/2/2009 4/3/2009 4/4/2009 4/5/2009 4/6/2009 4/7/2009 4/8/2009 4/9/2009 4/10/2009 4/11/2009 4/12/2009 4/13/2009 4/14/2009 4/15/2009 4/16/2009 4/17/2009 4/18/2009 4/19/2009 4/20/2009 4/21/2009 4/22/2009 4/23/2009 4/24/2009 4/25/2009 4/26/2009 4/27/2009 4/28/2009 4/29/2009 4/30/2009 5/1/2009 5/2/2009 5/3/2009 5/4/2009 5/5/2009 5/6/2009 5/7/2009 5/8/2009 5/9/2009 5/10/2009 5/11/2009 5/12/2009 5/13/2009 5/14/2009 5/15/2009 5/16/2009 5/17/2009 5/18/2009
U233 FG
U233 Total S
U233 FG SO2
MSCFD 29,279 28,637 28,622 27,867 27,652 26,924 25,347 25,090 26,214 26,574 25,970 25,400 26,028 25,555 25,896 24,863 25,724 25,650 25,654 25,181 24,548 25,261 24,889 24,239 23,935 22,849 23,040 22,314 23,849 25,886 26,817 27,214 27,201 26,937 27,465 29,098 30,389 30,427 30,920 31,696 34,618 30,953 25,738 26,210 27,990 28,929 28,605 28,615 28,963 29,078 28,169 26,032 26,005 26,146 27,733 29,291 30,456 29,237 29,067 28,600 30,062 25,634 27,591 26,859 26,997 27,631 28,233 28,660 28,370 29,479
ppm 310.8 325.5 287.9 265.8 291.3 344.9 380.1 350.1 365.7 378.6 403.9 334.0 305.1 365.7 327.2 344.3 352.6 351.8 347.8 371.0 409.9 389.1 408.6 418.7 380.7 373.0 404.5 447.3 432.7 321.9 329.8 337.0 344.3 322.8 329.9 332.9 317.2 332.5 325.0 320.6 308.2 239.8 25.1 31.3 24.5 23.0 23.4 23.0 22.1 23.4 20.4 24.9 26.9 25.0 102.5 419.0 547.3 548.1 538.0 448.5 463.3 490.8 481.5 562.7 566.7 543.0 563.9 556.5 561.3 545.0
lb/d 1,511 1,548 1,369 1,230 1,338 1,543 1,600 1,459 1,592 1,671 1,742 1,409 1,319 1,552 1,408 1,422 1,506 1,499 1,482 1,552 1,671 1,633 1,689 1,686 1,514 1,416 1,548 1,658 1,714 1,384 1,469 1,523 1,556 1,444 1,505 1,609 1,601 1,680 1,669 1,688 1,772 1,233 107 136 114 111 111 109 107 113 95 108 116 108 472 2,039 2,769 2,662 2,598 2,131 2,314 2,090 2,207 2,510 2,541 2,492 2,645 2,649 2,645 2,669
DATE 5/19/2009 5/20/2009 5/21/2009 5/22/2009 5/23/2009 5/24/2009 5/25/2009 5/26/2009 5/27/2009 5/28/2009 5/29/2009 5/30/2009 5/31/2009 6/1/2009 6/2/2009 6/3/2009 6/4/2009 6/5/2009 6/6/2009 6/7/2009 6/8/2009 6/9/2009 6/10/2009 6/11/2009 6/12/2009 6/13/2009 6/14/2009 6/15/2009 6/16/2009 6/17/2009 6/18/2009 6/19/2009 6/20/2009 6/21/2009 6/22/2009 6/23/2009 6/24/2009 6/25/2009 6/26/2009 6/27/2009 6/28/2009 6/29/2009 6/30/2009 7/1/2009 7/2/2009 7/3/2009 7/4/2009 7/5/2009 7/6/2009 7/7/2009 7/8/2009 7/9/2009 7/10/2009 7/11/2009 7/12/2009 7/13/2009 7/14/2009 7/15/2009 7/16/2009 7/17/2009 7/18/2009 7/19/2009 7/20/2009 7/21/2009 7/22/2009 7/23/2009 7/24/2009 7/25/2009 7/26/2009 7/27/2009
U233 FG
U233 Total S
U233 FG SO2
MSCFD 28,778 27,056 27,554 28,606 27,414 30,695 32,257 34,029 33,326 33,917 33,488 33,606 33,958 33,970 34,419 33,144 31,957 32,053 31,981 32,338 32,311 32,663 32,185 31,583 31,758 30,058 30,315 30,711 31,386 31,745 31,702 31,487 32,321 31,827 31,517 31,485 32,223 32,568 32,315 31,861 32,386 32,855 32,476 31,446 31,976 33,195 33,548 34,016 33,448 33,007 33,215 32,826 32,683 32,666 31,153 31,633 31,668 32,957 33,305 32,920 32,771 32,815 33,403 33,458 33,279 33,703 33,484 33,204 32,967 33,032
ppm 522.0 559.4 529.5 514.3 527.2 499.3 488.2 474.1 477.2 417.4 437.3 458.2 446.9 515.4 444.8 451.6 434.0 445.8 447.1 469.7 486.6 479.4 498.1 516.2 484.1 420.2 474.9 495.9 506.3 451.0 492.8 453.5 478.6 443.1 535.4 501.4 486.7 378.9 394.5 461.9 402.1 401.0 441.2 473.2 465.6 448.4 355.9 430.0 386.8 415.9 392.2 466.3 420.2 459.1 354.5 337.4 489.4 469.9 429.6 396.0 410.9 428.4 406.5 418.1 372.0 402.7 422.1 422.0 452.0 434.0
lb/d 2,495 2,514 2,424 2,444 2,401 2,546 2,616 2,680 2,641 2,352 2,432 2,557 2,521 2,908 2,543 2,486 2,304 2,374 2,375 2,523 2,611 2,601 2,663 2,708 2,553 2,098 2,391 2,530 2,640 2,378 2,595 2,372 2,569 2,343 2,803 2,622 2,605 2,050 2,117 2,445 2,163 2,188 2,380 2,472 2,473 2,472 1,983 2,429 2,149 2,280 2,164 2,543 2,281 2,491 1,835 1,773 2,574 2,572 2,377 2,165 2,237 2,335 2,255 2,324 2,056 2,254 2,348 2,327 2,475 2,381
DATE 7/28/2009 7/29/2009 7/30/2009 7/31/2009 8/1/2009 8/2/2009 8/3/2009 8/4/2009 8/5/2009 8/6/2009 8/7/2009 8/8/2009 8/9/2009 8/10/2009 8/11/2009 8/12/2009 8/13/2009 8/14/2009 8/15/2009 8/16/2009 8/17/2009 8/18/2009 8/19/2009 8/20/2009 8/21/2009 8/22/2009 8/23/2009 8/24/2009 8/25/2009 8/26/2009 8/27/2009 8/28/2009 8/29/2009 8/30/2009 8/31/2009 9/1/2009 9/2/2009 9/3/2009 9/4/2009 9/5/2009 9/6/2009 9/7/2009 9/8/2009 9/9/2009 9/10/2009 9/11/2009 9/12/2009 9/13/2009 9/14/2009 9/15/2009 9/16/2009 9/17/2009 9/18/2009 9/19/2009 9/20/2009 9/21/2009 9/22/2009 9/23/2009 9/24/2009 9/25/2009 9/26/2009 9/27/2009 9/28/2009 9/29/2009 9/30/2009 10/1/2009 10/2/2009 10/3/2009 10/4/2009 10/5/2009
U233 FG
U233 Total S
U233 FG SO2
MSCFD 32,942 33,234 32,999 33,131 33,199 33,572 33,847 33,676 33,495 32,588 31,314 31,954 32,187 31,452 32,112 31,111 31,689 32,452 31,919 31,823 31,443 31,928 32,200 32,267 32,380 33,915 33,003 33,471 33,255 33,468 33,597 32,898 32,129 33,061 32,987 33,036 32,533 33,174 33,515 33,484 33,284 33,175 33,047 34,239 33,071 34,130 34,070 33,824 33,501 33,158 30,697 29,823 30,155 30,843 30,442 31,131 29,473 31,038 31,735 30,369 32,828 32,196 30,296 30,946 33,470 30,715 31,648 28,276 27,083 26,405
ppm 471.8 446.5 464.2 462.7 484.7 495.3 476.2 464.7 488.4 493.4 522.1 470.9 510.6 520.4 407.7 536.6 495.8 424.3 453.6 470.1 471.0 431.6 389.6 412.1 461.9 473.7 443.2 451.9 431.9 458.5 469.5 486.0 463.3 445.3 394.9 467.6 509.9 484.7 435.9 476.1 490.1 457.5 454.0 398.8 422.8 465.6 431.3 352.8 405.6 349.3 449.2 441.0 473.9 432.8 450.4 446.9 416.0 379.1 303.4 322.0 341.6 216.6 180.9 178.7 176.0 220.3 198.4 226.9 257.7 276.3
lb/d 2,582 2,465 2,544 2,546 2,673 2,762 2,677 2,599 2,717 2,671 2,716 2,499 2,730 2,719 2,174 2,773 2,610 2,287 2,405 2,485 2,460 2,289 2,084 2,209 2,484 2,669 2,430 2,512 2,386 2,549 2,620 2,656 2,472 2,445 2,164 2,566 2,755 2,671 2,427 2,648 2,710 2,521 2,492 2,268 2,323 2,640 2,441 1,982 2,257 1,924 2,290 2,185 2,374 2,217 2,277 2,311 2,037 1,955 1,599 1,624 1,863 1,158 911 918 978 1,124 1,043 1,066 1,159 1,212
DATE 10/6/2009 10/7/2009 10/8/2009 10/9/2009 10/10/2009 10/11/2009 10/12/2009 10/13/2009 10/14/2009 10/15/2009 10/16/2009 10/17/2009 10/18/2009 10/19/2009 10/20/2009 10/21/2009 10/22/2009 10/23/2009 10/24/2009 10/25/2009 10/26/2009 10/27/2009 10/28/2009 10/29/2009 10/30/2009 10/31/2009 11/1/2009 11/2/2009 11/3/2009 11/4/2009 11/5/2009 11/6/2009 11/7/2009 11/8/2009 11/9/2009 11/10/2009 11/11/2009 11/12/2009 11/13/2009 11/14/2009 11/15/2009 11/16/2009 11/17/2009 11/18/2009 11/19/2009 11/20/2009 11/21/2009 11/22/2009 11/23/2009 11/24/2009 11/25/2009 11/26/2009 11/27/2009 11/28/2009 11/29/2009 11/30/2009 12/1/2009 12/2/2009 12/3/2009 12/4/2009 12/5/2009 12/6/2009 12/7/2009 12/8/2009 12/9/2009 12/10/2009 12/11/2009 12/12/2009 12/13/2009 12/14/2009
U233 FG
U233 Total S
U233 FG SO2
MSCFD 25,487 25,154 25,468 26,672 29,994 32,823 35,289 39,336 33,275 33,069 31,624 32,299 32,665 31,912 31,662 32,380 31,272 30,108 29,825 31,214 33,290 33,726 32,080 32,920 32,553 32,702 32,666 32,667 32,678 32,480 30,808 30,508 31,993 32,559 30,490 31,270 30,780 30,241 31,799 31,750 33,049 37,205 37,601 37,957 35,313 37,038 37,910 37,458 37,229 36,782 36,605 36,202 35,433 35,411 35,150 35,182 34,616 35,065 34,519 34,618 33,858 35,588 34,831 29,690 27,149 27,278 29,776 31,754 32,746 32,219
ppm 293.8 324.0 288.8 337.1 396.8 386.5 352.2 337.3 421.6 412.6 431.5 460.6 445.8 371.4 410.8 389.8 329.3 393.4 440.2 447.9 440.0 361.5 256.1 356.9 345.4 329.2 335.2 340.0 330.7 325.5 380.7 382.7 324.9 341.8 341.1 349.6 401.8 421.4 384.9 378.6 427.4 332.4 327.1 323.2 384.5 366.5 316.7 340.2 355.0 359.8 372.4 361.5 345.8 347.9 386.4 395.1 404.9 382.5 406.1 395.1 389.8 346.3 347.3 41.3 20.3 15.7 121.5 330.5 357.6 356.9
lb/d 1,244 1,354 1,222 1,493 1,977 2,107 2,065 2,204 2,330 2,267 2,266 2,471 2,419 1,969 2,161 2,097 1,711 1,967 2,181 2,322 2,433 2,025 1,365 1,952 1,868 1,788 1,819 1,845 1,795 1,756 1,948 1,939 1,726 1,849 1,728 1,816 2,054 2,117 2,033 1,996 2,346 2,054 2,043 2,038 2,255 2,255 1,994 2,117 2,195 2,198 2,265 2,174 2,035 2,046 2,256 2,309 2,328 2,228 2,328 2,272 2,192 2,047 2,009 203 92 71 601 1,743 1,945 1,910
DATE 12/15/2009 12/16/2009 12/17/2009 12/18/2009 12/19/2009 12/20/2009 12/21/2009 12/22/2009 12/23/2009 12/24/2009 12/25/2009 12/26/2009 12/27/2009 12/28/2009 12/29/2009 12/30/2009 12/31/2009 1/1/2010 1/2/2010 1/3/2010 1/4/2010 1/5/2010 1/6/2010 1/7/2010 1/8/2010 1/9/2010 1/10/2010 1/11/2010 1/12/2010 1/13/2010 1/14/2010 1/15/2010 1/16/2010 1/17/2010 1/18/2010 1/19/2010 1/20/2010 1/21/2010 1/22/2010 1/23/2010 1/24/2010 1/25/2010 1/26/2010 1/27/2010 1/28/2010 1/29/2010 1/30/2010 1/31/2010 2/1/2010 2/2/2010 2/3/2010 2/4/2010 2/5/2010 2/6/2010 2/7/2010 2/8/2010 2/9/2010 2/10/2010 2/11/2010 2/12/2010 2/13/2010 2/14/2010 2/15/2010 2/16/2010 2/17/2010 2/18/2010 2/19/2010 2/20/2010 2/21/2010 2/22/2010
U233 FG
U233 Total S
U233 FG SO2
MSCFD 33,455 31,960 32,435 33,637 32,468 32,270 31,934 32,744 31,613 31,238 31,890 31,439 32,049 31,554 33,780 36,698 37,763 36,887 37,113 38,316 40,225 39,453 34,638 33,459 34,474 31,163 35,750 36,557 33,343 33,316 33,300 32,374 33,445 32,050 33,587 36,122 36,892 31,429 29,782 31,180 31,421 32,400 35,667 35,146 32,510 34,802 36,862 37,542 36,951 36,742 36,741 37,005 36,717 35,910 35,445 33,620 32,640 33,886 33,836 33,682 32,035 29,406 33,756 36,494 35,735 35,018 33,977 34,058 34,436 34,915
ppm 380.6 398.8 413.3 374.6 377.7 372.4 361.0 393.1 423.6 430.2 408.9 386.3 393.5 431.5 387.8 375.7 363.8 414.9 419.8 381.5 348.6 369.0 403.0 379.5 397.6 407.3 409.7 408.6 435.9 374.2 414.0 453.8 410.8 409.5 412.2 386.6 341.7 409.9 419.5 420.5 442.4 372.0 347.2 400.8 397.8 418.2 389.8 407.6 410.3 318.5 320.9 373.2 372.8 400.0 368.4 396.2 354.5 424.8 403.6 472.5 483.1 471.8 463.7 408.3 404.6 387.5 405.0 405.2 336.8 392.7
lb/d 2,115 2,117 2,226 2,093 2,037 1,996 1,915 2,138 2,224 2,232 2,166 2,017 2,095 2,261 2,176 2,290 2,282 2,542 2,588 2,428 2,329 2,418 2,318 2,109 2,277 2,108 2,433 2,481 2,414 2,071 2,290 2,440 2,282 2,180 2,299 2,319 2,094 2,140 2,075 2,178 2,309 2,002 2,057 2,340 2,148 2,417 2,387 2,542 2,518 1,944 1,958 2,294 2,274 2,386 2,169 2,212 1,922 2,391 2,268 2,644 2,571 2,304 2,600 2,475 2,402 2,254 2,286 2,292 1,927 2,277
DATE 2/23/2010 2/24/2010 2/25/2010 2/26/2010 2/27/2010 2/28/2010 3/1/2010 3/2/2010 3/3/2010 3/4/2010 3/5/2010 3/6/2010 3/7/2010 3/8/2010 3/9/2010 3/10/2010 3/11/2010 3/12/2010 3/13/2010 3/14/2010 3/15/2010 3/16/2010 3/17/2010 3/18/2010 3/19/2010 3/20/2010 3/21/2010 3/22/2010 3/23/2010 3/24/2010 3/25/2010 3/26/2010 3/27/2010 3/28/2010 3/29/2010 3/30/2010 3/31/2010 4/1/2010 4/2/2010 4/3/2010 4/4/2010 4/5/2010 4/6/2010 4/7/2010 4/8/2010 4/9/2010 4/10/2010 4/11/2010 4/12/2010 4/13/2010 4/14/2010 4/15/2010 4/16/2010 4/17/2010 4/18/2010 4/19/2010 4/20/2010 4/21/2010 4/22/2010 4/23/2010 4/24/2010 4/25/2010 4/26/2010 4/27/2010 4/28/2010 4/29/2010 4/30/2010 5/1/2010 5/2/2010 5/3/2010
U233 FG
U233 Total S
U233 FG SO2
MSCFD 36,740 32,389 33,592 33,601 34,773 35,176 34,192 35,124 35,965 35,912 35,515 35,548 35,284 30,401 29,429 28,342 31,064 36,289 38,198 35,845 31,116 32,475 31,198 32,916 30,368 32,857 32,880 30,875 31,347 33,551 33,965 33,947 33,539 33,433 34,959 36,188 36,101 36,028 37,397 38,113 38,378 36,590 32,062 31,369 31,123 31,089 30,439 31,050 29,711 30,979 32,966 31,723 31,865 33,258 32,791 32,571 31,485 31,940 31,438 31,989 31,457 31,702 31,974 31,093 28,295 27,683 28,745 29,604 33,958 33,255
ppm 348.8 412.5 360.4 347.3 386.3 363.8 418.2 407.8 256.7 386.9 390.4 362.9 369.5 337.4 352.5 374.7 361.8 248.1 269.6 267.3 318.7 405.1 432.0 416.3 412.5 394.7 372.6 396.6 408.6 370.4 380.9 407.1 429.4 381.3 393.6 330.3 349.6 392.9 364.4 352.5 330.2 327.7 413.9 450.7 368.5 482.3 420.6 381.3 413.2 434.5 375.7 432.5 267.8 498.2 533.5 460.9 435.4 421.2 491.6 486.0 451.5 453.1 465.2 427.5 427.8 452.8 541.0 514.9 466.5 467.7
lb/d 2,129 2,219 2,011 1,938 2,231 2,125 2,375 2,379 1,533 2,308 2,303 2,143 2,165 1,704 1,723 1,764 1,867 1,495 1,710 1,592 1,647 2,185 2,239 2,276 2,081 2,154 2,035 2,034 2,127 2,064 2,149 2,295 2,392 2,117 2,286 1,985 2,096 2,352 2,263 2,232 2,105 1,992 2,205 2,348 1,905 2,491 2,127 1,967 2,039 2,236 2,057 2,279 1,418 2,752 2,906 2,494 2,277 2,235 2,567 2,583 2,359 2,386 2,471 2,208 2,011 2,082 2,583 2,532 2,631 2,584
DATE 5/4/2010 5/5/2010 5/6/2010 5/7/2010 5/8/2010 5/9/2010 5/10/2010 5/11/2010 5/12/2010 5/13/2010 5/14/2010 5/15/2010 5/16/2010 5/17/2010 5/18/2010 5/19/2010 5/20/2010 5/21/2010 5/22/2010 5/23/2010 5/24/2010 5/25/2010 5/26/2010 5/27/2010 5/28/2010 5/29/2010 5/30/2010 5/31/2010 6/1/2010 6/2/2010 6/3/2010 6/4/2010 6/5/2010 6/6/2010 6/7/2010 6/8/2010 6/9/2010 6/10/2010 6/11/2010 6/12/2010 6/13/2010 6/14/2010 6/15/2010 6/16/2010 6/17/2010 6/18/2010 6/19/2010 6/20/2010 6/21/2010 6/22/2010 6/23/2010 6/24/2010 6/25/2010 6/26/2010 6/27/2010 6/28/2010 6/29/2010 6/30/2010 7/1/2010 7/2/2010 7/3/2010 7/4/2010 7/5/2010 7/6/2010 7/7/2010 7/8/2010 7/9/2010 7/10/2010 7/11/2010 7/12/2010 7/13/2010 7/14/2010
U233 FG
U233 Total S
U233 FG SO2
MSCFD 32,786 31,936 29,912 31,785 30,381 31,585 34,315 36,256 38,217 37,482 36,739 36,426 36,508 35,446 34,448 36,805 36,988 36,589 36,351 35,767 35,583 34,983 35,345 36,378 35,527 34,545 35,211 35,637 35,366 35,226 33,842 33,305 34,104 34,493 34,415 34,429 33,489 33,605 34,073 33,784 33,281 33,093 33,883 32,592 34,323 35,575 35,371 35,836 36,147 34,559 34,702 35,249 34,883 34,480 34,106 33,062 32,157 27,206 23,717 27,067 34,369 35,103 33,758 34,412 36,702 35,451 34,710 37,634 38,242 38,524 37,105 36,010
ppm 443.4 398.8 449.6 437.8 539.0 521.3 434.5 447.3 488.5 446.4 453.0 519.0 545.3 501.9 505.0 458.8 380.8 407.5 406.5 400.4 389.9 430.4 463.7 416.0 468.4 524.2 546.6 541.6 495.6 424.8 400.5 409.6 458.8 524.6 543.8 487.4 478.1 498.4 521.9 561.9 565.2 484.3 458.4 463.8 439.5 382.5 269.9 433.3 462.7 457.4 486.8 483.8 477.1 429.7 401.5 273.3 231.8 249.9 308.0 291.4 408.5 469.2 465.5 464.2 429.9 449.2 506.8 508.6 453.8 434.6 449.7 422.0
lb/d 2,415 2,115 2,234 2,311 2,720 2,735 2,476 2,694 3,101 2,779 2,765 3,140 3,306 2,955 2,889 2,805 2,339 2,477 2,454 2,379 2,304 2,501 2,722 2,514 2,764 3,008 3,197 3,206 2,911 2,486 2,251 2,266 2,599 3,005 3,108 2,787 2,659 2,782 2,954 3,153 3,124 2,662 2,580 2,511 2,505 2,260 1,586 2,579 2,778 2,626 2,806 2,832 2,764 2,461 2,275 1,501 1,238 1,129 1,213 1,310 2,332 2,736 2,610 2,653 2,621 2,645 2,922 3,179 2,883 2,781 2,771 2,524
DATE 7/15/2010 7/16/2010 7/17/2010 7/18/2010 7/19/2010 7/20/2010 7/21/2010 7/22/2010 7/23/2010 7/24/2010 7/25/2010 7/26/2010 7/27/2010 7/28/2010 7/29/2010 7/30/2010 7/31/2010 8/1/2010 8/2/2010 8/3/2010 8/4/2010 8/5/2010 8/6/2010 8/7/2010 8/8/2010 8/9/2010 8/10/2010 8/11/2010 8/12/2010 8/13/2010 8/14/2010 8/15/2010 8/16/2010 8/17/2010 8/18/2010 8/19/2010 8/20/2010 8/21/2010 8/22/2010 8/23/2010 8/24/2010 8/25/2010 8/26/2010 8/27/2010 8/28/2010 8/29/2010 8/30/2010 8/31/2010 9/1/2010 9/2/2010 9/3/2010 9/4/2010 9/5/2010 9/6/2010 9/7/2010 9/8/2010 9/9/2010 9/10/2010 9/11/2010 9/12/2010 9/13/2010 9/14/2010 9/15/2010 9/16/2010 9/17/2010 9/18/2010 9/19/2010 9/20/2010 9/21/2010 9/22/2010 9/23/2010 9/24/2010
U233 FG
U233 Total S
U233 FG SO2
MSCFD 35,444 36,168 35,353 36,236 36,916 33,646 32,115 36,843 35,548 34,454 32,324 34,412 34,546 32,921 30,741 30,378 30,875 31,421 32,666 33,373 33,684 35,529 36,907 36,855 35,759 35,988 36,285 35,117 34,669 34,865 34,822 34,678 34,897 35,627 35,294 34,871 35,636 35,601 35,484 33,761 32,021 31,853 33,051 32,144 32,203 31,718 32,554 34,563 35,157 35,124 36,082 36,093 35,636 34,926 35,203 37,427 38,586 36,181 34,683 35,766 33,939 31,847 32,304 32,576 32,809 32,809 33,414 34,479 33,949 32,292 32,040 33,125
ppm 397.1 493.9 554.4 388.9 431.8 396.5 398.8 438.7 454.6 442.3 430.0 456.0 407.8 505.4 551.5 578.9 499.4 512.8 565.7 579.7 550.0 526.2 460.4 391.1 412.0 448.0 438.7 461.6 472.6 437.1 403.6 417.7 442.8 359.9 425.6 460.8 427.2 414.6 441.4 436.5 477.2 518.4 448.6 432.8 449.0 456.8 494.5 498.2 450.7 486.6 363.5 395.5 420.4 401.6 281.7 365.8 338.4 365.5 410.1 405.7 388.0 427.9 405.9 425.7 479.0 481.6 451.1 413.9 376.8 398.9 443.2 434.5
lb/d 2,338 2,967 3,256 2,341 2,648 2,216 2,127 2,685 2,685 2,531 2,309 2,606 2,340 2,764 2,816 2,921 2,561 2,677 3,069 3,213 3,077 3,106 2,823 2,394 2,447 2,678 2,644 2,692 2,721 2,532 2,334 2,406 2,567 2,130 2,495 2,669 2,529 2,452 2,602 2,448 2,538 2,743 2,463 2,311 2,402 2,407 2,674 2,860 2,632 2,839 2,179 2,371 2,488 2,330 1,647 2,274 2,169 2,197 2,363 2,410 2,188 2,264 2,178 2,304 2,611 2,625 2,504 2,370 2,125 2,140 2,359 2,391
DATE 9/25/2010 9/26/2010 9/27/2010 9/28/2010 9/29/2010 9/30/2010 10/1/2010 10/2/2010 10/3/2010 10/4/2010 10/5/2010 10/6/2010 10/7/2010 10/8/2010 10/9/2010 10/10/2010 10/11/2010 10/12/2010 10/13/2010 10/14/2010 10/15/2010 10/16/2010 10/17/2010 10/18/2010 10/19/2010 10/20/2010 10/21/2010 10/22/2010 10/23/2010 10/24/2010 10/25/2010 10/26/2010 10/27/2010 10/28/2010 10/29/2010 10/30/2010 10/31/2010 11/1/2010 11/2/2010 11/3/2010 11/4/2010 11/5/2010 11/6/2010 11/7/2010 11/8/2010 11/9/2010 11/10/2010 11/11/2010 11/12/2010 11/13/2010 11/14/2010 11/15/2010 11/16/2010 11/17/2010 11/18/2010 11/19/2010 11/20/2010 11/21/2010 11/22/2010 11/23/2010 11/24/2010 11/25/2010 11/26/2010 11/27/2010 11/28/2010 11/29/2010 11/30/2010 12/1/2010 12/2/2010 12/3/2010 12/4/2010 12/5/2010
U233 FG
U233 Total S
U233 FG SO2
MSCFD 32,672 31,018 31,366 30,403 30,588 33,051 32,720 32,287 31,483 31,261 30,368 30,451 28,546 27,746 31,114 29,770 29,272 29,318 30,307 29,652 30,179 30,009 30,756 31,111 31,142 31,815 32,220 12,785 9,082 16,917 22,740 24,632 22,132 24,311 26,682 29,166 27,253 26,477 25,935 25,503 24,985 25,714 28,460 29,745 30,151 30,609 31,075 30,586 30,035 30,818 30,465 29,380 29,690 31,578 32,986 32,582 31,174 28,322 29,334 33,640 34,882 32,870 32,201 31,755 32,096 32,139 30,773 31,353 32,247 33,523 33,503 33,382
ppm 432.0 472.7 491.0 517.2 434.9 395.7 418.5 466.1 419.4 393.6 469.9 435.6 400.5 384.1 308.2 447.4 457.0 515.7 421.1 475.0 417.1 389.4 388.3 368.0 391.4 364.2 339.4 190.2 43.8 54.5 115.5 389.3 452.1 464.3 363.9 355.6 431.8 405.9 395.2 375.7 373.9 323.1 309.0 340.3 349.6 333.1 263.6 367.2 341.1 353.0 397.3 356.6 397.2 329.3 269.9 272.8 300.5 301.4 271.7 269.9 347.2 324.9 325.4 330.8 307.2 308.4 304.5 327.3 316.8 321.1 353.6 385.2
lb/d 2,344 2,435 2,558 2,612 2,210 2,172 2,274 2,499 2,193 2,044 2,370 2,203 1,899 1,770 1,593 2,212 2,222 2,512 2,120 2,340 2,091 1,941 1,984 1,901 2,025 1,925 1,816 404 66 153 436 1,593 1,662 1,875 1,613 1,723 1,954 1,785 1,703 1,592 1,552 1,380 1,461 1,681 1,751 1,694 1,360 1,865 1,702 1,807 2,010 1,740 1,959 1,727 1,479 1,476 1,556 1,418 1,324 1,508 2,012 1,774 1,741 1,745 1,638 1,646 1,557 1,705 1,697 1,788 1,968 2,136
DATE 12/6/2010 12/7/2010 12/8/2010 12/9/2010 12/10/2010 12/11/2010 12/12/2010 12/13/2010 12/14/2010 12/15/2010 12/16/2010 12/17/2010 12/18/2010 12/19/2010 12/20/2010 12/21/2010 12/22/2010 12/23/2010 12/24/2010 12/25/2010 12/26/2010 12/27/2010 12/28/2010 12/29/2010 12/30/2010 12/31/2010 1/1/2011 1/2/2011 1/3/2011 1/4/2011 1/5/2011 1/6/2011 1/7/2011 1/8/2011 1/9/2011 1/10/2011 1/11/2011 1/12/2011 1/13/2011 1/14/2011 1/15/2011 1/16/2011 1/17/2011 1/18/2011 1/19/2011 1/20/2011 1/21/2011 1/22/2011 1/23/2011 1/24/2011 1/25/2011 1/26/2011 1/27/2011 1/28/2011 1/29/2011 1/30/2011 1/31/2011 2/1/2011 2/2/2011 2/3/2011 2/4/2011 2/5/2011 2/6/2011 2/7/2011 2/8/2011 2/9/2011 2/10/2011 2/11/2011 2/12/2011 2/13/2011 2/14/2011 2/15/2011
U233 FG
U233 Total S
U233 FG SO2
MSCFD 32,733 32,030 31,364 32,728 33,413 33,901 33,095 30,780 31,267 33,459 32,773 31,632 30,176 30,485 30,595 31,456 30,843 30,723 31,130 31,555 31,316 31,603 31,687 31,922 31,872 31,660 32,152 31,589 31,494 31,360 31,563 32,050 32,011 30,895 30,838 31,043 31,072 30,336 28,579 28,145 27,507 29,125 28,648 28,028 28,526 27,054 27,836 26,010 24,720 22,709 21,157 22,128 22,917 24,704 25,447 22,489 19,350 18,344 20,365 20,100 21,449 21,573 20,448 23,378 28,162 27,436 28,365 28,909 29,226 29,655 29,444 29,588
ppm 375.9 366.2 366.1 367.6 397.4 366.9 360.1 345.0 264.0 362.1 379.6 290.0 203.5 272.2 290.5 326.3 378.3 295.6 385.0 363.0 324.3 378.9 339.8 364.8 349.3 353.2 326.7 361.9 361.0 282.9 348.8 361.7 371.6 311.2 377.1 365.5 386.9 411.5 427.3 415.1 430.0 407.6 400.1 218.5 199.9 216.8 256.6 374.1 362.2 365.5 426.4 421.4 370.4 387.8 406.9 315.8 19.4 20.1 12.3 14.0 23.4 36.5 23.8 133.2 304.6 306.6 392.2 419.1 447.0 399.7 438.5 456.5
lb/d 2,044 1,949 1,907 1,999 2,206 2,066 1,979 1,764 1,371 2,013 2,067 1,524 1,020 1,378 1,476 1,705 1,938 1,508 1,991 1,903 1,687 1,989 1,789 1,934 1,849 1,857 1,745 1,899 1,889 1,474 1,829 1,926 1,976 1,597 1,932 1,885 1,997 2,073 2,028 1,941 1,965 1,972 1,904 1,017 947 974 1,186 1,616 1,487 1,379 1,499 1,549 1,410 1,591 1,720 1,180 62 61 41 47 83 131 81 517 1,425 1,397 1,848 2,012 2,170 1,969 2,145 2,244
DATE 2/16/2011 2/17/2011 2/18/2011 2/19/2011 2/20/2011 2/21/2011 2/22/2011 2/23/2011 2/24/2011 2/25/2011 2/26/2011 2/27/2011 2/28/2011 3/1/2011 3/2/2011 3/3/2011 3/4/2011 3/5/2011 3/6/2011 3/7/2011 3/8/2011 3/9/2011 3/10/2011 3/11/2011 3/12/2011 3/13/2011 3/14/2011 3/15/2011 3/16/2011 3/17/2011 3/18/2011 3/19/2011 3/20/2011 3/21/2011 3/22/2011 3/23/2011 3/24/2011 3/25/2011 3/26/2011 3/27/2011 3/28/2011 3/29/2011 3/30/2011 3/31/2011 4/1/2011 4/2/2011 4/3/2011 4/4/2011 4/5/2011 4/6/2011 4/7/2011 4/8/2011 4/9/2011 4/10/2011 4/11/2011 4/12/2011 4/13/2011 4/14/2011 4/15/2011 4/16/2011 4/17/2011 4/18/2011 4/19/2011 4/20/2011 4/21/2011 4/22/2011 4/23/2011 4/24/2011 4/25/2011 4/26/2011 4/27/2011 4/28/2011
U233 FG
U233 Total S
U233 FG SO2
MSCFD 29,098 28,926 29,174 29,306 29,673 25,001 19,875 24,574 26,411 26,765 27,498 27,833 29,285 30,104 31,618 32,135 33,162 35,886 32,913 31,951 32,517 32,866 32,758 32,838 32,113 32,307 31,017 31,681 32,758 34,560 35,367 35,848 35,251 35,871 36,399 36,681 35,653 33,478 33,696 32,503 30,971 32,425 33,451 33,721 33,081 31,826 33,422 31,571 32,832 32,428 32,448 32,345 34,603 34,781 34,440 34,820 33,525 32,329 31,853 32,430 32,762 32,652 32,375 32,898 32,823 32,741 32,425 32,397 32,259 32,484 32,165 32,268
ppm 362.5 304.2 338.0 364.3 416.8 376.0 345.3 301.9 308.9 333.5 369.1 393.6 386.4 387.5 387.6 369.1 461.5 403.1 386.6 381.7 406.4 436.7 425.0 410.7 460.6 446.7 513.0 448.8 471.8 448.3 412.8 471.2 414.4 414.3 368.3 381.8 341.8 425.7 474.6 475.5 532.9 495.5 513.5 488.5 488.3 484.2 524.5 438.0 469.0 463.7 450.5 475.6 432.6 403.2 446.0 384.1 369.2 424.6 428.0 426.3 415.6 418.7 430.5 462.7 451.8 516.9 567.6 461.8 497.0 609.7 669.9 531.7
lb/d 1,752 1,462 1,638 1,774 2,054 1,561 1,140 1,232 1,355 1,483 1,686 1,820 1,880 1,938 2,036 1,970 2,542 2,403 2,113 2,026 2,195 2,384 2,313 2,240 2,457 2,397 2,643 2,362 2,567 2,573 2,425 2,806 2,426 2,469 2,227 2,326 2,024 2,367 2,656 2,567 2,742 2,669 2,853 2,736 2,683 2,560 2,912 2,297 2,558 2,497 2,428 2,555 2,486 2,330 2,551 2,222 2,056 2,280 2,264 2,296 2,262 2,271 2,315 2,528 2,463 2,811 3,057 2,485 2,663 3,290 3,579 2,850
DATE 4/29/2011 4/30/2011 5/1/2011 5/2/2011 5/3/2011 5/4/2011 5/5/2011 5/6/2011 5/7/2011 5/8/2011 5/9/2011 5/10/2011 5/11/2011 5/12/2011 5/13/2011 5/14/2011 5/15/2011 5/16/2011 5/17/2011 5/18/2011 5/19/2011 5/20/2011 5/21/2011 5/22/2011 5/23/2011 5/24/2011 5/25/2011 5/26/2011 5/27/2011 5/28/2011 5/29/2011 5/30/2011 5/31/2011 6/1/2011 6/2/2011 6/3/2011 6/4/2011 6/5/2011 6/6/2011 6/7/2011 6/8/2011 6/9/2011 6/10/2011 6/11/2011 6/12/2011 6/13/2011 6/14/2011 6/15/2011 6/16/2011 6/17/2011 6/18/2011 6/19/2011 6/20/2011 6/21/2011 6/22/2011 6/23/2011 6/24/2011 6/25/2011 6/26/2011 6/27/2011 6/28/2011 6/29/2011 6/30/2011 7/1/2011 7/2/2011 7/3/2011 7/4/2011 7/5/2011 7/6/2011 7/7/2011 7/8/2011 7/9/2011
U233 FG
U233 Total S
U233 FG SO2
MSCFD 32,310 31,570 31,388 31,590 31,526 31,217 30,551 30,918 31,593 31,667 28,672 31,950 25,334 21,016 21,842 21,498 21,449 20,770 21,105 18,877 19,538 18,425 19,882 18,917 18,397 17,975 19,702 18,048 16,286 17,996 17,896 18,759 20,497 19,879 20,611 20,559 23,771 28,513 27,932 25,169 26,088 25,810 25,930 24,955 23,674 20,055 20,268 21,291 22,329 22,354 22,223 21,781 19,434 20,316 21,061 21,726 22,590 23,875 22,012 21,201 23,008 23,664 24,109 24,104 26,167 27,598 29,142 31,674 33,521 34,194 33,956 34,341
ppm 447.0 497.0 603.8 671.0 590.8 748.2 716.1 678.4 414.0 332.2 470.1 434.6 184.1 76.9 51.8 48.9 54.7 61.7 77.0 98.3 67.9 110.5 107.1 55.5 152.1 231.1 99.1 96.1 110.2 119.0 119.0 137.8 207.1 310.1 50.0 16.2 73.0 55.8 6.0 8.1 6.0 8.3 7.9 29.2 19.8 57.8 105.1 176.5 206.9 221.7 211.4 246.6 238.4 197.7 174.9 198.4 188.1 296.1 375.1 358.8 267.3 275.6 373.9 402.9 425.3 501.4 447.7 444.9 440.2 435.3 451.0 470.8
lb/d 2,399 2,606 3,148 3,521 3,094 3,880 3,634 3,484 2,173 1,748 2,239 2,307 775 268 188 175 195 213 270 308 220 338 354 174 465 690 324 288 298 356 354 429 705 1,024 171 55 288 264 28 34 26 36 34 121 78 193 354 624 767 823 780 892 770 667 612 716 706 1,174 1,371 1,264 1,021 1,083 1,497 1,613 1,848 2,298 2,167 2,341 2,451 2,472 2,544 2,686
DATE 7/10/2011 7/11/2011 7/12/2011 7/13/2011 7/14/2011 7/15/2011 7/16/2011 7/17/2011 7/18/2011 7/19/2011 7/20/2011 7/21/2011 7/22/2011 7/23/2011 7/24/2011 7/25/2011 7/26/2011 7/27/2011 7/28/2011 7/29/2011 7/30/2011 7/31/2011 8/1/2011 8/2/2011 8/3/2011 8/4/2011 8/5/2011 8/6/2011 8/7/2011 8/8/2011 8/9/2011 8/10/2011 8/11/2011 8/12/2011 8/13/2011 8/14/2011 8/15/2011 8/16/2011 8/17/2011 8/18/2011 8/19/2011 8/20/2011 8/21/2011 8/22/2011 8/23/2011 8/24/2011 8/25/2011 8/26/2011 8/27/2011 8/28/2011 8/29/2011 8/30/2011 8/31/2011 9/1/2011 9/2/2011 9/3/2011 9/4/2011 9/5/2011 9/6/2011 9/7/2011 9/8/2011 9/9/2011 9/10/2011 9/11/2011 9/12/2011 9/13/2011 9/14/2011 9/15/2011 9/16/2011 9/17/2011 9/18/2011 9/19/2011
U233 FG
U233 Total S
U233 FG SO2
MSCFD 33,950 33,805 33,056 32,921 32,298 32,946 32,403 31,636 32,137 32,279 31,755 32,160 32,060 31,593 30,225 30,951 31,700 32,658 33,987 33,498 31,913 29,512 29,242 30,233 31,352 32,036 32,169 32,707 32,491 32,504 33,034 33,944 33,468 32,844 33,005 33,147 33,340 33,154 32,302 32,537 32,774 33,075 36,305 36,666 34,933 32,355 32,392 32,218 33,021 34,348 33,355 33,523 33,636 34,528 35,403 35,290 35,612 35,176 34,807 30,308 29,506 28,835 29,577 29,824 31,012 30,838 30,805 29,654 30,495 30,568 30,470 30,541
ppm 460.2 455.4 394.7 405.2 434.3 456.2 470.1 393.0 432.7 460.0 504.1 484.3 497.7 446.3 384.9 366.7 326.1 360.0 390.4 444.7 449.8 436.4 445.0 429.4 415.6 425.3 459.6 418.9 444.8 467.4 427.7 402.4 374.5 461.4 510.1 455.6 212.9 297.1 419.2 409.5 425.0 438.9 390.5 378.9 448.3 542.1 531.8 486.9 313.8 409.6 403.7 382.8 424.0 427.3 448.8 400.6 441.2 457.4 438.3 116.2 69.1 57.4 40.1 41.2 91.0 346.4 333.2 344.1 340.2 391.6 422.3 410.4
lb/d 2,595 2,557 2,167 2,216 2,330 2,496 2,530 2,065 2,310 2,466 2,659 2,587 2,651 2,342 1,932 1,885 1,717 1,953 2,204 2,475 2,384 2,139 2,161 2,157 2,164 2,263 2,456 2,276 2,401 2,523 2,347 2,269 2,082 2,517 2,797 2,509 1,179 1,636 2,249 2,213 2,314 2,411 2,355 2,307 2,601 2,913 2,861 2,606 1,721 2,337 2,237 2,132 2,369 2,451 2,639 2,348 2,610 2,673 2,534 585 338 275 197 204 469 1,775 1,705 1,695 1,723 1,988 2,137 2,082
DATE 9/20/2011 9/21/2011 9/22/2011 9/23/2011 9/24/2011 9/25/2011 9/26/2011 9/27/2011 9/28/2011 9/29/2011 9/30/2011 10/1/2011 10/2/2011 10/3/2011 10/4/2011 10/5/2011 10/6/2011 10/7/2011 10/8/2011 10/9/2011 10/10/2011 10/11/2011 10/12/2011 10/13/2011 10/14/2011 10/15/2011 10/16/2011 10/17/2011 10/18/2011 10/19/2011 10/20/2011 10/21/2011 10/22/2011 10/23/2011 10/24/2011 10/25/2011 10/26/2011 10/27/2011 10/28/2011 10/29/2011 10/30/2011 10/31/2011 11/1/2011 11/2/2011 11/3/2011 11/4/2011 11/5/2011 11/6/2011 11/7/2011 11/8/2011 11/9/2011 11/10/2011 11/11/2011 11/12/2011 11/13/2011 11/14/2011 11/15/2011 11/16/2011 11/17/2011 11/18/2011 11/19/2011 11/20/2011 11/21/2011 11/22/2011 11/23/2011 11/24/2011 11/25/2011 11/26/2011 11/27/2011 11/28/2011 11/29/2011 11/30/2011
U233 FG
U233 Total S
U233 FG SO2
MSCFD 31,085 29,940 29,517 30,160 32,083 32,955 33,498 33,051 31,823 32,401 30,691 29,692 29,456 29,871 29,720 29,167 28,827 28,370 27,300 25,430 25,829 24,968 23,599 23,411 26,579 29,982 29,376 27,729 27,732 29,011 29,964 31,025 28,850 28,600 29,501 29,834 28,359 30,291 31,011 30,873 29,368 27,763 28,691 28,924 30,478 29,442 29,917 29,664 29,823 29,407 28,961 28,502 27,467 26,954 27,904 29,570 29,441 28,923 28,129 28,393 29,016 28,690 28,827 27,969 28,211 28,334 27,803 28,455 28,162 27,819 27,615 27,420
ppm 387.8 353.3 374.2 432.6 393.7 427.2 512.9 422.0 561.7 463.6 412.2 489.1 488.5 483.2 522.2 532.6 605.2 489.7 254.5 269.1 286.2 303.8 354.0 383.8 586.8 534.5 483.6 465.8 496.1 508.3 438.3 492.7 509.8 555.7 549.3 500.4 526.0 459.7 486.9 504.2 543.7 580.3 641.1 560.5 479.8 437.9 506.0 498.5 432.7 405.0 472.0 459.1 434.8 420.3 430.2 384.4 517.3 533.4 470.1 471.3 506.5 438.0 463.4 424.3 394.4 438.9 421.1 406.8 440.0 515.3 554.9 567.4
lb/d 2,003 1,757 1,835 2,167 2,098 2,338 2,854 2,316 2,969 2,495 2,101 2,412 2,390 2,398 2,578 2,580 2,898 2,307 1,154 1,137 1,228 1,260 1,388 1,492 2,591 2,662 2,360 2,145 2,285 2,449 2,182 2,539 2,443 2,640 2,692 2,480 2,478 2,313 2,508 2,586 2,652 2,676 3,055 2,693 2,429 2,141 2,515 2,456 2,143 1,978 2,271 2,174 1,984 1,882 1,994 1,888 2,530 2,562 2,196 2,223 2,441 2,088 2,219 1,971 1,848 2,066 1,945 1,923 2,058 2,381 2,545 2,584
DATE 12/1/2011 12/2/2011 12/3/2011 12/4/2011 12/5/2011 12/6/2011 12/7/2011 12/8/2011 12/9/2011 12/10/2011 12/11/2011 12/12/2011 12/13/2011 12/14/2011 12/15/2011 12/16/2011 12/17/2011 12/18/2011 12/19/2011 12/20/2011 12/21/2011 12/22/2011 12/23/2011 12/24/2011 12/25/2011 12/26/2011 12/27/2011 12/28/2011 12/29/2011 12/30/2011 12/31/2011 1/1/2012 1/2/2012 1/3/2012 1/4/2012 1/5/2012 1/6/2012 1/7/2012 1/8/2012 1/9/2012 1/10/2012 1/11/2012 1/12/2012 1/13/2012 1/14/2012 1/15/2012 1/16/2012 1/17/2012 1/18/2012 1/19/2012 1/20/2012 1/21/2012 1/22/2012 1/23/2012 1/24/2012 1/25/2012 1/26/2012 1/27/2012 1/28/2012 1/29/2012 1/30/2012 1/31/2012 2/1/2012 2/2/2012 2/3/2012 2/4/2012 2/5/2012 2/6/2012 2/7/2012 2/8/2012 2/9/2012 2/10/2012
U233 FG
U233 Total S
U233 FG SO2
MSCFD 27,237 26,843 26,516 26,238 26,377 26,748 25,268 26,568 27,486 26,909 26,686 26,985 29,921 30,279 29,926 29,733 29,670 30,562 29,704 29,596 28,852 30,020 27,969 25,205 26,987 25,602 25,073 26,335 25,906 24,576 25,910 24,917 24,453 23,849 24,199 24,494 25,264 24,877 25,404 25,380 26,270 26,064 25,531 26,121 27,354 27,331 25,291 25,938 22,606 20,952 22,968 28,051 28,179 27,267 26,924 27,984 29,514 29,369 28,766 26,075 24,580 25,811 27,071 27,464 27,543 28,260 27,672 28,248 29,096 29,572 29,530 27,892
ppm 510.9 502.7 431.7 444.7 426.4 399.0 369.8 348.8 339.6 377.5 426.4 438.3 383.9 382.9 363.2 413.2 373.8 392.6 401.5 400.0 391.1 329.5 305.7 336.4 357.6 360.3 384.3 418.6 403.8 436.5 473.9 507.2 473.4 451.9 373.6 364.1 322.9 302.1 385.7 367.8 326.9 297.2 409.8 472.7 453.1 438.6 426.9 422.4 432.2 442.9 451.4 492.0 505.8 501.2 543.1 476.0 371.6 414.0 432.6 470.7 487.7 488.8 549.8 550.1 561.8 549.3 552.7 540.0 512.1 467.8 517.8 535.7
lb/d 2,311 2,241 1,901 1,938 1,868 1,773 1,552 1,539 1,551 1,687 1,890 1,965 1,908 1,926 1,805 2,041 1,842 1,993 1,981 1,966 1,874 1,643 1,420 1,408 1,603 1,532 1,600 1,831 1,738 1,782 2,039 2,099 1,923 1,790 1,502 1,481 1,355 1,248 1,627 1,551 1,426 1,287 1,738 2,051 2,059 1,991 1,794 1,820 1,623 1,541 1,722 2,293 2,367 2,270 2,429 2,212 1,822 2,020 2,067 2,039 1,991 2,096 2,472 2,509 2,570 2,579 2,540 2,534 2,475 2,298 2,540 2,482
DATE 2/11/2012 2/12/2012 2/13/2012 2/14/2012 2/15/2012 2/16/2012 2/17/2012 2/18/2012 2/19/2012 2/20/2012 2/21/2012 2/22/2012 2/23/2012 2/24/2012 2/25/2012 2/26/2012 2/27/2012 2/28/2012 2/29/2012 3/1/2012 3/2/2012 3/3/2012 3/4/2012 3/5/2012 3/6/2012 3/7/2012 3/8/2012 3/9/2012 3/10/2012 3/11/2012 3/12/2012 3/13/2012 3/14/2012 3/15/2012 3/16/2012 3/17/2012 3/18/2012 3/19/2012 3/20/2012 3/21/2012 3/22/2012 3/23/2012 3/24/2012 3/25/2012 3/26/2012 3/27/2012 3/28/2012 3/29/2012 3/30/2012 3/31/2012 4/1/2012 4/2/2012 4/3/2012 4/4/2012 4/5/2012 4/6/2012 4/7/2012 4/8/2012 4/9/2012 4/10/2012 4/11/2012 4/12/2012 4/13/2012 4/14/2012 4/15/2012 4/16/2012 4/17/2012 4/18/2012 4/19/2012 4/20/2012 4/21/2012 4/22/2012
U233 FG
U233 Total S
U233 FG SO2
MSCFD 27,305 26,335 27,105 26,879 26,810 26,548 25,271 24,951 26,582 25,840 24,550 24,852 25,397 25,660 25,788 24,963 24,633 23,777 24,099 23,922 22,787 23,202 23,466 24,540 24,587 26,106 29,576 30,647 30,357 27,786 26,564 27,606 25,633 25,966 30,010 28,829 26,307 25,805 24,897 26,421 28,825 29,079 28,995 28,384 26,924 25,347 28,974 28,145 28,282 29,642 29,799 29,277 29,894 29,816 29,441 29,194 28,517 29,314 29,036 29,951 29,054 28,203 28,028 29,272 28,371 28,798 28,984 29,242 29,511 28,053 27,543 27,273
ppm 581.0 519.8 478.5 543.1 527.8 347.9 329.1 368.6 562.3 493.1 556.5 575.8 568.1 407.2 493.7 506.3 303.5 299.4 488.0 721.1 625.6 663.5 675.3 646.6 638.3 640.1 578.1 480.7 402.0 387.7 349.1 335.9 371.8 447.7 437.4 421.8 463.4 547.9 535.6 514.8 493.9 467.1 442.0 457.1 492.2 508.1 477.8 502.4 498.1 470.1 440.0 477.5 435.4 416.9 393.9 407.7 424.0 384.4 411.0 468.2 426.1 445.7 382.7 318.7 329.0 336.7 319.8 312.2 319.7 332.3 396.2 442.1
lb/d 2,635 2,274 2,155 2,425 2,350 1,534 1,381 1,527 2,483 2,116 2,269 2,377 2,397 1,736 2,115 2,099 1,242 1,182 1,954 2,865 2,368 2,557 2,632 2,636 2,607 2,776 2,840 2,447 2,027 1,789 1,540 1,540 1,583 1,931 2,180 2,020 2,025 2,348 2,215 2,259 2,365 2,256 2,129 2,155 2,201 2,139 2,299 2,349 2,340 2,314 2,178 2,322 2,162 2,065 1,926 1,977 2,009 1,872 1,982 2,329 2,056 2,088 1,782 1,550 1,550 1,611 1,540 1,516 1,567 1,549 1,812 2,003
DATE 4/23/2012 4/24/2012 4/25/2012 4/26/2012 4/27/2012 4/28/2012 4/29/2012 4/30/2012 5/1/2012 5/2/2012 5/3/2012 5/4/2012 5/5/2012 5/6/2012 5/7/2012 5/8/2012 5/9/2012 5/10/2012 5/11/2012 5/12/2012 5/13/2012 5/14/2012 5/15/2012 5/16/2012 5/17/2012 5/18/2012 5/19/2012 5/20/2012 5/21/2012 5/22/2012 5/23/2012 5/24/2012 5/25/2012 5/26/2012 5/27/2012 5/28/2012 5/29/2012 5/30/2012 5/31/2012 6/1/2012 6/2/2012 6/3/2012 6/4/2012 6/5/2012 6/6/2012 6/7/2012 6/8/2012 6/9/2012 6/10/2012 6/11/2012 6/12/2012 6/13/2012 6/14/2012 6/15/2012 6/16/2012 6/17/2012 6/18/2012 6/19/2012 6/20/2012 6/21/2012 6/22/2012 6/23/2012 6/24/2012 6/25/2012 6/26/2012 6/27/2012 6/28/2012 6/29/2012 6/30/2012 7/1/2012 7/2/2012 7/3/2012
U233 FG
U233 Total S
U233 FG SO2
MSCFD 27,074 27,806 27,362 27,937 26,784 25,291 24,628 24,672 24,929 25,196 25,263 24,868 22,923 23,472 23,352 23,747 24,438 24,409 24,880 25,306 25,646 26,103 26,748 26,983 27,886 27,447 27,261 28,425 27,946 28,531 27,173 27,800 26,695 25,890 25,626 25,853 26,519 27,974 29,488 30,040 28,529 29,191 28,290 20,731 19,313 21,415 20,153 20,280 21,508 23,444 23,426 24,596 25,924 26,626 25,279 23,201 24,892 25,581 25,441 25,095 24,738 25,040 25,150 25,541 25,914 26,154 26,248 26,825 26,241 28,666 28,982 29,046
ppm 447.5 470.6 425.6 410.5 427.7 399.9 409.2 364.9 403.4 368.1 374.6 359.7 376.8 416.7 416.7 388.1 431.5 404.0 381.4 339.3 355.5 290.8 322.0 315.0 304.2 336.7 397.7 383.6 402.4 392.2 355.1 279.3 248.2 298.8 261.1 233.6 264.6 275.8 222.2 234.5 293.7 324.3 351.0 398.5 496.4 391.9 396.5 395.3 529.9 405.1 366.6 398.2 369.4 316.9 311.3 333.9 371.7 400.9 387.0 354.0 330.2 252.2 326.2 346.7 370.3 380.2 393.1 332.1 413.1 395.8 404.0 434.8
lb/d 2,012 2,174 1,934 1,905 1,903 1,680 1,674 1,496 1,670 1,540 1,572 1,486 1,435 1,625 1,616 1,531 1,752 1,638 1,576 1,426 1,515 1,261 1,431 1,412 1,409 1,535 1,801 1,811 1,868 1,859 1,603 1,290 1,100 1,285 1,111 1,003 1,165 1,281 1,088 1,170 1,392 1,572 1,649 1,372 1,592 1,394 1,327 1,331 1,893 1,577 1,427 1,627 1,591 1,401 1,307 1,287 1,537 1,703 1,635 1,476 1,357 1,049 1,363 1,471 1,594 1,652 1,714 1,480 1,801 1,885 1,945 2,098
DATE 7/4/2012 7/5/2012 7/6/2012 7/7/2012 7/8/2012 7/9/2012 7/10/2012 7/11/2012 7/12/2012 7/13/2012 7/14/2012 7/15/2012 7/16/2012 7/17/2012 7/18/2012 7/19/2012 7/20/2012 7/21/2012 7/22/2012 7/23/2012 7/24/2012 7/25/2012 7/26/2012 7/27/2012 7/28/2012 7/29/2012 7/30/2012 7/31/2012 8/1/2012 8/2/2012 8/3/2012 8/4/2012 8/5/2012 8/6/2012 8/7/2012 8/8/2012 8/9/2012 8/10/2012 8/11/2012 8/12/2012 8/13/2012 8/14/2012 8/15/2012 8/16/2012 8/17/2012 8/18/2012 8/19/2012 8/20/2012 8/21/2012 8/22/2012 8/23/2012 8/24/2012 8/25/2012 8/26/2012 8/27/2012 8/28/2012 8/29/2012 8/30/2012 8/31/2012 9/1/2012
U233 FG
U233 Total S
U233 FG SO2
MSCFD 29,709 29,638 29,661 29,149 28,429 28,590 27,664 27,486 27,903 28,625 27,279 27,198 27,250 27,148 27,782 28,102 28,382 28,379 29,039 30,055 29,730 27,547 27,320 27,694 29,403 28,906 28,707 28,680 27,891 31,494 32,095 31,863 31,085 31,473 31,243 30,234 32,896 33,004 31,145 30,629 30,492 31,019 30,839 30,893 30,693 30,440 30,321 30,680 30,754 31,097 31,574 29,239 25,934 25,408 28,534 25,213 28,198 25,222 27,639 28,309
ppm 403.2 379.3 406.7 391.3 334.3 279.2 305.9 339.1 410.1 328.9 407.2 378.2 317.8 374.2 402.1 390.8 390.3 390.0 372.3 368.9 364.6 400.7 412.8 389.0 327.1 348.5 361.0 347.9 375.1 322.6 277.5 293.8 388.3 362.6 361.9 398.5 444.8 385.5 433.7 383.9 409.6 393.9 387.0 428.1 433.1 406.2 401.2 386.4 357.5 327.9 324.0 309.2 291.3 339.5 274.5 354.5 159.5 20.6 102.4 212.0
lb/d 1,990 1,867 2,004 1,895 1,579 1,326 1,406 1,548 1,901 1,564 1,845 1,709 1,438 1,688 1,856 1,824 1,840 1,838 1,796 1,842 1,801 1,834 1,873 1,790 1,598 1,674 1,721 1,657 1,738 1,688 1,479 1,555 2,005 1,896 1,878 2,001 2,430 2,113 2,244 1,953 2,075 2,029 1,982 2,197 2,208 2,054 2,021 1,969 1,826 1,694 1,699 1,502 1,255 1,433 1,301 1,485 747 86 470 997
DATE 9/2/2012 9/3/2012 9/4/2012 9/5/2012 9/6/2012 9/7/2012 9/8/2012 9/9/2012 9/10/2012 9/11/2012 9/12/2012 9/13/2012 9/14/2012 9/15/2012 9/16/2012 9/17/2012 9/18/2012 9/19/2012 9/20/2012 9/21/2012 9/22/2012 9/23/2012 9/24/2012 9/25/2012 9/26/2012 9/27/2012 9/28/2012 9/29/2012 9/30/2012 10/1/2012 10/2/2012 10/3/2012 10/4/2012 10/5/2012 10/6/2012 10/7/2012 10/8/2012 10/9/2012 10/10/2012 10/11/2012 10/12/2012 10/13/2012 10/14/2012 10/15/2012 10/16/2012 10/17/2012 10/18/2012 10/19/2012 10/20/2012 10/21/2012 10/22/2012 10/23/2012 10/24/2012 10/25/2012 10/26/2012 10/27/2012 10/28/2012 10/29/2012 10/30/2012 10/31/2012 11/1/2012 11/2/2012 11/3/2012
U233 FG
U233 Total S
U233 FG SO2
MSCFD 27,038 27,550 29,854 28,634 28,078 28,311 28,318 28,949 28,968 26,835 29,708 28,372 28,472 27,277 27,573 26,892 27,723 27,855 27,554 28,194 28,305 27,873 28,646 28,557 29,131 29,178 29,553 29,362 29,186 32,171 30,627 30,901 30,913 32,326 26,367 24,725 24,683 24,223 24,475 24,520 24,336 24,331 23,780 24,110 25,388 25,083 26,119 23,386 19,250 17,644 19,941 23,737 24,529 24,405 26,025 30,900 28,619 28,723 28,384 26,285 26,646 27,235 26,859
ppm 244.0 299.7 391.0 360.2 436.2 428.3 409.0 395.1 353.1 392.1 438.8 439.2 413.0 401.0 401.0 401.0 401.0 401.0 401.0 401.0 401.0 401.0 401.0 401.0 401.0 401.0 401.0 401.0 401.0 401.0 401.0 400.7 374.2 304.7 293.3 407.7 385.6 375.3 423.6 436.8 340.9 365.1 340.0 313.3 307.0 325.9 259.2 256.8 285.9 176.2 35.5 32.6 181.4 340.4 502.2 427.2 382.9 388.4 407.1 420.7 496.8 515.4 460.3
lb/d 1,096 1,372 1,939 1,713 2,034 2,014 1,924 1,900 1,699 1,748 2,165 2,070 1,953 1,817 1,837 1,791 1,847 1,855 1,835 1,878 1,885 1,857 1,908 1,902 1,940 1,943 1,968 1,956 1,944 2,143 2,040 2,057 1,921 1,636 1,285 1,674 1,581 1,510 1,722 1,779 1,378 1,475 1,343 1,255 1,295 1,358 1,124 998 914 516 117 129 739 1,380 2,171 2,192 1,820 1,853 1,920 1,837 2,199 2,331 2,053
DATE 11/4/2012 11/5/2012 11/6/2012 11/7/2012 11/8/2012 11/9/2012 11/10/2012 11/11/2012 11/12/2012 11/13/2012 11/14/2012 11/15/2012 11/16/2012 11/17/2012 11/18/2012 11/19/2012 11/20/2012 11/21/2012 11/22/2012 11/23/2012 11/24/2012 11/25/2012 11/26/2012 11/27/2012 11/28/2012 11/29/2012 11/30/2012
U233 FG
U233 Total S
U233 FG SO2
MSCFD 26,966 27,273 27,422 29,167 29,439 29,321 29,759 29,631 26,908 26,490 24,863 25,275 25,129 25,567 26,089 25,316 25,088 24,724 24,968 24,465 25,390 26,287 26,716 26,558 26,797 26,376 26,244
ppm 491.5 481.4 512.9 440.9 343.7 365.1 346.1 362.4 417.3 376.0 385.3 380.0 353.0 313.4 330.0 340.6 433.5 386.3 413.6 546.1 543.9 503.8 520.4 500.2 501.8 509.0 425.0
lb/d 2,201 2,181 2,336 2,136 1,681 1,778 1,711 1,784 1,865 1,654 1,591 1,596 1,473 1,331 1,430 1,432 1,806 1,587 1,715 2,219 2,294 2,200 2,309 2,207 2,234 2,230 1,852
Appendix B BAAQMD Permit Application Forms •
Attachment B-1 – Authority to Construct Forms
•
Attachment B-2 – Title V Permit Revision Forms
Attachment B-1 Authority to Construct Forms
BAY AREA AIR QUALITY MANAGEMENT DISTRICT 939 Ellis Street, San Francisco, CA 94109 Engineering Division (415) 749-4990 www.baaqmd.gov fax (415) 749-5030
Form P-101B Authority to Construct/ Permit to Operate
1. Application Information BAAQMD Plant No.
16
Company Name
Equipment/Project Description
Phillips 66 (formerly "Conoco Phillips")
Propane Recovery Project (PRP)
2. Plant Information If you have not previously been assigned a Plant Number by the District or if you want to update any plant data that you have previously supplied to the District, please complete this section. Equipment Location City
Zip Code
Mail Address City
State
Plant Contact Telephone
Zip Code
Title (
)
Fax
(
)
Email
NAICS (North American Industry Classification System) see www.census.gov/epcd/naics02/naico602.htm
3. Proximity to a School (K-12) The sources in this permit application (check one)
Are
Are not within 1,000 ft of the outer boundary of the nearest school.
4. Application Contact Information All correspondence from the District regarding this application will be sent to the plant contact unless you wish to designate a different contact for this application. Application Contact
Brent Eastep
Mail Address
1380 San Pablo Avenue
City
Rodeo
Telephone
( 510 ) 245-4672
Title
State Fax
( 510 ) 245-4512
Email
Environmental Engineer
CA
Zip Code
94572-1299
[email protected]
5. Additional Information The following additional information is required for all permit applications and should be included with your submittal. Failure to provide this information may delay the review of your application. Please indicate that each item has been addressed by checking the box. Contact the Engineering Division if you need assistance. If a new Plant, a local street map showing the location of your business A facility map, drawn roughly to scale, that locates the equipment and its emission points Completed data form(s) and a pollutant flow diagram for each piece of equipment. (See www.baaqmd.gov/Forms/Engineering.aspx ) Project/equipment description, manufacturer’s data Discussion and/or calculations of the emissions of air pollutants from the equipment
6. Trade Secrets Under the California Public Records Act, all information in your permit application will be considered a matter of public record and may be disclosed to a third party. If you wish to keep certain items separate as specified in Regulation 2, Rule 1, Section 202.7, please complete the following steps. Each page containing trade secret information must be labeled “trade secret” with the trade secret information clearly marked. A second copy, with trade secret information blanked out, marked “public copy” must be provided. For each item asserted to be trade secret, you must provide a statement which provides the basis for your claim.
-1-
7. Small Business Certification You are entitled to a reduced permit fee if you qualify as a small business as defined in Regulation 3. In order to qualify, you must certify that your business meets all of the following criteria: The business does not employ more than 10 persons and its gross annual income does not exceed $750,000. And the business is not an affiliate of a non-small business. (Note: a non-small business employs more than 10 persons and/or its gross income exceeds $750,000.)
8. Green Business Certification You are entitled to a reduced permit fee if you qualify as a green business as defined in Regulation 3. In order to qualify, you must certify that your business meets all of the following criteria:
The business has been certified under the Bay Area Green Business Program coordinated by the Association of Bay Area Governments and implemented by participating counties. A copy of the certification is included.
9. Accelerated Permitting The Accelerated Permitting Program entitles you to install and operate qualifying sources of air pollution and abatement equipment without waiting for the District to issue a Permit to Operate. To participate in this program you must certify that your project will meet all of the following criteria. Please acknowledge each item by checking each box. Uncontrolled emissions of any single pollutant are each less than 10 lb/highest day, or the equipment has been precertified by the BAAQMD. Emissions of toxic compounds do not exceed the trigger levels identified in Table 2-5-1 (see Regulation 2, Rule 5). The source is not a diesel engine. The project is not subject to public notice requirements (the source is either more than 1000 ft. from the nearest school, or the source does not emit any toxic compound in Table 2-5-1). For replacement of abatement equipment, the new equipment must have an equal or greater overall abatement efficiency for all pollutants than the equipment being replaced. For alterations of existing sources, for all pollutants the alteration does not result in an increase in emissions. Payment of applicable fees (the minimum permit fee to install and operate each source). See Regulation 3 or contact the Engineering Division for help in determining your fees.
10. CEQA Please answer the following questions pertaining to CEQA (California Environmental Quality Act). A.
Has another public agency prepared, required preparation of, or issued a notice regarding preparation of a California Environmental Quality Act (CEQA) document (initial study, negative declaration, environmental impact report, or other CEQA document) that analyzes impacts of this project or another project of which it is a part or to which it is related? YES NO If no, go t o section 10B. Describe the document or notice, preparer, and date of document or expected date of completion: EIR by Contra Costa County Community Development Department. Expected date of completion - January 2013.
B. List and describe any other permits or agency approvals required for this project by city, regional, state or federal agencies: Land Use Permit by Contra Costa County Community Development Department
C.
List and describe all other prior or current projects for which either of the following statements is true: (1) the project that is the subject of this application could not be undertaken without the project listed below, (2) the project listed below could not be undertaken without the project that is the subject of this application: Not Applicable
11. Certification I hereby certify that all information contained herein is true and correct. (Please sign and date this form)
Brent Eastep
Envt'l Engineer
Name of person certifying (print)
Title of person certifying
Signature of person certifying
Date
Send all application materials to the BAAQMD Engineering Division, 939 Ellis Street, San Francisco, CA 94109. -2
07/27/11
DATA FORM G General Air Pollution Source
BAY AREA AIR QUALITY MANAGEMENT DISTRICT 939 Ellis Street
San Francisco, CA 94109
(415) 749-4990
FAX (415) 749-5030 www.baaqmd.gov
Form G is for general air pollution sources. Use specific forms when applicable. If this source burns fuel, then also complete Form C. 1. Business Name: 2. SIC No.:
Phillips 66 (formerly "Conoco Phillips")
2911
Date of Initial Operation
3. Name or Description: Process Code1
5035/ 9000
8. Typical operating times:
24
9. For batch or cyclic processes: 10. Exhaust gases from source: (at maximum operation)
%
hrs/day
238
Mar-May 25
%
days/week
minutes/cycle
Wet gas flowrate
MM cubic feet
Usage Unit2
usage units2 /hr
Maximum operating rate: 0.83
7
NA
S-New
Hydrotreatment unit - 20 MMscf of Refinery Fuel Gas /day
usage units2
7. Typical % of total throughput: Dec-Feb 25
(if unknown, leave blank)
Source No.:
Material Code2
6. Total throughput, last 12 mos. NA
16
NA
RFG Hydrotreatment Unit
4. Make, Model, and Rated Capacity of Equipment: 5
Plant No:
NA
52 NA
cfm
Approximate water vapor content
Jun-Aug 25 %
%
weeks/year minutes between cycles at
NA
Sep-Nov 25
°F
NA
volume%
EMISSION FACTORS (at maximum operating rate) If this form is being submitted as part of an application for an authority to construct, completion of the following table is mandatory. If not, and the Source is already in operation, completion of the table is requested but not required. If this source also burns fuel, do not include those combustion products in the emission factors below; they are accounted for on Form C. If source test or other data are available for composite emissions only, estimate from those data the emissions attributable to just the general process and show below. Check box if factors apply to emissions after Abatement Device(s). Emission Factors lb/Usage Unit 2
Basis Code 3
See Fugitive Emissions Estimate – Appendix A-3
7
11. Particulate ..................................... 12. Organics ........................................ 13. Nitrogen Oxides (as N0 2 ) .............. 14, Sulfur Dioxide ................................ 15. Carbon Monoxide .......................... 16. Other:_______________________ 17. Other:_______________________ 18. With regard to air pollutant flow from this source, what sources(s), abatement device(s) and/or emission point(s) are immediately downstream?
SP-
SP-
SP-
1See Tables G-1 through G-7 for code 3See Basis Code Table below
Person completing this form: Form G – 05/07
Brent Eastep
A P-
AP-
A-
2See Table G5 or the Material Codes Table (available upon request)
Date:
2/5/2013
Process Code Tables for General Air Pollution Sources (Data Form G)
Basis Code Codes
Method
Table
Process
0
Not applicable for this pollutant
G-1
Food & Agricultural
1 2 3 4
Source Testing or other measurement by plant Source Testing or other measurement by BAAQMD Specification from vendor Material balance by plant using engineering expertise and knowledge of process Material balances by BAAQMD using engineering expertise and knowledge of process Taken from AP-42 ("Compilation of Air Pollutant Emission Factors," E.P.A.) Taken from literature, other than AP-42 Guess
G-3 G-4 G-5 G-7 G-8 G-9
Metallurgical (Secondary Metals) Mineral Petroleum Refining Chemical/Other Miscellaneous Fugitive Emissions
5 6 7 8
TABLE G-1
FOOD AND AGRICULTURAL PROCESSES CODE 1028 1001 1022 1021 1003 1020 1004 1005 1006 1026 1007 1008 1016 1019 1023 1009 1030 1029 1027 1014 1010 1011 1007
PROCESS Aging Brewing Cleaning Conveying/transferring Cooking Cooling/stoning Cotton ginning - cleaner Cotton ginning - stick/burr machine Cotton ginning - unloading fan Dehydration Direct fired kiln Direct fired roaster Dryer - rotary Dryer - spray Dryer - other Drying tower Extraction - mechanical Extraction - solvent Fermentation Grinding Indirect fired kiln Indirect fired roaster Kiln - direct fired
1010 1012 1013 1024 1036 1025 1035 1030 1031 1015 1008 1011 1016 1017 1018 1019 1032 1020 1034 1033 1021 1999
Kiln - indirect fired Liquor aging Meat smoker Milling Mixing/blending Oven baking Packaging Pressing - extraction Pressing - other Prilling Roaster - direct fired Roaster - indirect fired Rotary dryer Screening Shipping & receiving Spray dryer Sterilization - food/pharmaceutical products Stoning/cooling Storage Sulfuring - fruit/food stuff Transferring/conveying Other/not specified
10/08
TABLE G-3
METALLURGICAL (SECONDARY METALS) DRYING (Kilns/Dryers/Ovens) 3002 3003 3004 3005
Calcining kiln Concentrate dryer Oxide kiln Other/not specified
FURNACES 3030 3007 3008 3009 3010 3011 3012 3013 3014 3015 3016 3017 3018 3019 3020 3059 3022 3021 3023 3024 3025 3026 3027
Bake furnace Blast furnace Casting furnace Crucible furnace Cupola Cupola furnace Electric arc furnace Flux furnace Heat treating furnace Horizontal muffle furnace Induction furnace Open hearth furnace Open hearth furnace w/ oxygen lance Pot furnace Retort furnace Reverberatory - rotary Reverberatory - sweat Reverberatory - other Rotary furnace - non-reverberatory Smelt-crucible furnace Smelt-reverberatory furnace Sweating furnace Other/not specified
MATERIAL HANDLING/MISCELLANEOUS 3062 3078 3029 3065 3063 3069 3031 3046 3033 3062 3034 3076 3068 3035 3036 3037
Abrasives blasting Alodyning Annealing Annealing - continuous Anodizing Buffing/polishing Can making operations Casting - miscellaneous Chlorination station Cleaning - abrasives blasting Cleaning - chemical Conveying Crushing/shredding Drawing Drilling Extruding
3047 3039 3038 3040 3041 3042 3043 3044 3045 3067 3061 3046 3047 3048 3064 3049 3072 3050 3051 3070 3080 3079 3071 3081 3052 3073 3053 3054 3055 3056 3077 3060 3075 3057 3074 3066 3999
Fabricating - miscellaneous Finishing - soak pit Finishing - other/not specified Foil converting Foil rolling Galvanizing Grinding Honing Lead oxide manufacturing Machine shop operations Milling/turning Miscellaneous casting Miscellaneous fabricating Mixing Non-destructive coating Paste mixer (lead batteries) Pickling Pitch treating (furnace electrode mfg) Plating (not chrome) Plating dec chrome-hexavalent <=500,000 amphr Plating dec chrome-hexavalent >500,000 amphr Plating dec chrome-trivalent Plating hard chrome-hexavalent Plasma metal application (thermal spraying) Reaming Refining Rolling Sand handling Sanding Sawing Screening Sintering Soldering Storage Ventilation Welding Other/not specified
10/08
TABLE G-4
MINERAL PROCESSES DRYING (Kilns/Dryers/Ovens) 4002 4082 4003 4004 4005 4006 4070 4007 4008
Calcimatic kiln Cement calcining kiln Coke dryer Curing oven Fluidized bed kiln Rotary dryer Rotary kiln Vertical kiln Other/not specified
FURNACES 4010 4012 4011 4013 4014 4015 4071 4016 4072 4017
Cupola Electric furnace Electric induction furnace Reverberatory furnace - other Reverberatory furnace - recupex Reverberatory furnace - regenex Rotary - non-reverberatory Soda lime genl furnace (glass manufacturing) Vertical furnace - other Other/not specified
MATERIAL HANDLING/MISCELLANEOUS 4073 4019 4020 4077 4078 4021 4022 4073 4023 4024 4075 4025 4026 4027 4028 4029 4030 4031 4032 4033 4034 4035
Abrasives blasting Asphalt blowing Asphalt dipping Asphalt mixing - batch/continuous Asphalt mixing - rotary drum Asphalt spraying Bagging Blasting - abrasives cleaning Blasting - quarry Blow chamber Calcining Coal cleaning - therm/flash Coal cleaning - therm/fluid bed Coal cleaning - therm/multi low pd Concrete batching - asbestos/cement products Concrete batching - other Conveying Cooling Crushing Drying (open air) Electric arc melting Fiberizing
4036 4037 4074 4038 4039 4040 4041 4042 4043 4044 4045 4046 4079 4080 4047 4048 4053 4054 4069 4061 4049 4050 4051 4052 4055 4056 4057 4058 4059 4060 4062 4068 4081 4063 4073 4064 4065 4066 4067 4076 4037 4099
Forming line (fiberglass manufacturing) Furnace room venting Glass enamel spraying Glass manufacturing - batching Glass manufacturing - material receiving Glass manufacturing - material storage Glass manufacturing - mixing Glass manufacturing - molten holding tanks Glass manufacturing - other/not specified Grinding Hold/shakeout Hydrator Loading - feed/surge/weigh bins Loading/unloading (non-mining/quarry) Milling Mining/quarry - cobbing Mining/quarry - crushing (primary) Mining/quarry - crushing (secondary) Mining/quarry - crushing (tertiary) Mining/quarry - loading/unloading Mining/quarry - open pit blasting Mining/quarry - open pit cobbing Mining/quarry - open pit drilling Mining/quarry - ore concentrating Mining/quarry - stockpiling Mining/quarry - stripping Mining/quarry - surface blasting Mining/quarry - surface drilling Mining/quarry - tailing piles Mining/quarry - tailings Mining/quarry - ventilating Mining/quarry - other Mixing operations Road surfacing Sand blasting Screening Sintering Stone cutting Storage - contained Storage - open Venting - furnace room Other/not specified
10/08
TABLE G-5
PETROLEUM REFINING PROCESSES CODE 5040 5030 5001 5002 5003 5004 5023 5038 5025 5005 5005 5005 5018 5027 5032 5028 5034 5007 5008 5009 5010 5011 5021 5026 5026 5026 5022 5031 5039 5017 5017 5024 5012 5012 5013 5013 5017 5017 5014 5029 5037 5035 5019 5020 5032 5015 5016 5033 5036 5993 5994 5995 5997 5998 5999
PROCESS Air Stripping/DAF processing Alkylation Asphalt oxidizer Blow-down system - w/ controls Blow-down system - w/o controls Catalytic reforming Chemical treating - other Coke storage piles (open) Converting - other/not specified Cooling tower Cooling tower Cooling tower Delayed coking Distillation - crude Distillation - vacuum Distillation - other Flexicoking Fluid cat cracker Fluid coking - cooling Fluid coking - general Fluid coking - storage Fluid coking - transportation Hydrocracking Hydrogen manufacturing Hydrogen manufacturing Hydrogen manufacturing Hydrotreating/hydrofining Isomerization Marine loading/unloading berths Oil-water separator Oil-water separator Polymerization Process drain - w/controls Process drain - w/controls Process drain - w/o controls Process drain - w/o controls Separator - oil/water Separator - oil/water Sludge converter Solvent extraction Sour water stripping Sulfur removal - other/caustic Thermal cracking Thermal processing - other Vacuum distillation Vacuum jet - w/ controls Vacuum jet - w/o controls Wastewater storage - ponds Wastewater storage - tanks Other/not specified Other/not specified Other/not specified Other/not specified Other/not specified Other/not specified
CODE 300 195 30 340 340 342 239 80 239 428 415 300 343 89 339 239 346 344 345 346 345 345 239 50 52 188 239 52 80 300 427 195 442 300 442 300 300 427 347 *** 442 238 446 446 339 339 339 300 300 80 89 239 339 338 321
MATERIAL Waste Water Hydrocarbons - olefinic Asphalt Crude oil * Crude oil * Cat reformer fresh feed Feedstock Coke Feedstock Water - brackish/sea Water - fresh Waste Water Delayed coke product Crude oil Vacuum distillation feed Feedstock Coker fresh feed FCC fresh feed Fluid coke product Coker fresh feed Fluid coke product Fluid coke product Feedstock C1-C2 paraffins C3+ paraffins Naphtha Feedstock C3+ paraffins Coke Waste water Process water Hydrocarbons - olefinic Waste water - sour Waste water Waste water - sour Waste water Waste water Process water Sludge (use specific Materials Code) Waste water - sour Refinery fuel gas Thermal cracker fresh feed Thermal cracker fresh feed Vacuum distillation feed Vacuum distillation feed Vacuum distillation feed Waste water Waste water Coke Crude oil Feedstock Vacuum distillation feed Waste gases Other petroleum products
USAGE UNITS 1000 barrels 1000 barrels feed tons processed 1000 bbl/day ref cap 1000 bbl/day ref cap 1000 barrels fresh feed 1000 barrels tons 1000 barrels 1000 gallons 1000 gallons 1000 barrels tons produced 1000 barrels 1000 barrels 1000 barrels 1000 barrels fresh feed 1000 barrels fresh feed tons produced 1000 barrels fresh feed tons produced tons produced 1000 barrels million cubic feet 1000 barrels feed 1000 barrels feed 1000 barrels 1000 barrels feed tons 1000 barrels 1000 gallons 1000 barrels feed 1000 barrels 1000 barrels 1000 barrels 1000 barrels 1000 barrels 1000 gallons tons produced 1000 barrels million cubic feet 1000 barrels feed 1000 barrels feed 1000 barrels 1000 barrels 1000 barrels 1000 gallons 1000 gallons tons 1000 barrels 1000 barrels feed 1000 barrels million cubic feet 1000 gallons
NOTE: Each process listed in Table G-5 has a specific material associated with it for use on the G-Form. *Code 340 for crude oil for these processes must be used; emissions are dependent on total refinery capacity rather than on throughput. Use code 89 for crude oil in any other process.
10/08
TABLE G-7
CHEMICAL PROCESSES 7019
7020 7016 7018 7131 7021 7022 7023 7096 7024 7030 7132 7031 7032 7998 7173 7073 7055 7056 7057 7033 7155 7156 7034 7035 7114 7036 7151 7037 7133 7038 7039 7023 7110 7040 7041 7042 7152 7158 7044 7046 7130 7148 7043 7144 7145 7159 7132 7053 7054 7055 7056 7057 7097 7062 7051 7052 7063 7064 7131
Air blow ml brine Ammoniating Ammonium sulfate mfg - NH3/H2SO4 proc Ammonium sulfate mfg - coke oven byprdcts Biological oxidation Bodying oil Boiling tub Brine evaporation Calcining - rotary kiln Calcining - other Carbon black manufacturing - other process Carbon dioxide liquifaction plant Carpet operation Caulking Chemical reaction - other/not specified Chemical reactor – greater than 1000 gallons Chemical reactor - other/not specified Claus - modified 2 stage Claus - modified 3 stage Claus - modified 4 stage Condensing Contaminated ground water stripping Contaminated soil remediation Cooking Creosote pressure treating Crystallizing Cyclohex - general Dipping/cleaning tank Distillation Etching Ethylene dichloride mfg - direct chlorination Ethylene dichloride mfg - oxychlorination Evaporation - brine Evaporation - other Fabrics manufacturing - bleaching Fabrics manufacturing - yarn prep Fabrics manufacturing - other/not specified Feed/holding tank Gas collection system Gas purging Gypsum pond Hydrochloric acid manufacturing Hydrochloric acid regeneration Injection – NOx control system Laboratory Landfill with gas collection system Landfill without gas collection system Liquifaction - CO2 plant Liquifaction - diaphragm Liquifaction - merc cell Mod-Claus 2 stage Mod-Claus 3 stage Mod-Claus 4 stage Neutralizing Nitration reactors Nitric acid - paraxylen gen Nitric acid concentrators Nitric acid mfg - ammonia oxid new Nitric acid mfg - ammonia oxid old Oxidation, biological
7065 7066 7147 7154 7067 7068 7153 7071 7072 7073 7074 7075 7076 7077 7078 7080 7081 7160 7103 7098 7290 7270 7230 7210 7220 7300 7250 7240 7280 7260 7200 7058 7059 7060 7061 7146 7089 7082 7083 7084 7085 7086 7087 7088 7090 7091 7092 7093 7094 7095 7047 7048 7050 7049 7157 7073 7998 7999
Phosphoric acid manufacturing - thermal Phosphoric acid manufacturing - wet process Phosphoric acid manufacturing - other Photographic equipment Pressure treating - other Prilling Process tank Pulpboard manufacturing Pyrolysis Reactor - other/not specified Regenerator Rubberized fabric mfg - hot melt coating Rubberized fabric mfg - impregnation Rubberized fabric mfg - wet coating Rubberized fabric mfg - other/not spec Scrubber Seelite exhaust Separating – DAF processing Separating - oil/water Separating - other Sewage - Digesters Sewage - Disinfection Sewage - Flow equalization Sewage - Preliminary treatment Sewage - Primary treatment Sewage - Reclamation Sewage - Secondary clarifiers Sewage - Secondary treatment Sewage - Sludge handling processes Sewage - Tertiary treatment Sewage - Wastewater treatment plant Sodium carbonate Solvay - NH3 recovery Sodium carbonate Solvay - handling Sodium carbonate Trona - calcining Sodium carbonate Trona - dryer Sterilization - medical equipment Sulfate pulping - other/not specified Sulfate pulping - blow tank accumulator Sulfate pulping - fluidbed calciner Sulfate pulping - liquor oxidation tower Sulfate pulping - mult-effect evaporation Sulfate pulping - smelt dissolv tank Sulfate pulping - turpentine condenser Sulfate pulping - washer/screen Sulfite pulping - digester Sulfite pulping - evaporator Sulfite pulping - liquor recovery Sulfite pulping - pulp digester Sulfite pulping - smelt tank Sulfite pulping - other/not specified Sulfuric acid mfg - chamber process Sulfuric acid mfg - contact process Sulfuric acid mfg - other/not specified Sulfuric acid regenerators Tank/drum/container cleaning Other chemical - reactor Other chemical reaction - other/not spec Other process/not specified
10/08
TABLE G-8
MISCELLANEOUS PROCESSES DRYING (Dehydration/Kilns/Dryers/Ovens) 7006 7002 7003 7004 7005
Natural gas dehydrating Pigment drying Spray drying Veneer drying Drying - other/not specified
MATERIAL HANDLING 7116 8007 7007 7045 7008 7009 7010 7108 7011 7115 7017 7012 7014 7013
Bagging/packaging Coke storage pile Drying Granulating Grinding Loading - storage tank Loading - tank car Milling Mixing Pelletizing Pumping facility - organic liquids Sanding Storage Material handling - other/not spec
MISCELLANEOUS 7109 7109 8001 8010
Abrasives blasting Cleaning - abrasives blasting Coating operation - powder, other nonsolvent Conveying
7164 7165 7166 7105 7104 7106 8011 8003 8004 7045 7143 7143 7170 8005 7111 7112 7113 8002 8006 7109 7079 8008 8009 8012 7161 7143 7107 8999
Composting - windows Composting - aerated static piles Composting - in-vessel Cooling - pond Cooling - tower Cooling - other Crematory retort Expanders - plastics, other Extruders - plastics, other Granulating Insulation stripping - wire Laser-stripping - wire insulation Latex dipping Material working equipment - plastics, other Molding/curing - plastics Molding/curing - rubber Molding/curing - other/not specified Oven Paper/paperboard handling equipment Sand blasting Sawmill operation Screening/Separating Shredding/Mangling/Cutting Waste material grinding Wastewater – industrial storage ponds Wire insulation stripping - laser Woodworking - other/not specified Other process - not specified
TABLE G-9 FUGITIVE EMISSION SOURCES FUGITIVE EMISSIONS 9000 9010 9070 9080 9040 9060 9030 9050
Combined fugitive emission sources Refinery flaring/blowdown Refinery pressure relief valves Refinery process drains Refinery process vessels Refinery pumps/compressors Refinery vacuum products Refinery valves/flanges
10/08
DATA FORM G General Air Pollution Source
BAY AREA AIR QUALITY MANAGEMENT DISTRICT 939 Ellis Street
San Francisco, CA 94109
(415) 749-4990
FAX (415) 749-5030 www.baaqmd.gov
Form G is for general air pollution sources. Use specific forms when applicable. If this source burns fuel, then also complete Form C. 1. Business Name: 2. SIC No.:
Phillips 66 (formerly "Conoco Phillips")
2911
Date of Initial Operation
3. Name or Description: Process Code1
5028/ 9000
8. Typical operating times:
24
9. For batch or cyclic processes: 10. Exhaust gases from source: (at maximum operation)
%
hrs/day NA
239
1000 barrels
Usage Unit2
usage units2 /hr
Maximum operating rate: Mar-May 25
7
%
days/week
minutes/cycle
Wet gas flowrate
S-New
Propane Recovery Unit - bbl/day
usage units2
7. Typical % of total throughput: Dec-Feb 25
(if unknown, leave blank)
Source No.:
Material Code2
6. Total throughput, last 12 mos. NA
16
NA
Propane Recovery Unit
4. Make, Model, and Rated Capacity of Equipment: 5
Plant No:
NA
52 NA
cfm
Approximate water vapor content
Jun-Aug 25 %
%
weeks/year minutes between cycles at
NA
Sep-Nov 25
°F
NA
volume%
EMISSION FACTORS (at maximum operating rate) If this form is being submitted as part of an application for an authority to construct, completion of the following table is mandatory. If not, and the Source is already in operation, completion of the table is requested but not required. If this source also burns fuel, do not include those combustion products in the emission factors below; they are accounted for on Form C. If source test or other data are available for composite emissions only, estimate from those data the emissions attributable to just the general process and show below. Check box if factors apply to emissions after Abatement Device(s). Emission Factors lb/Usage Unit 2
Basis Code 3
See Fugitive Emissions Estimate Appendix A-3
7
11. Particulate ..................................... 12. Organics ........................................ 13. Nitrogen Oxides (as N0 2 ) .............. 14, Sulfur Dioxide ................................ 15. Carbon Monoxide .......................... 16. Other:_______________________ 17. Other:_______________________ 18. With regard to air pollutant flow from this source, what sources(s), abatement device(s) and/or emission point(s) are immediately downstream?
SP-
SP-
SP-
1See Tables G-1 through G-7 for code 3See Basis Code Table below
Person completing this form: Form G – 05/07
Brent Eastep
A P-
AP-
A-
2See Table G5 or the Material Codes Table (available upon request)
Date:
2/5/2013
Process Code Tables for General Air Pollution Sources (Data Form G)
Basis Code Codes
Method
Table
Process
0
Not applicable for this pollutant
G-1
Food & Agricultural
1 2 3 4
Source Testing or other measurement by plant Source Testing or other measurement by BAAQMD Specification from vendor Material balance by plant using engineering expertise and knowledge of process Material balances by BAAQMD using engineering expertise and knowledge of process Taken from AP-42 ("Compilation of Air Pollutant Emission Factors," E.P.A.) Taken from literature, other than AP-42 Guess
G-3 G-4 G-5 G-7 G-8 G-9
Metallurgical (Secondary Metals) Mineral Petroleum Refining Chemical/Other Miscellaneous Fugitive Emissions
5 6 7 8
TABLE G-1
FOOD AND AGRICULTURAL PROCESSES CODE 1028 1001 1022 1021 1003 1020 1004 1005 1006 1026 1007 1008 1016 1019 1023 1009 1030 1029 1027 1014 1010 1011 1007
PROCESS Aging Brewing Cleaning Conveying/transferring Cooking Cooling/stoning Cotton ginning - cleaner Cotton ginning - stick/burr machine Cotton ginning - unloading fan Dehydration Direct fired kiln Direct fired roaster Dryer - rotary Dryer - spray Dryer - other Drying tower Extraction - mechanical Extraction - solvent Fermentation Grinding Indirect fired kiln Indirect fired roaster Kiln - direct fired
1010 1012 1013 1024 1036 1025 1035 1030 1031 1015 1008 1011 1016 1017 1018 1019 1032 1020 1034 1033 1021 1999
Kiln - indirect fired Liquor aging Meat smoker Milling Mixing/blending Oven baking Packaging Pressing - extraction Pressing - other Prilling Roaster - direct fired Roaster - indirect fired Rotary dryer Screening Shipping & receiving Spray dryer Sterilization - food/pharmaceutical products Stoning/cooling Storage Sulfuring - fruit/food stuff Transferring/conveying Other/not specified
10/08
TABLE G-3
METALLURGICAL (SECONDARY METALS) DRYING (Kilns/Dryers/Ovens) 3002 3003 3004 3005
Calcining kiln Concentrate dryer Oxide kiln Other/not specified
FURNACES 3030 3007 3008 3009 3010 3011 3012 3013 3014 3015 3016 3017 3018 3019 3020 3059 3022 3021 3023 3024 3025 3026 3027
Bake furnace Blast furnace Casting furnace Crucible furnace Cupola Cupola furnace Electric arc furnace Flux furnace Heat treating furnace Horizontal muffle furnace Induction furnace Open hearth furnace Open hearth furnace w/ oxygen lance Pot furnace Retort furnace Reverberatory - rotary Reverberatory - sweat Reverberatory - other Rotary furnace - non-reverberatory Smelt-crucible furnace Smelt-reverberatory furnace Sweating furnace Other/not specified
MATERIAL HANDLING/MISCELLANEOUS 3062 3078 3029 3065 3063 3069 3031 3046 3033 3062 3034 3076 3068 3035 3036 3037
Abrasives blasting Alodyning Annealing Annealing - continuous Anodizing Buffing/polishing Can making operations Casting - miscellaneous Chlorination station Cleaning - abrasives blasting Cleaning - chemical Conveying Crushing/shredding Drawing Drilling Extruding
3047 3039 3038 3040 3041 3042 3043 3044 3045 3067 3061 3046 3047 3048 3064 3049 3072 3050 3051 3070 3080 3079 3071 3081 3052 3073 3053 3054 3055 3056 3077 3060 3075 3057 3074 3066 3999
Fabricating - miscellaneous Finishing - soak pit Finishing - other/not specified Foil converting Foil rolling Galvanizing Grinding Honing Lead oxide manufacturing Machine shop operations Milling/turning Miscellaneous casting Miscellaneous fabricating Mixing Non-destructive coating Paste mixer (lead batteries) Pickling Pitch treating (furnace electrode mfg) Plating (not chrome) Plating dec chrome-hexavalent <=500,000 amphr Plating dec chrome-hexavalent >500,000 amphr Plating dec chrome-trivalent Plating hard chrome-hexavalent Plasma metal application (thermal spraying) Reaming Refining Rolling Sand handling Sanding Sawing Screening Sintering Soldering Storage Ventilation Welding Other/not specified
10/08
TABLE G-4
MINERAL PROCESSES DRYING (Kilns/Dryers/Ovens) 4002 4082 4003 4004 4005 4006 4070 4007 4008
Calcimatic kiln Cement calcining kiln Coke dryer Curing oven Fluidized bed kiln Rotary dryer Rotary kiln Vertical kiln Other/not specified
FURNACES 4010 4012 4011 4013 4014 4015 4071 4016 4072 4017
Cupola Electric furnace Electric induction furnace Reverberatory furnace - other Reverberatory furnace - recupex Reverberatory furnace - regenex Rotary - non-reverberatory Soda lime genl furnace (glass manufacturing) Vertical furnace - other Other/not specified
MATERIAL HANDLING/MISCELLANEOUS 4073 4019 4020 4077 4078 4021 4022 4073 4023 4024 4075 4025 4026 4027 4028 4029 4030 4031 4032 4033 4034 4035
Abrasives blasting Asphalt blowing Asphalt dipping Asphalt mixing - batch/continuous Asphalt mixing - rotary drum Asphalt spraying Bagging Blasting - abrasives cleaning Blasting - quarry Blow chamber Calcining Coal cleaning - therm/flash Coal cleaning - therm/fluid bed Coal cleaning - therm/multi low pd Concrete batching - asbestos/cement products Concrete batching - other Conveying Cooling Crushing Drying (open air) Electric arc melting Fiberizing
4036 4037 4074 4038 4039 4040 4041 4042 4043 4044 4045 4046 4079 4080 4047 4048 4053 4054 4069 4061 4049 4050 4051 4052 4055 4056 4057 4058 4059 4060 4062 4068 4081 4063 4073 4064 4065 4066 4067 4076 4037 4099
Forming line (fiberglass manufacturing) Furnace room venting Glass enamel spraying Glass manufacturing - batching Glass manufacturing - material receiving Glass manufacturing - material storage Glass manufacturing - mixing Glass manufacturing - molten holding tanks Glass manufacturing - other/not specified Grinding Hold/shakeout Hydrator Loading - feed/surge/weigh bins Loading/unloading (non-mining/quarry) Milling Mining/quarry - cobbing Mining/quarry - crushing (primary) Mining/quarry - crushing (secondary) Mining/quarry - crushing (tertiary) Mining/quarry - loading/unloading Mining/quarry - open pit blasting Mining/quarry - open pit cobbing Mining/quarry - open pit drilling Mining/quarry - ore concentrating Mining/quarry - stockpiling Mining/quarry - stripping Mining/quarry - surface blasting Mining/quarry - surface drilling Mining/quarry - tailing piles Mining/quarry - tailings Mining/quarry - ventilating Mining/quarry - other Mixing operations Road surfacing Sand blasting Screening Sintering Stone cutting Storage - contained Storage - open Venting - furnace room Other/not specified
10/08
TABLE G-5
PETROLEUM REFINING PROCESSES CODE 5040 5030 5001 5002 5003 5004 5023 5038 5025 5005 5005 5005 5018 5027 5032 5028 5034 5007 5008 5009 5010 5011 5021 5026 5026 5026 5022 5031 5039 5017 5017 5024 5012 5012 5013 5013 5017 5017 5014 5029 5037 5035 5019 5020 5032 5015 5016 5033 5036 5993 5994 5995 5997 5998 5999
PROCESS Air Stripping/DAF processing Alkylation Asphalt oxidizer Blow-down system - w/ controls Blow-down system - w/o controls Catalytic reforming Chemical treating - other Coke storage piles (open) Converting - other/not specified Cooling tower Cooling tower Cooling tower Delayed coking Distillation - crude Distillation - vacuum Distillation - other Flexicoking Fluid cat cracker Fluid coking - cooling Fluid coking - general Fluid coking - storage Fluid coking - transportation Hydrocracking Hydrogen manufacturing Hydrogen manufacturing Hydrogen manufacturing Hydrotreating/hydrofining Isomerization Marine loading/unloading berths Oil-water separator Oil-water separator Polymerization Process drain - w/controls Process drain - w/controls Process drain - w/o controls Process drain - w/o controls Separator - oil/water Separator - oil/water Sludge converter Solvent extraction Sour water stripping Sulfur removal - other/caustic Thermal cracking Thermal processing - other Vacuum distillation Vacuum jet - w/ controls Vacuum jet - w/o controls Wastewater storage - ponds Wastewater storage - tanks Other/not specified Other/not specified Other/not specified Other/not specified Other/not specified Other/not specified
CODE 300 195 30 340 340 342 239 80 239 428 415 300 343 89 339 239 346 344 345 346 345 345 239 50 52 188 239 52 80 300 427 195 442 300 442 300 300 427 347 *** 442 238 446 446 339 339 339 300 300 80 89 239 339 338 321
MATERIAL Waste Water Hydrocarbons - olefinic Asphalt Crude oil * Crude oil * Cat reformer fresh feed Feedstock Coke Feedstock Water - brackish/sea Water - fresh Waste Water Delayed coke product Crude oil Vacuum distillation feed Feedstock Coker fresh feed FCC fresh feed Fluid coke product Coker fresh feed Fluid coke product Fluid coke product Feedstock C1-C2 paraffins C3+ paraffins Naphtha Feedstock C3+ paraffins Coke Waste water Process water Hydrocarbons - olefinic Waste water - sour Waste water Waste water - sour Waste water Waste water Process water Sludge (use specific Materials Code) Waste water - sour Refinery fuel gas Thermal cracker fresh feed Thermal cracker fresh feed Vacuum distillation feed Vacuum distillation feed Vacuum distillation feed Waste water Waste water Coke Crude oil Feedstock Vacuum distillation feed Waste gases Other petroleum products
USAGE UNITS 1000 barrels 1000 barrels feed tons processed 1000 bbl/day ref cap 1000 bbl/day ref cap 1000 barrels fresh feed 1000 barrels tons 1000 barrels 1000 gallons 1000 gallons 1000 barrels tons produced 1000 barrels 1000 barrels 1000 barrels 1000 barrels fresh feed 1000 barrels fresh feed tons produced 1000 barrels fresh feed tons produced tons produced 1000 barrels million cubic feet 1000 barrels feed 1000 barrels feed 1000 barrels 1000 barrels feed tons 1000 barrels 1000 gallons 1000 barrels feed 1000 barrels 1000 barrels 1000 barrels 1000 barrels 1000 barrels 1000 gallons tons produced 1000 barrels million cubic feet 1000 barrels feed 1000 barrels feed 1000 barrels 1000 barrels 1000 barrels 1000 gallons 1000 gallons tons 1000 barrels 1000 barrels feed 1000 barrels million cubic feet 1000 gallons
NOTE: Each process listed in Table G-5 has a specific material associated with it for use on the G-Form. *Code 340 for crude oil for these processes must be used; emissions are dependent on total refinery capacity rather than on throughput. Use code 89 for crude oil in any other process.
10/08
TABLE G-7
CHEMICAL PROCESSES 7019
7020 7016 7018 7131 7021 7022 7023 7096 7024 7030 7132 7031 7032 7998 7173 7073 7055 7056 7057 7033 7155 7156 7034 7035 7114 7036 7151 7037 7133 7038 7039 7023 7110 7040 7041 7042 7152 7158 7044 7046 7130 7148 7043 7144 7145 7159 7132 7053 7054 7055 7056 7057 7097 7062 7051 7052 7063 7064 7131
Air blow ml brine Ammoniating Ammonium sulfate mfg - NH3/H2SO4 proc Ammonium sulfate mfg - coke oven byprdcts Biological oxidation Bodying oil Boiling tub Brine evaporation Calcining - rotary kiln Calcining - other Carbon black manufacturing - other process Carbon dioxide liquifaction plant Carpet operation Caulking Chemical reaction - other/not specified Chemical reactor – greater than 1000 gallons Chemical reactor - other/not specified Claus - modified 2 stage Claus - modified 3 stage Claus - modified 4 stage Condensing Contaminated ground water stripping Contaminated soil remediation Cooking Creosote pressure treating Crystallizing Cyclohex - general Dipping/cleaning tank Distillation Etching Ethylene dichloride mfg - direct chlorination Ethylene dichloride mfg - oxychlorination Evaporation - brine Evaporation - other Fabrics manufacturing - bleaching Fabrics manufacturing - yarn prep Fabrics manufacturing - other/not specified Feed/holding tank Gas collection system Gas purging Gypsum pond Hydrochloric acid manufacturing Hydrochloric acid regeneration Injection – NOx control system Laboratory Landfill with gas collection system Landfill without gas collection system Liquifaction - CO2 plant Liquifaction - diaphragm Liquifaction - merc cell Mod-Claus 2 stage Mod-Claus 3 stage Mod-Claus 4 stage Neutralizing Nitration reactors Nitric acid - paraxylen gen Nitric acid concentrators Nitric acid mfg - ammonia oxid new Nitric acid mfg - ammonia oxid old Oxidation, biological
7065 7066 7147 7154 7067 7068 7153 7071 7072 7073 7074 7075 7076 7077 7078 7080 7081 7160 7103 7098 7290 7270 7230 7210 7220 7300 7250 7240 7280 7260 7200 7058 7059 7060 7061 7146 7089 7082 7083 7084 7085 7086 7087 7088 7090 7091 7092 7093 7094 7095 7047 7048 7050 7049 7157 7073 7998 7999
Phosphoric acid manufacturing - thermal Phosphoric acid manufacturing - wet process Phosphoric acid manufacturing - other Photographic equipment Pressure treating - other Prilling Process tank Pulpboard manufacturing Pyrolysis Reactor - other/not specified Regenerator Rubberized fabric mfg - hot melt coating Rubberized fabric mfg - impregnation Rubberized fabric mfg - wet coating Rubberized fabric mfg - other/not spec Scrubber Seelite exhaust Separating – DAF processing Separating - oil/water Separating - other Sewage - Digesters Sewage - Disinfection Sewage - Flow equalization Sewage - Preliminary treatment Sewage - Primary treatment Sewage - Reclamation Sewage - Secondary clarifiers Sewage - Secondary treatment Sewage - Sludge handling processes Sewage - Tertiary treatment Sewage - Wastewater treatment plant Sodium carbonate Solvay - NH3 recovery Sodium carbonate Solvay - handling Sodium carbonate Trona - calcining Sodium carbonate Trona - dryer Sterilization - medical equipment Sulfate pulping - other/not specified Sulfate pulping - blow tank accumulator Sulfate pulping - fluidbed calciner Sulfate pulping - liquor oxidation tower Sulfate pulping - mult-effect evaporation Sulfate pulping - smelt dissolv tank Sulfate pulping - turpentine condenser Sulfate pulping - washer/screen Sulfite pulping - digester Sulfite pulping - evaporator Sulfite pulping - liquor recovery Sulfite pulping - pulp digester Sulfite pulping - smelt tank Sulfite pulping - other/not specified Sulfuric acid mfg - chamber process Sulfuric acid mfg - contact process Sulfuric acid mfg - other/not specified Sulfuric acid regenerators Tank/drum/container cleaning Other chemical - reactor Other chemical reaction - other/not spec Other process/not specified
10/08
TABLE G-8
MISCELLANEOUS PROCESSES DRYING (Dehydration/Kilns/Dryers/Ovens) 7006 7002 7003 7004 7005
Natural gas dehydrating Pigment drying Spray drying Veneer drying Drying - other/not specified
MATERIAL HANDLING 7116 8007 7007 7045 7008 7009 7010 7108 7011 7115 7017 7012 7014 7013
Bagging/packaging Coke storage pile Drying Granulating Grinding Loading - storage tank Loading - tank car Milling Mixing Pelletizing Pumping facility - organic liquids Sanding Storage Material handling - other/not spec
MISCELLANEOUS 7109 7109 8001 8010
Abrasives blasting Cleaning - abrasives blasting Coating operation - powder, other nonsolvent Conveying
7164 7165 7166 7105 7104 7106 8011 8003 8004 7045 7143 7143 7170 8005 7111 7112 7113 8002 8006 7109 7079 8008 8009 8012 7161 7143 7107 8999
Composting - windows Composting - aerated static piles Composting - in-vessel Cooling - pond Cooling - tower Cooling - other Crematory retort Expanders - plastics, other Extruders - plastics, other Granulating Insulation stripping - wire Laser-stripping - wire insulation Latex dipping Material working equipment - plastics, other Molding/curing - plastics Molding/curing - rubber Molding/curing - other/not specified Oven Paper/paperboard handling equipment Sand blasting Sawmill operation Screening/Separating Shredding/Mangling/Cutting Waste material grinding Wastewater – industrial storage ponds Wire insulation stripping - laser Woodworking - other/not specified Other process - not specified
TABLE G-9 FUGITIVE EMISSION SOURCES FUGITIVE EMISSIONS 9000 9010 9070 9080 9040 9060 9030 9050
Combined fugitive emission sources Refinery flaring/blowdown Refinery pressure relief valves Refinery process drains Refinery process vessels Refinery pumps/compressors Refinery vacuum products Refinery valves/flanges
10/08
BAY AREA AIR QUALITY MANAGEMENT DISTRICT
Data Form C
939 Ellis Street . . . San Francisco, CA 94109. . . (415) 749-4990 . . . fax (415) 749-5030 FUEL COMBUSTION SOURCE Website: www.baaqmd.gov (for District use only)
New Modified Retro Form C is for all operations which burn fuel except for internal combustion engines (use Form ICE unless it is a gas turbine; for gas turbines use this form). If the operation also involves evaporation of any organic solvent, complete Form S and attach to this form. If the operation involves a process which generates any other air pollutants, complete Form G and attach to this form. Check box if this source has a secondary function as an abatement device for some other source(s); complete lines 1, 2, and 7-13 on Form A (using the source number below for the Abatement Device No.) and attach to this form. (If unknown, leave blank)
1. Company Name:
Phillips 66 (formerly "Conoco Phillips")
2. Equipment Name & Number, or Description:
Plant No:
16
Source No.
Refinery fuel gas or Natural gas fired boiler - 140 MMBtu/hr
3. Make, Model :
Maximum firing rate: 140 MM
4. Date of modification or initial operation: 5. Primary use (check one): 6. SIC Number 2911
Btu/hr
(if unknown, leave blank)
electrical generation space heat abatement device cogeneration process heat; material heated Refinery Fuel Gas __ __
S-New
waste disposal resource recovery
testing other
_
__
If unknown leave blank
7. Equipment type (check one) Use Form ICE (Internal Combustion Engine) unless it is a gas turbine
Internal combustion
gas turbine other
hp hp
Incinerator
salvage operation liquid waste
pathological waste other
Others
boiler afterburner flare open burning other _
dryer oven furnace kiln
yes yes yes
no no no
If yes, what percent If yes, what percent Temperature
11. Low NOx burners?
yes
no
Make, Model
24
hours/day
15. Typical % of annual total:
Dec-Feb
% %
°F _
°F
13. Combustion products: Wet gas flowrate 34,636 Typical Oxygen Content dry volume % or 14. Typical Use
Sec
Material dried, baked, or heated: Refinery Fuel Gas
8. Overfire air? 9. Flue gas recirculation? 10. Air preheat? 12. Maximum flame temperature
°F
Temperature Residence time
acfm at 300 °F wet volume % or
7
days/week
25%
Mar-May
% excess air 52
25%
weeks/year
Jun-Aug
25%
Sep-Nov
16. With regard to air pollutant flow, what source(s) or abatement device(s) are immediately UPSTREAM? S S S S S S A A
25%
A
With regard to air pollutant flow, what source(s) or abatement device(s), and/or emission points are immediately DOWNSTREAM? S S A New A P P Person completing this form: (revised 5/11)
Brent Eastep
Date:
2-5-2013
FUELS INSTRUCTIONS: Complete one line in Section A for each fuel. Section B is OPTIONAL. Please use the units at the bottom of each table. N/A means "Not Applicable." SECTION A: FUEL DATA
Fuel Name 1. 2. 3. 4. 5.
Fuel Code**
Natural gas Refinery fuel gas
12264000
189 238
915224
Natural Gas Other Gas Liquid Solid
Use the appropriate units for each fuel
Total Annual Usage***
Maximum Possible Fuel Use Rate 140,000,000 104.5
therm* MSCF* m gal* ton
Typical Heat Content
Sulfur Content
1.34 x 10ˆ6
100 ppmv TRS
Btu/hr MSCF/hr m gal/hr ton/hr
N/A Btu/MSCF Btu/m gal Btu/ton
N/A ppm wt% wt%
Nitrogen Content (optional)
N/A N/A wt% wt%
Ash Content (optional)
N/A N/A wt% wt%
SECTION B: EMISSION FACTORS (optional) Fuel Name 1. 2. 3. 4.
Fuel Code**
Particulates Emission **Basis Factor Code
NOx Emission **Basis Factor Code
CO Emission **Basis Factor Code
See Appendix A
Use the appropriate units for each fuel: Natural Gas Other Gas Liquid Solid
= = = =
lb/therm* lb/MSCF* lb/m gal* lb/ton
------------------------------------------Note:
* * * ** ***
MSCF = thousand standard cubic feet m gal = thousand gallons therm = 100,000 BTU See tables below for Fuel and Basis Codes Total annual usage is: – Projected usage over next 12 months if equipment is new or modified. – Actual usage for last 12 months if equipment is existing and unchanged. **Fuel Codes
Code
Fuel
Code
25 33 35 43 47 242 80 89 98 493 315 392 551 158 160 165 167 494
Anthracite coal Bagasse Bark Bituminous coal Brown coal Bunker C fuel oil Coke Crude oil Diesel oil Digester gas Distillate oil Fuel oil #2 Gasoline Jet fuel LPG Lignite Liquid waste Municipal solid waste
189 234 235 236 238 237 242 495 511 256 466 304 305 198 200 203
(revised: 6/01)
**Basis Codes Fuel Natural Gas Process gas - blast furnace Process gas - CO Process gas - coke oven gas Process gas - RMG Process gas - other Residual oil Refuse derived fuel Landfill gas Solid propellant Solid waste Wood - hogged Wood - other Other - gaseous fuels Other - liquid fuels Other - solid fuels
Code 0 1 2 3 4 5 6 7 8
Method Not applicable for this pollutant Source testing or other measurement by plant (attach copy) Source testing or other measurement by BAAQMD (give date) Specifications from vendor (attach copy) Material balance by plant using engineering expertise and knowledge of process Material balance by BAAQMD Taken from AP-42 (compilation of Air Pollutant Emission Factors, EPA) Taken from literature, other than AP-42 (attach copy) Guess
Data Form A ABATEMENT DEVICE
BAY AREA AIR QUALITY MANAGEMENT DISTRICT 939 Ellis Street . . . San Francisco, CA 94109. . . (415) 749-4990 . . . F AX (415) 749-5030
for office use only
Abatement Device: Equipment/process whose primary purpose is to reduce the quantity of pollutant(s) emitted to the atmosphere. 1. Business Name:
Phillips 66 (formerly "Conoco Phillips")
2. Name or Description
Plant No:
Selective Catalytic Reduction (SCR)
3. Make, Model, and Rated Capacity
16
(If unknown, leave blank)
Abatement Device No:
A- New
SCR for propane recovery unit boiler
4. Abatement Device Code (See table*)
66
Date of Initial Operation
5. With regard to air pollutant flow into this abatement device, what sources(s) and/or abatement device(s) are immediately upstream?
S-
New
S-
S-
S-
S-
S-
A-
A-
A-
A-
6. Typical gas stream temperature at inlet:
300
A-
°F
If this form is being submitted as part of an application for an Authority to Construct, completion of the following table is mandatory. If not, and the Abatement Device is already in operation, completion of the table is requested but not required. Weight Percent Reduction (at typical operation)
Pollutant
Basis Codes (See Table**)
7.
Particulate
6
8.
Organics
6
9.
Nitrogen Oxides (as NO2)
BACT – 5 ppmvd @ 3% O 2 , 3-hr avg.
3
10.
Sulfur Dioxide
11.
Carbon Monoxide
BACT – 10 ppmvd @ 3% O 2 , 3-hr avg.
3
12.
Other: Ammonia
BACT – 15 ppmvd @ 3% O 2 , 3-hr avg.
3
13.
Other:
14.
6
Check box if this Abatement Device burns fuel; complete lines 1, 2 and 15-36 on Form C (using the Abatement Device No. above for the Source No.) and attach to this form.
15. With regard to air pollutant flow from this abatement device, what sources(s), abatement device(s) and/or emission point(s) are immediately downstream?
S-
A-
Person completing this form: P:www\FormA (revised: 7/99)
A-
Brent Eastep
A-
P-
Date:
New
2/5/2013
P-
*ABATEMENT DEVICE CODES Code
1 2 3 4 5 6
68 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 69 70 71 72 29 30 31 32 33 34 35 66 (revised: 8/08)
DEVICE
ADSORBER (See Vapor Recovery) AFTERBURNER
CO Boiler Catalytic Direct Flame Flare Furnace-firebox Other BAGHOUSE (See Dry Filter) CYCLONE (See Dry Inertial Collector and Scrubber)
DUST CONTROL Water Spray
DRY FILTER
Absolute Baghouse, Pulse Jet Baghouse, Reverse Air Baghouse, Reverse Jet Baghouse, Shaking Baghouse, Simple Baghouse, Other Envelope Moving Belt Other
DRY INERTIAL COLLECTOR
Cyclone, Dynamic Cyclone, Multiple (12 inches dia. or more) Cyclone, Multiple (less than 12 inches dia.) Cyclone, Simple Settling Chamber, Baffled/Louvered Settling Chamber, Simple Other
ELECTROSTATIC PRECIPITATOR Single Stage Single Stage, Wet Two Stage Two Stage, Wet Other INCINERATOR (See Afterburner)
INTERNAL COMBUSTION ENGINE CONTROL Catalyzed Diesel Particulate Filter Non-Cat. Diesel Part. Filter w/ Active Regeneration Diesel Oxidation Catalyst Oxidation Catalyst KNOCK-OUT POT (See Liquid Separator)
LIQUID SEPARATOR
Knock-out Pot Mist Eliminator, Horizontal Pad, Dry Mist Eliminator, Panel, Dry Mist Eliminator, Spray/Irrigated Mist Eliminator, Vertical Tube, Dry Mist Eliminator, Other Other
NO X CONTROL
Selective Catalytic Reduction (SCR)
Code 67 73 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 61 62 63 64 74 65
DEVICE Non-Selective Catalytic Reduction (NSCR) Selective Non-Catalytic Reduction (SNCR)
SCRUBBER
Baffle and Secondary Flow Centrifugal Cyclone, Irrigated Fibrous Packed Impingement Plate Impingement and Entrainment Mechanically Aided Moving Bed Packed Bed Preformed Spray Venturi Other SETTLING CHAMBER (See Dry Inertial Collector)
SULFUR DIOXIDE CONTROL
Absorption and Regeneration, for Sulfur Plant Claus Solution Reaction, for Sulfur Plant Dual Absorption, for H2S04 Plant Flue Gas Desulfurization, for Fossil Fuel Combustion Reduction and Solution Regeneration, for Sulfur Plant Reduction and Stretford Process, for Sulfur Plant Sodium Sulfite-Bisulfite Scrubber, for H2S04 Plant Other
VAPOR RECOVERY
Adsorption, Activated Carbon/Charcoal Adsorption, Silica Adsorption, Other Balance Compression/Condensation/Absorption Compression/Refrigeration Condenser, Water-Cooled Condenser, Other Other
MISCELLANEOUS
Soil Vapor Extraction Abatement System Not classified above **BASIS
Code 0 1 2 3 4 5 6 7 8
CODES
Method Not applicable for this pollutant Source testing or other measurement by plant Source testing or other measurement by BAAQMD Specifications from vendor Material balance by plant using engineering expertise and knowledge of process Material balance by BAAQMD using engineering expertise and knowledge of process Taken from AP-42 ("Compilation of Air Pollutant Emission Factors," EPA) Taken from literature, other than AP-42 Guess
DATA FORM P Emission Point
BAY AREA AIR QUALITY MANAGEMENT DISTRICT 939 Ellis Street .. . San Francisco, CA . . . 94109. . . (415) 749-4990 . . . Fax (415) 749-5030
Form P is for well-defined emission points such as stacks or chimneys only; do not use for windows, room vents, etc.
Business Name:
Plant No:
Phillips 66 (Formerly “ConocoPhillips”)
Emission Point No:
16
P-
New for propane recovery unit boiler
With regard to air pollutant flow into this emission point, what sources(s) and/or abatement device(s) are immediately upstream? S-
S-
S-
A-
S A -
New SCR
Exit cross-section area: 38.5
sq. ft.
S-
S-
A-
A-
Height above grade: 120
A-
ft.
Effluent Flow from Stack Typical Operating Condition Actual Wet Gas Flowrate
34,636
Percent Water Vapor Temperature
cfm
cfm
Vol %
Vol %
°F
300
Maximum Operating Condition
300
If this stack is equipped to measure (monitor) the emission of any air pollutants, Is monitoring continuous?
yes
no
What pollutants are monitored? Person completing this form
P:www\Permit\forms\FormP – 4/99
Brent Eastep
Date 2/5/2013
°F
Form Appendix H BAY AREA AIR Q UALIT Y M ANAG EM ENT DIST RICT
939 Ellis Street . . . San Francisco, CA 94109. . . (415) 749-4990 . . . F AX (415) 749-5030 W ebsite: www.baaqmd.gov
APPENDIX H ENVIRONMENTAL INFORMATION FORM (To Be Completed By Applicant)
Date Filed: 2/6/2013 General Information 1.
Name and address of developer or project sponsor: Phillips 66 (formerly "ConocoPhillips")
2.
Address of project: 1380 San Pablo Avenue, Rodeo, CA, 94572-1299 Assessor’s Block and Lot Number:
3.
Name, address, and telephone number of person to be contacted concerning this project: Brent Eastep, 1380 San Pablo Avenue, Rodeo, CA, 94572-1299. Tel - ( 510 ) 245-4672
4.
Indicate number of the permit application for the project to which this form pertains:
5.
List and describe any other related permits and other public approvals required for this project, including those required by city, regional, state, and federal agencies: Contra Costa County Land Use Permit
6.
Existing zoning district: Heavy Industrial
7.
Proposed use of site (Project for which this form is filed): Propane recovery project at existing refinery
Project Description 8. Site size. 9.
Square footage.
10.
Number of floors of construction.
11.
Amount of off-street parking provided.
12.
Attach plans.
13.
Proposed scheduling.
14.
Associated project.
15.
Anticipated incremental development.
H:pub_data/forms/appenxh.doc 9/99
16.
If residential, include the number of units, schedule of unit sizes, range of sale prices or rents, and type of household size expected.
17.
If commercial, indicate the type, whether neighborhood, city or regionally oriented, square footage of sales area, and loading facilities.
18.
If industrial, indicate type, estimated employment per shift, and loading facilities
19.
If institutional, indicate the major function, estimated employment per shift, estimated occupancy, loading facilities, and community benefits to be derived from the project.
20.
If the project involves a variance, conditional use or rezoning application, state this and indicate clearly why the application is required.
Are the following items applicable to the project or its effects? Discuss below all items checked yes. Attach additional sheets as necessary. Yes 21. Change in existing features of any bays, tidelands, beaches, or hills, or substantial alteration of ground contours. 22. Change in scenic views or vistas from existing residential areas or public lands or roads. 23. Change in pattern, scale or character of general area of project. 24. Significant amounts of solid waste or litter. 25. Change in dust, ash, smoke, fumes or odors in vicinity. 26. Change in ocean, bay, lake, stream or groundwater quality or quantity, or alteration of existing drainage patterns. 27. Substantial change in existing noise or vibration levels in the vicinity. 28. Site on filled land or on slope of 10 percent or more. 29. Use of disposal of potentially hazardous materials, such as toxic substances, flammables or explosives. 30. Substantial change in demand for municipal services (police, fire, water, sewage, etc.). 31. Substantially increase fossil fuel consumption (electricity, oil, natural gas, etc.). 32. Relationship to a larger project or series of projects.
2
No
Environmental Setting 33.
Describe the project site as is exists before the project, including information on topography, soil stability, plants and animals, and any cultural, historical or scenic aspects. Describe any existing structures on the site, and the use of the structures. Attach photographs of the site. Snapshots or Polaroid photos will be accepted.
34.
Describe the surrounding properties, including information on plants and animals and any cultural, historical or scenic aspects. Indicate the type of land use (residential, commercial, etc.), intensity of land use (one-family, apartment houses, shops, department stores, etc.), and scale of development (height, frontage, set-back, rear yard, etc.). Attach photographs of the vicinity. Snapshots or Polaroid photos will be accepted.
Certification I hereby certify that the statements furnished above and in the attached exhibits present the data and information required for this initial evaluation to the best of my ability, and that the facts, statements, and information presented are true and correct to the best of my knowledge and belief.
Date
Signature
For
(Note: This is only a suggested form. Public agencies are free to devise their own format for initial studies.)
3
Attachment B-2 Title V Permit Revision Forms
Engineering Division Bay Area Air Quality Management District 939 Ellis Street, San Francisco, CA 94109 • 749-4990
FACILITY NAME:
Major Facility Review Certification Statement
FACILITY #:
Phillips 66 Rodeo Refinery
16
STATEMENT OF COMPLIANCE: I certify the following: Read each statement carefully and initial each box for confirmation. Based on information and belief formed after reasonable inquiry, the source(s) identified in the Applicable Requirements and Compliance Summary form that is(are) in compliance will continue to comply with the applicable requirement(s); Based on information and belief formed after reasonable inquiry, the source(s) identified in the Applicable Requirements and Compliance Summary form will comply with future-effective applicable requirement(s), on a timely basis; Based on information and belief formed after reasonable inquiry, information on application forms, all accompanying reports, and other required certifications is true, accurate, and complete; All fees required by Regulation 3, including Schedule P have been paid.
STATEMENT OF NON-COMPLIANCE Read statement carefully. Initial box for confirmation if statement is true. I certify the following: Based on information and belief formed after reasonable inquiry, the source(s) identified in the Schedule of Compliance application form that is(are) not in compliance with the applicable requirement(s) will comply in accordance with the attached compliance plan schedule. Signature of Responsible Official
Date
Rand Swenson
Name of Responsible Official F:\Title V Forms 2010\mfr_cert_statement.doc 2/5/2013
Stationary Source Summary
Engineering Division Bay Area Air Quality Management District 939 Ellis Street, San Francisco, CA 94109 • 749-4990
Page 1
FACILITY NAME: Phillips 66 Rodeo Refinery
FACILITY ID: 16
♦ DISTRICT USE ONLY ♦ Application #: ___________________________
Application Received: _______________________
Application Filing Fee:_____________________
Application Deemed Complete: _______________
I.
FACILITY IDENTIFICATION 1. Facility Name: Phillips 66 Rodeo Refinery (Formerly "ConocoPhillips San Francisco Refinery) 2. Four digit SIC: 2911
EPA Plant ID:
3. Parent Company (if different than Facility Name): 4. Mailing Address: 1380 San Pablo Avenue, Rodeo, CA, 94572-1299 5. Street Address or Source Location: 1380 San Pablo Avenue, Rodeo, CA, 94572-1299 6. UTM C oordinates (if required): 7. Source Located within 50 miles of the state line:
Yes
No
8. Source Located within 1000 feet of a school:
Yes
No
9. Type of Orginzation:
Corporation
Sole Ownership
Partnership
Utility Company
Government
10. Legal Owner's Name: 11. Owner's Agent name (if any): 12. Responsible Official: Rand Swenson 13. Plant Site Manager/Contact: Brent Eastep
Telephone #: (510) 245-4672
14. Type of Facility: Petroleum Refinery 15. General description of processes/products:
Manufacturing of petroleum fuels – converting crude oil and other
feedstock into gasoline, jet fuel, diesel and fuel gases. Yes No 16. Is a Federal Risk Management Plan pursuant to Section 112(r) required? (If application is submitted after Risk Management Plan due date, attach verification that the plan is registered with the appropriate agency.) F:\Title V Forms 2010\stationary_source_summary_p1.doc
2/5/2013
Stationary Source Summary
Engineering Division Bay Area Air Quality Management District 939 Ellis Street, San Francisco, CA 94109 • 749-4990
Page 2
FACILITY NAME: Phillips 66 Rodeo Refinery
II.
FACILITY ID: 16
TYPE OF PERMIT ACTION CURRENT PERMIT (permit number)
EXPIRATION (date)
A0016
August 30, 2016
Initial Title V Application Permit Renewal Significant Permit Modification Minor Permit Modification Administrative Amendment III. DESCRIPTION OF PERMIT ACTION 1. Does the permit action requested involve:
Temporary Source
Voluntary Emissions Caps
Acid Rain Source
Alternative Operating Scenarios
CEM's
Abatement Devices
Source Subject to MACT Requirements [Section 112] Source Subject to Enhanced Monitoring
2. Is source operating under a Compliance Schedule?
Yes
No
3. For permit modification, provide a general description of the proposed permit modification: New refinery fuel gas
hydrotreatment unit and new propane recovery unit including a refinery fuel gas and natural gas fired boiler at 140 MMBtu/hr heat input, to recover up to an additional 8,000 barrels of propane and butane. New six pressurized LPG storage tanks with a total storage capacity of 15,000 barrels. LPG loading rack with two new rail spurs with the capacity to hold 4 rail cars on each spur
Rand Swenson Signature of Responsible Official
Print Name of Responsible Official
Refinery Manager, Phillips 66 Title of Responsible Official and Company Name
Date: F:\Title V Forms 2010\stationary_source_summary_p2.doc
2/5/2013
Engineering Division
Major Facility Review
Bay Area Air Quality Management District 939 Ellis Street, San Francisco, CA 94109 • 749-4990
Exempt Source List
FACILITY NAME:
Phillips 66 Rodeo Refinery
FACILITY #:
16
LIST OF EQUIPMENT EXEMPT FROM DISTRICT PERMIT REQUIREMENTS In numerical order, list all equipment which is exempt from District permit requirements. Cite relevant Section of Rule 2-1 for basis for exemption. Please note that emissions must be below 5 tons per year of any regulated pollutant for each source. If more space is required, use additional forms. Please type or print legibly. In the "Emissions Report" column, state whether emissions are listed in the detailed Emissions Report.
SOURCE #
(if any)
SOURCE DESCRIPTION (or name)
EMISSIONS REPORTED
BASIS FOR EXEMPTION
(Y/N)
LPG Storage Tanks
2-1-123.3.1
N
LPG Loading Rack
2-1-123.3.1
N
2/6/2013 Page 1 of 1 F:\Projects\0167855 Phillips66 Propane Recovery\BAAQMD Permit Application\Final Appendices 2-5-2013\Appendix B - BAAQMD Forms\B-2 Title V Forms\4. exempt_source_list_word.doc
Appendix C Health Risk Assessment •
Attachment C-1 – BAAQMD HRSA Forms
•
Attachment C-2 – ISCST3 and HARP Modeling Input and Output Files (on CD)
Attachment C-1 BAAQMD HRSA Forms
Form HRSA BAY AREA AIR QUALITY MANAGEMENT DISTRICT
939 Ellis Street . . . San Francisco, CA 94109. . . (415) 749-4990 . . . FAX (415) 749-5030 OR 4949 W EBSITE: WWW .BAAQMD.GOV
Health Risk Screening Analysis IMPORTANT: For any permit application that requires a Health Risk Screening Analysis, fill out one form for each source that emits a Toxic Air Contaminant(s) [or for a group of sources that exhaust through a common stack]. Emissions can be from a discrete point source (with stack) or a source with fugitive emissions (area or volume source). You must provide a plot plan (drawn to scale, if possible) and a local map (aerial photos are recommended), which clearly demonstrate the location of your site, the source(s), property lines, and any surrounding buildings [see attached example]. Label streets, schools, residences, and other businesses. List major dimensions of all buildings surrounding the source in Section C. Plant Name: Phillips 66 Rodeo Refinery (formerly "Conoco Phillips San Francisco Refinery") Plant No.: 16 Source Description: 140 MMBtu/hr refinery fuel gas and natural gas-fired boiler w/ SCR Source No.: S-New
Emission Point No.: P-New
(if known)
_
(if known)
SECTION A (Point Source) 1.
Does the source exhaust at clearly defined emission point; i.e., a stack or exhaust pipe?
YES OR
NO
(If YES continue at #2, If NO, skip to Section B) 2.
Does the stack (or exhaust pipe) stand alone or is it located on the roof of a building?
alone OR
on roof
Important: If stack is on a roof, provide building dimensions on line B1 in Section C. feet OR
3.
What is the height of the stack outlet above ground level? 120
4.
What is the inside diameter of the stack outlet?
5.
What is the direction of the exhaust from the stack outlet?
6.
Is the stack outlet:
7.
What is the exhaust flowrate during normal operation? 34,636
8.
What is the typical temperature of the exhaust gas? 300
open or hinged rain flap OR
inches OR 7
meters? feet OR
horizontal OR
meters
vertical
rain capped (deflects exhaust downward or horizontally) meters3/second
cfm (cubic feet/min) OR
degrees Fahrenheit OR
degrees Celsius
(Skip Section B and Go on to Section C)
SECTION B (Area/Volume Source) This section applies to fugitive emissions that are NOT captured by a collection system nor directly emitted through a stack or other emission point. Volume sources have fugitive emissions generally released within a building or other defined space (e.g., dry cleaner, gasoline station canopy). Area sources are generally flat areas of release (e.g., landfill, quarry). 1.
Is the emission source located within a building?
YES (go to #2) OR
2.
If YES (source inside building), provide building dimensions on line B1 in Section C a. Does the building have a ventilation system that is vented to the outside?
NO (go to #3) YES OR
NO
b. If NO (ventilation), are the building's doors & windows kept open during hours of operation? 3.
YES OR
If NO (source not inside building), provide a description of the source, dimensions, & indicate location on plot plan.
NO
(Go on to Section C)
HRSA-1
SECTION C (Building Dimensions) Provide building dimensions. Use Line B1 only for building with source/stack on the roof or with fugitive emissions inside building. Use Lines B2-B9 for buildings surrounding the source (within 300 feet). Distance and direction are optional if map feet OR meters and/or aerial photo are adequately labeled with locations of buildings. Check one for units: B#
Building name or description
Height
Width
Length
Distance To Source
Direction To Source
n/a
n/a
Building with source:
B1 B2
Provided in AERMOD input file and spreadsheet on compact disk in Appendix C
B3 B4 B5 B6 B7 B8 B9 NOTE: Label buildings by B# on plot plan, map and/or aerial photo. Provide comments below for any details that need additional clarification (e.g., list buildings that are co-occupied by your employees and other workers, residents, students, etc).
(Go on to Section D)
SECTION D (Receptor Locations) NOTE: Indicate on maps or aerial photos the residential and nonresidential areas surrounding your facility. 1.
Indicate the area where the source is located (check one): zoned for residential use
zoned for mixed residential and commercial/industrial use
zoned for commercial and/or industrial use
zoned for agricultural use
2.
Distance from source (stack or building) to nearest facility property line = 1700
feet OR
3.
Distance from source (stack or building) to the property line of the nearest residence = 2300
4.
Describe the nearest nonresidential property (check one):
Industrial/Commercial OR
meters feet OR
meters
Other
NuStar Energy Selby Terminal (East) and Rodeo Sewage Treatment Plant (South-West) 5.
Distance from source (stack or building) to property line of nearest nonresidential site = 2000
6.
Distance from source to property line of nearest school* (or school site) =
feet OR
feet OR
meters
Greater than 1,000 feet
[Note: Helpful website with California Dept. of Education data: www.greatschools.net] *
Provide the names and addresses of all schools that have property line(s) within 1,000 feet of the source: None *K-12 and more than twelve children only
HRSA-101205
HRSA-2
Form HRSA BAY AREA AIR QUALITY MANAGEMENT DISTRICT
939 Ellis Street . . . San Francisco, CA 94109. . . (415) 749-4990 . . . FAX (415) 749-5030 OR 4949 W EBSITE: WWW .BAAQMD.GOV
Health Risk Screening Analysis IMPORTANT: For any permit application that requires a Health Risk Screening Analysis, fill out one form for each source that emits a Toxic Air Contaminant(s) [or for a group of sources that exhaust through a common stack]. Emissions can be from a discrete point source (with stack) or a source with fugitive emissions (area or volume source). You must provide a plot plan (drawn to scale, if possible) and a local map (aerial photos are recommended), which clearly demonstrate the location of your site, the source(s), property lines, and any surrounding buildings [see attached example]. Label streets, schools, residences, and other businesses. List major dimensions of all buildings surrounding the source in Section C. Plant Name: Phillips 66 Rodeo Refinery (formerly "Conoco Phillips San Francisco Refinery") Plant No.: 16 Source Description: Fugitive component leaks
_
Source No.: S-New (Propane Recovery Unit and Hydrotreater) (if known)
Emission Point No.:
(if known)
SECTION A (Point Source) 1.
Does the source exhaust at clearly defined emission point; i.e., a stack or exhaust pipe?
YES OR
NO
(If YES continue at #2, If NO, skip to Section B) 2.
Does the stack (or exhaust pipe) stand alone or is it located on the roof of a building?
alone OR
on roof
Important: If stack is on a roof, provide building dimensions on line B1 in Section C. 3.
What is the height of the stack outlet above ground level?
4.
What is the inside diameter of the stack outlet?
5.
What is the direction of the exhaust from the stack outlet?
6.
Is the stack outlet:
7.
What is the exhaust flowrate during normal operation?
8.
What is the typical temperature of the exhaust gas?
open or hinged rain flap OR
feet OR
inches OR
meters? feet OR
horizontal OR
meters vertical
rain capped (deflects exhaust downward or horizontally) meters3/second
cfm (cubic feet/min) OR degrees Fahrenheit OR
degrees Celsius
(Skip Section B and Go on to Section C)
SECTION B (Area/Volume Source) This section applies to fugitive emissions that are NOT captured by a collection system nor directly emitted through a stack or other emission point. Volume sources have fugitive emissions generally released within a building or other defined space (e.g., dry cleaner, gasoline station canopy). Area sources are generally flat areas of release (e.g., landfill, quarry). 1.
Is the emission source located within a building?
YES (go to #2) OR
2.
If YES (source inside building), provide building dimensions on line B1 in Section C a. Does the building have a ventilation system that is vented to the outside?
NO (go to #3) YES OR
NO
b. If NO (ventilation), are the building's doors & windows kept open during hours of operation? 3.
YES OR
NO
If NO (source not inside building), provide a description of the source, dimensions, & indicate location on plot plan.
Leaks from components such as valves, flanges, pump seals, compressor seals, etc. in the Propane Recovery Unit and Hydrotreatment Unit. Approximate dimensions of the area = 230 ft (East) x 215 ft (North). See plot plan for location
(Go on to Section C)
HRSA-1
SECTION C (Building Dimensions) Provide building dimensions. Use Line B1 only for building with source/stack on the roof or with fugitive emissions inside building. Use Lines B2-B9 for buildings surrounding the source (within 300 feet). Distance and direction are optional if map feet OR meters and/or aerial photo are adequately labeled with locations of buildings. Check one for units: B#
Building name or description
Height
Width
Length
Distance To Source
Direction To Source
n/a
n/a
Building with source:
B1 B2
Provided in AERMOD input file and spreadsheet on compact disk in Appendix C
B3 B4 B5 B6 B7 B8 B9 NOTE: Label buildings by B# on plot plan, map and/or aerial photo. Provide comments below for any details that need additional clarification (e.g., list buildings that are co-occupied by your employees and other workers, residents, students, etc).
(Go on to Section D)
SECTION D (Receptor Locations) NOTE: Indicate on maps or aerial photos the residential and nonresidential areas surrounding your facility. 1.
Indicate the area where the source is located (check one): zoned for residential use
zoned for mixed residential and commercial/industrial use
zoned for commercial and/or industrial use
zoned for agricultural use
2.
Distance from source (stack or building) to nearest facility property line = 1700
feet OR
3.
Distance from source (stack or building) to the property line of the nearest residence = 2000
4.
Describe the nearest nonresidential property (check one):
Industrial/Commercial OR
meters feet OR
meters
Other
NuStar Energy Selby Terminal (East) and Rodeo Sewage Treatment Plant (South-West) 5.
Distance from source (stack or building) to property line of nearest nonresidential site = 2000
6.
Distance from source to property line of nearest school* (or school site) =
feet OR
feet OR
meters
Greater than 1,000 feet
[Note: Helpful website with California Dept. of Education data: www.greatschools.net] *
Provide the names and addresses of all schools that have property line(s) within 1,000 feet of the source: None *K-12 and more than twelve children only
HRSA-101205
HRSA-2
Attachment C-2 ISCST3 and HARP Modeling Input and Output Files (on CD)
Appendix A Air Quality and Greenhouse Gas Emissions Documentation
APPENDIX A.5
Unit B-401 Process Heater Annual Average Baseline Emissions
Phillips 66 Propane Recovery Project Final Environmental Impact Report
November 2013
Baseline Process Heater Unit 240 B‐401 Year 1 Date NOx 07/25/09 428 07/26/09 420 07/27/09 421 07/28/09 418 07/29/09 419 07/30/09 418 07/31/09 425 08/01/09 417 08/02/09 431 08/03/09 433 08/04/09 430 08/05/09 428 08/06/09 430 08/07/09 430 08/08/09 427 08/09/09 418 08/10/09 415 08/11/09 411 08/12/09 402 08/13/09 418 08/14/09 426 08/15/09 408 08/16/09 417 08/17/09 414 08/18/09 404 08/19/09 400 08/20/09 418 08/21/09 419 08/22/09 419 08/23/09 426 08/24/09 430 08/25/09 428 08/26/09 431 08/27/09 440 08/28/09 442 08/29/09 439 08/30/09 430 08/31/09 421 09/01/09 387 09/02/09 387 09/03/09 387 09/04/09 424 09/05/09 426 09/06/09 434 09/07/09 443 09/08/09 505 09/09/09 471 09/10/09 453 09/11/09 436 09/12/09 426
Year 2 Date NOx 07/25/10 348 07/26/10 356 07/27/10 359 07/28/10 351 07/29/10 333 07/30/10 341 07/31/10 362 08/01/10 393 08/02/10 395 08/03/10 411 08/04/10 414 08/05/10 410 08/06/10 374 08/07/10 351 08/08/10 263 08/09/10 343 08/10/10 347 08/11/10 325 08/12/10 311 08/13/10 313 08/14/10 314 08/15/10 314 08/16/10 309 08/17/10 308 08/18/10 318 08/19/10 304 08/20/10 306 08/21/10 321 08/22/10 322 08/23/10 353 08/24/10 391 08/25/10 373 08/26/10 400 08/27/10 385 08/28/10 379 08/29/10 379 08/30/10 372 08/31/10 363 09/01/10 344 09/02/10 313 09/03/10 302 09/04/10 283 09/05/10 288 09/06/10 285 09/07/10 276 09/08/10 283 09/09/10 297 09/10/10 290 09/11/10 0 09/12/10 0
Year 3 Date NOx 07/25/11 286 07/26/11 271 07/27/11 273 07/28/11 277 07/29/11 282 07/30/11 285 07/31/11 288 08/01/11 289 08/02/11 263 08/03/11 278 08/04/11 281 08/05/11 277 08/06/11 286 08/07/11 289 08/08/11 289 08/09/11 285 08/10/11 281 08/11/11 282 08/12/11 287 08/13/11 289 08/14/11 295 08/15/11 288 08/16/11 292 08/17/11 293 08/18/11 298 08/19/11 302 08/20/11 300 08/21/11 278 08/22/11 278 08/23/11 284 08/24/11 288 08/25/11 276 08/26/11 280 08/27/11 275 08/28/11 282 08/29/11 279 08/30/11 287 08/31/11 286 09/01/11 287 09/02/11 288 09/03/11 289 09/04/11 290 09/05/11 291 09/06/11 292 09/07/11 293 09/08/11 294 09/09/11 295 09/10/11 296 09/11/11 297 09/12/11 298
09/13/09 09/14/09 09/15/09 09/16/09 09/17/09 09/18/09 09/19/09 09/20/09 09/21/09 09/22/09 09/23/09 09/24/09 09/25/09 09/26/09 09/27/09 09/28/09 09/29/09 09/30/09 10/01/09 10/02/09 10/03/09 10/04/09 10/05/09 10/06/09 10/07/09 10/08/09 10/09/09 10/10/09 10/11/09 10/12/09 10/13/09 10/14/09 10/15/09 10/16/09 10/17/09 10/18/09 10/19/09 10/20/09 10/21/09 10/22/09 10/23/09 10/24/09 10/25/09 10/26/09 10/27/09 10/28/09 10/29/09 10/30/09 10/31/09 11/01/09 11/02/09 11/03/09 11/04/09 11/05/09 11/06/09
435 425 405 380 385 396 403 409 407 404 402 384 340 388 328 336 346 346 331 339 373 375 379 381 376 374 375 358 368 387 405 401 374 399 404 422 428 437 429 424 386 320 359 389 446 473 464 441 432 424 422 423 417 391 378
09/13/10 09/14/10 09/15/10 09/16/10 09/17/10 09/18/10 09/19/10 09/20/10 09/21/10 09/22/10 09/23/10 09/24/10 09/25/10 09/26/10 09/27/10 09/28/10 09/29/10 09/30/10 10/01/10 10/02/10 10/03/10 10/04/10 10/05/10 10/06/10 10/07/10 10/08/10 10/09/10 10/10/10 10/11/10 10/12/10 10/13/10 10/14/10 10/15/10 10/16/10 10/17/10 10/18/10 10/19/10 10/20/10 10/21/10 10/22/10 10/23/10 10/24/10 10/25/10 10/26/10 10/27/10 10/28/10 10/29/10 10/30/10 10/31/10 11/01/10 11/02/10 11/03/10 11/04/10 11/05/10 11/06/10
0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0
09/13/11 09/14/11 09/15/11 09/16/11 09/17/11 09/18/11 09/19/11 09/20/11 09/21/11 09/22/11 09/23/11 09/24/11 09/25/11 09/26/11 09/27/11 09/28/11 09/29/11 09/30/11 10/01/11 10/02/11 10/03/11 10/04/11 10/05/11 10/06/11 10/07/11 10/08/11 10/09/11 10/10/11 10/11/11 10/12/11 10/13/11 10/14/11 10/15/11 10/16/11 10/17/11 10/18/11 10/19/11 10/20/11 10/21/11 10/22/11 10/23/11 10/24/11 10/25/11 10/26/11 10/27/11 10/28/11 10/29/11 10/30/11 10/31/11 11/01/11 11/02/11 11/03/11 11/04/11 11/05/11 11/06/11
299 300 301 302 303 304 305 306 307 308 309 310 311 312 313 314 315 316 266 267 274 269 248 252 241 237 234 222 224 229 226 237 245 246 233 79 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0
11/07/09 11/08/09 11/09/09 11/10/09 11/11/09 11/12/09 11/13/09 11/14/09 11/15/09 11/16/09 11/17/09 11/18/09 11/19/09 11/20/09 11/21/09 11/22/09 11/23/09 11/24/09 11/25/09 11/26/09 11/27/09 11/28/09 11/29/09 11/30/09 12/01/09 12/02/09 12/03/09 12/04/09 12/05/09 12/06/09 12/07/09 12/08/09 12/09/09 12/10/09 12/11/09 12/12/09 12/13/09 12/14/09 12/15/09 12/16/09 12/17/09 12/18/09 12/19/09 12/20/09 12/21/09 12/22/09 12/23/09 12/24/09 12/25/09 12/26/09 12/27/09 12/28/09 12/29/09 12/30/09 12/31/09
414 426 426 418 419 391 409 411 446 448 436 470 485 470 479 463 483 488 476 471 482 512 499 482 476 471 482 508 542 543 539 427 345 359 345 371 490 510 512 542 556 560 570 560 539 618 671 661 649 535 503 485 505 470 454
11/07/10 11/08/10 11/09/10 11/10/10 11/11/10 11/12/10 11/13/10 11/14/10 11/15/10 11/16/10 11/17/10 11/18/10 11/19/10 11/20/10 11/21/10 11/22/10 11/23/10 11/24/10 11/25/10 11/26/10 11/27/10 11/28/10 11/29/10 11/30/10 12/01/10 12/02/10 12/03/10 12/04/10 12/05/10 12/06/10 12/07/10 12/08/10 12/09/10 12/10/10 12/11/10 12/12/10 12/13/10 12/14/10 12/15/10 12/16/10 12/17/10 12/18/10 12/19/10 12/20/10 12/21/10 12/22/10 12/23/10 12/24/10 12/25/10 12/26/10 12/27/10 12/28/10 12/29/10 12/30/10 12/31/10
0 0 0 0 0 0 0 0 0 214 348 448 413 437 466 452 456 499 492 479 456 477 481 453 427 419 403 404 394 400 400 363 384 380 398 420 434 400 367 385 352 341 343 356 353 336 361 344 329 336 340 341 366 369 367
11/07/11 11/08/11 11/09/11 11/10/11 11/11/11 11/12/11 11/13/11 11/14/11 11/15/11 11/16/11 11/17/11 11/18/11 11/19/11 11/20/11 11/21/11 11/22/11 11/23/11 11/24/11 11/25/11 11/26/11 11/27/11 11/28/11 11/29/11 11/30/11 12/01/11 12/02/11 12/03/11 12/04/11 12/05/11 12/06/11 12/07/11 12/08/11 12/09/11 12/10/11 12/11/11 12/12/11 12/13/11 12/14/11 12/15/11 12/16/11 12/17/11 12/18/11 12/19/11 12/20/11 12/21/11 12/22/11 12/23/11 12/24/11 12/25/11 12/26/11 12/27/11 12/28/11 12/29/11 12/30/11 12/31/11
0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0
01/01/10 01/02/10 01/03/10 01/04/10 01/05/10 01/06/10 01/07/10 01/08/10 01/09/10 01/10/10 01/11/10 01/12/10 01/13/10 01/14/10 01/15/10 01/16/10 01/17/10 01/18/10 01/19/10 01/20/10 01/21/10 01/22/10 01/23/10 01/24/10 01/25/10 01/26/10 01/27/10 01/28/10 01/29/10 01/30/10 01/31/10 02/01/10 02/02/10 02/03/10 02/04/10 02/05/10 02/06/10 02/07/10 02/08/10 02/09/10 02/10/10 02/11/10 02/12/10 02/13/10 02/14/10 02/15/10 02/16/10 02/17/10 02/18/10 02/19/10 02/20/10 02/21/10 02/22/10 02/23/10 02/24/10
435 441 467 493 494 509 504 505 481 449 419 449 456 480 425 371 370 359 375 385 406 395 378 375 356 355 354 374 350 337 341 332 320 333 351 373 384 401 397 351 347 352 356 369 350 345 360 361 362 359 358 358 372 401 371
01/01/11 01/02/11 01/03/11 01/04/11 01/05/11 01/06/11 01/07/11 01/08/11 01/09/11 01/10/11 01/11/11 01/12/11 01/13/11 01/14/11 01/15/11 01/16/11 01/17/11 01/18/11 01/19/11 01/20/11 01/21/11 01/22/11 01/23/11 01/24/11 01/25/11 01/26/11 01/27/11 01/28/11 01/29/11 01/30/11 01/31/11 02/01/11 02/02/11 02/03/11 02/04/11 02/05/11 02/06/11 02/07/11 02/08/11 02/09/11 02/10/11 02/11/11 02/12/11 02/13/11 02/14/11 02/15/11 02/16/11 02/17/11 02/18/11 02/19/11 02/20/11 02/21/11 02/22/11 02/23/11 02/24/11
385 362 354 355 354 359 372 362 368 357 364 385 353 357 376 420 429 348 318 324 318 330 335 335 343 352 356 364 356 340 305 289 329 331 332 315 404 338 369 371 355 351 356 352 335 341 344 349 352 350 354 166 0 0 0
01/01/12 01/02/12 01/03/12 01/04/12 01/05/12 01/06/12 01/07/12 01/08/12 01/09/12 01/10/12 01/11/12 01/12/12 01/13/12 01/14/12 01/15/12 01/16/12 01/17/12 01/18/12 01/19/12 01/20/12 01/21/12 01/22/12 01/23/12 01/24/12 01/25/12 01/26/12 01/27/12 01/28/12 01/29/12 01/30/12 01/31/12 02/01/12 02/02/12 02/03/12 02/04/12 02/05/12 02/06/12 02/07/12 02/08/12 02/09/12 02/10/12 02/11/12 02/12/12 02/13/12 02/14/12 02/15/12 02/16/12 02/17/12 02/18/12 02/19/12 02/20/12 02/21/12 02/22/12 02/23/12 02/24/12
0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0
02/25/10 02/26/10 02/27/10 02/28/10 03/01/10 03/02/10 03/03/10 03/04/10 03/05/10 03/06/10 03/07/10 03/08/10 03/09/10 03/10/10 03/11/10 03/12/10 03/13/10 03/14/10 03/15/10 03/16/10 03/17/10 03/18/10 03/19/10 03/20/10 03/21/10 03/22/10 03/23/10 03/24/10 03/25/10 03/26/10 03/27/10 03/28/10 03/29/10 03/30/10 03/31/10 04/01/10 04/02/10 04/03/10 04/04/10 04/05/10 04/06/10 04/07/10 04/08/10 04/09/10 04/10/10 04/11/10 04/12/10 04/13/10 04/14/10 04/15/10 04/16/10 04/17/10 04/18/10 04/19/10 04/20/10
353 350 353 362 366 354 368 360 346 350 336 369 416 373 345 322 379 363 393 411 407 411 439 393 382 441 466 456 457 465 462 429 390 372 365 369 362 419 424 408 411 389 329 373 365 362 367 353 366 364 333 319 320 320 319
02/25/11 02/26/11 02/27/11 02/28/11 03/01/11 03/02/11 03/03/11 03/04/11 03/05/11 03/06/11 03/07/11 03/08/11 03/09/11 03/10/11 03/11/11 03/12/11 03/13/11 03/14/11 03/15/11 03/16/11 03/17/11 03/18/11 03/19/11 03/20/11 03/21/11 03/22/11 03/23/11 03/24/11 03/25/11 03/26/11 03/27/11 03/28/11 03/29/11 03/30/11 03/31/11 04/01/11 04/02/11 04/03/11 04/04/11 04/05/11 04/06/11 04/07/11 04/08/11 04/09/11 04/10/11 04/11/11 04/12/11 04/13/11 04/14/11 04/15/11 04/16/11 04/17/11 04/18/11 04/19/11 04/20/11
0 0 0 0 0 0 298 376 438 311 338 331 333 342 354 353 307 320 304 319 326 315 322 317 313 321 311 308 314 312 322 323 313 296 292 290 317 349 334 323 324 353 373 345 378 366 361 382 390 346 319 317 330 331 328
02/25/12 02/26/12 02/27/12 02/28/12 02/29/12 03/01/12 03/02/12 03/03/12 03/04/12 03/05/12 03/06/12 03/07/12 03/08/12 03/09/12 03/10/12 03/11/12 03/12/12 03/13/12 03/14/12 03/15/12 03/16/12 03/17/12 03/18/12 03/19/12 03/20/12 03/21/12 03/22/12 03/23/12 03/24/12 03/25/12 03/26/12 03/27/12 03/28/12 03/29/12 03/30/12 03/31/12 04/01/12 04/02/12 04/03/12 04/04/12 04/05/12 04/06/12 04/07/12 04/08/12 04/09/12 04/10/12 04/11/12 04/12/12 04/13/12 04/14/12 04/15/12 04/16/12 04/17/12 04/18/12 04/19/12
0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0
04/21/10 04/22/10 04/23/10 04/24/10 04/25/10 04/26/10 04/27/10 04/28/10 04/29/10 04/30/10 05/01/10 05/02/10 05/03/10 05/04/10 05/05/10 05/06/10 05/07/10 05/08/10 05/09/10 05/10/10 05/11/10 05/12/10 05/13/10 05/14/10 05/15/10 05/16/10 05/17/10 05/18/10 05/19/10 05/20/10 05/21/10 05/22/10 05/23/10 05/24/10 05/25/10 05/26/10 05/27/10 05/28/10 05/29/10 05/30/10 05/31/10 06/01/10 06/02/10 06/03/10 06/04/10 06/05/10 06/06/10 06/07/10 06/08/10 06/09/10 06/10/10 06/11/10 06/12/10 06/13/10 06/14/10
323 323 315 333 388 387 419 448 369 374 381 378 384 385 373 398 379 350 378 412 438 418 427 428 414 424 379 433 449 423 410 442 445 413 384 392 414 420 405 398 391 390 366 351 332 337 330 344 366 343 342 336 333 343 409
04/21/11 04/22/11 04/23/11 04/24/11 04/25/11 04/26/11 04/27/11 04/28/11 04/29/11 04/30/11 05/01/11 05/02/11 05/03/11 05/04/11 05/05/11 05/06/11 05/07/11 05/08/11 05/09/11 05/10/11 05/11/11 05/12/11 05/13/11 05/14/11 05/15/11 05/16/11 05/17/11 05/18/11 05/19/11 05/20/11 05/21/11 05/22/11 05/23/11 05/24/11 05/25/11 05/26/11 05/27/11 05/28/11 05/29/11 05/30/11 05/31/11 06/01/11 06/02/11 06/03/11 06/04/11 06/05/11 06/06/11 06/07/11 06/08/11 06/09/11 06/10/11 06/11/11 06/12/11 06/13/11 06/14/11
334 344 336 338 344 363 354 355 369 380 367 360 333 349 331 310 302 167 236 307 313 318 314 314 319 316 293 278 264 273 271 276 278 280 266 267 262 273 272 280 272 281 250 236 234 268 258 242 253 248 245 237 230 234 231
04/20/12 04/21/12 04/22/12 04/23/12 04/24/12 04/25/12 04/26/12 04/27/12 04/28/12 04/29/12 04/30/12 05/01/12 05/02/12 05/03/12 05/04/12 05/05/12 05/06/12 05/07/12 05/08/12 05/09/12 05/10/12 05/11/12 05/12/12 05/13/12 05/14/12 05/15/12 05/16/12 05/17/12 05/18/12 05/19/12 05/20/12 05/21/12 05/22/12 05/23/12 05/24/12 05/25/12 05/26/12 05/27/12 05/28/12 05/29/12 05/30/12 05/31/12 06/01/12 06/02/12 06/03/12 06/04/12 06/05/12 06/06/12 06/07/12 06/08/12 06/09/12 06/10/12 06/11/12 06/12/12 06/13/12
0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0
06/15/10 06/16/10 06/17/10 06/18/10 06/19/10 06/20/10 06/21/10 06/22/10 06/23/10 06/24/10 06/25/10 06/26/10 06/27/10 06/28/10 06/29/10 06/30/10 07/01/10 07/02/10 07/03/10 07/04/10 07/05/10 07/06/10 07/07/10 07/08/10 07/09/10 07/10/10 07/11/10 07/12/10 07/13/10 07/14/10 07/15/10 07/16/10 07/17/10 07/18/10 07/19/10 07/20/10 07/21/10 07/22/10 07/23/10 07/24/10 Year 1 total (lbs/year) Year 1 average (lbs/day) Year 1 total (tons/year)
481 06/15/11 391 06/16/11 352 06/17/11 339 06/18/11 336 06/19/11 341 06/20/11 328 06/21/11 303 06/22/11 305 06/23/11 334 06/24/11 330 06/25/11 331 06/26/11 324 06/27/11 304 06/28/11 278 06/29/11 316 06/30/11 339 07/01/11 330 07/02/11 242 07/03/11 333 07/04/11 341 07/05/11 328 07/06/11 353 07/07/11 429 07/08/11 393 07/09/11 417 07/10/11 425 07/11/11 434 07/12/11 384 07/13/11 392 07/14/11 380 07/15/11 375 07/16/11 384 07/17/11 379 07/18/11 388 07/19/11 375 07/20/11 369 07/21/11 360 07/22/11 326 07/23/11 330 07/24/11 147,347 Year 2 total (lbs/year) 404 Year 2 average (lbs/day) 74 Year 2 total (tons/year)
253 06/14/12 263 06/15/12 265 06/16/12 260 06/17/12 253 06/18/12 248 06/19/12 236 06/20/12 229 06/21/12 235 06/22/12 238 06/23/12 247 06/24/12 252 06/25/12 255 06/26/12 245 06/27/12 253 06/28/12 251 06/29/12 246 06/30/12 244 07/01/12 244 07/02/12 256 07/03/12 270 07/04/12 283 07/05/12 290 07/06/12 277 07/07/12 284 07/08/12 279 07/09/12 276 07/10/12 267 07/11/12 267 07/12/12 276 07/13/12 272 07/14/12 272 07/15/12 281 07/16/12 274 07/17/12 279 07/18/12 265 07/19/12 267 07/20/12 274 07/21/12 279 07/22/12 309 07/23/12 95,398 07/24/12 261 Year 3 total (lbs) 48 Year 3 average (lbs/day) Year 3 total (tons/year)
0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 24,073 66 12
Daily emissions are source data obtained from the BAAQMD, 2012.
Bay Area Air Quality Management District (BAAQMD), 2012. Initial Study, Marine Terminal Offload Limit Revision Project, Phillips 66 Refinery, Appendix C, Detailed Project‐Specific Emission Calculations. December 2012.
