DAQ-2024-010103

Appendix A

Site Plan
Building and Stack Information

CVWRF Buidling Dimensions
Name Length, ft Width, ft Wall Height, ft Max Wall Height, ft Roof Shape
Egg Digester Building 74 50 28 104 Parapet with Raised Stairwell
East Digester Building 63 63 16 28 Parapet with Raised Stairwell
Waste Gas Burner Bldg 24 23 8 12 Gable
West Digester Building 77 71 16 28 Parapet with Raised Stairwell
O&M Building 220 82 17 27 Parapet with Raised Roof Section
Maintenance Barn 102 52 14 22 Gable
Truck Barn 109 67 16 27 Gable
Equipment Barn 107 66 16 27 Gable
UV Building 127 34 29 29 Parapet
3W Expansion Tank Building 56 25 19 19 Parapet
3W Building 162 50 26 26 Parapet
West RSS Building 67 45 17 17 Parapet
East RSS Building 80 48 17 17 Parapet
Power Gen Building 215 105 37 49 Parapet with Raised Stairwell
Blower Building 313 105 40 47 Parapet with Raised Stairwell
GBT Building 96 79 27 27 Parapet
Filtrate Building 74 27 17 17 Parapet
Headworks Building 101 99 30 45 Parapet with Raised Roof Section
Admin Building 222 122 20 25 Parapet with Raised Stairwell
Dewatering Building 225 130 24 41 Parapet with Raised Roof Section
Compost Shed 62 53 24 27 Gable
Sidestream N Building 60 52 23 23 Parapet
Sidestream P Building 57 41 19 19 Parapet with Protruding Tanks
O&M Safety Building 22 17 13 13 Parapet
RAS Denite Pump Station 115 101 10 20 Flat with Raised Stairwell and Roof Section
BNR Electrical 73 59 23 23 Parapet
Condensate Building 20 12 12 12 Flat
Maintenance Barn Expansion 50 50 14 22 Gable
Compost MCC 17 17 15 15 Parapet
Compost Sales Shed 7 6 7 8 Gable
East TACO Stand 28 27 14 14 Parapet
West TACO Stand 28 23 14 14 Parapet
Guard Shack 12 8 7 12 Gable
South TACO Stand 21 19 12 12 Parapet
Thickening and Straining Building174 88 27 40 Parapet with Raised Roof Section
Oil Storage Shed 18 12 8 9 Gable
East Tunnel Access Stairway Bldg18 6 11 11 Parapet
West Tunnel Access Stairway Bldg18 6 12 12 Parapet
Pilot Shed 16 11 9 15 Mono Pitch
Stack Information

1
EMISSION UNIT LOCATION /
BUILDING
STACK PARAMETERS: (HEIGHT, DIAMETER,
PLUME, TEMPERATURE, ETC.)
FIGURE REFERENCE
BOILER #1
EQ ID: BLR33140
KBC
Power Genera on
Building Roof
(South)

· Height: 42 FT
· Shape: Circular
· Diameter: 1.7 FT
· Temperature: 400 F
· Flow: 17 SCFS @ max output
· Velocity: 7.5 FPS
· White plume
#1
BOILER #2
EQ ID: BLR33140
BURNHAM
Power Genera on
Building Roof
(North)
· Height: 42 FT
· Shape: Circular
· Diameter: 1.67 FT
· Temperature: 400 F
· Flow: 17 SCFS @ max output
· Velocity: 7.5 FPS
· White plume
#2
JMS ENGINE #1
EQ ID: ENG330001

Power Genera on
Building Roof
(Furthest North)
· Height: 45 FT
· Shape: Circular
· Diameter: 1.67 FT
· Temperature: 340 F
· Flow: 10,000 CFM @ max load
· Velocity: 77 FPS
· Black Plume
#3 (far right of 3)
JMS ENGINE #2
EQ ID: ENG330002
Power Genera on
Building Roof
· Height: 45 FT
· Shape: Circular
· Diameter: 1.67 FT
· Temperature: 340 F
· Flow: 10,000 CFM @ max load
· Velocity: 77 FPS
· Black Plume
#3 (middle of 3)
JMS ENGINE #3
EQ ID: ENG330003
Power Genera on
Building Roof
· Height: 45 FT
· Shape: Circular
· Diameter: 1.67 FT
· Temperature: 340 F
· Flow: 10,000 CFM @ max load
· Velocity: 77 FPS
· Black Plume
#4 (middle of 3)
JMS ENGINE #4
EQ ID: ENG330004

Power Genera on
Building Roof
(Furthest South)
· Height: 45 FT
· Shape: Circular
· Diameter: 1.67 FT
· Temperature: 340 F
· Flow: 10,000 CFM @ max load
· Velocity: 77 FPS
· Black Plume
#4 (far le5 of 3)
STANDBY DIESEL GENERATOR
#2
EQ ID: ENG330009
RSS AREA
North of RSS East Building
(South)
· Height: 11.5 FT
· Shape: Circular
· Diameter: 0.83 FT
· Temperature: 1011 F
· Flow: 5085 CFM @ max load
· Velocity: 156.6 FPS
· Black Plume
#5 (le5 of 2)
STANDBY DIESEL GENERATOR
#3
EQ ID: ENG330011
RSS AREA
North of RSS East Building
(North)
· Height: 11.5 FT
· Shape: Circular
· Diameter: 0.88 FT
· Temperature: 1011 F
· Flow: 5085 CFM @ max load
· Velocity: 139.8 FPS
· Black Plume
#5 (right of 2)
Stack Information

2
EMISSION UNIT LOCATION /
BUILDING
STACK PARAMETERS: (HEIGHT, DIAMETER,
PLUME, TEMPERATURE, ETC.)
FIGURE REFERENCE
STANDBY DIESEL GENERATOR
#4
EQ ID: ENG330010
ADMIN AREA
East of Admin Building · Height: 11 FT
· Shape: Circular
· Diameter: 0.53 FT
· Temperature: 971 F
· Flow: 2160 CFM @ max load
· Velocity: 163.2 FPS
· Black Plume
#6
STANDBY DIESEL GENERATOR
#5
EQ ID: ENG330006
POWER GEN AREA
North of Power
Genera on Building
(West)
· Height: 14.9 FT
· Shape: Circular
· Diameter: 0.56 FT
· Temperature: 797 F
· Flow: 4662 CFM @ max load
· Velocity: 312.7 FPS
· Black Plume
#7 (right of 2)
STANDBY DIESEL GENERATOR
#6
EQ ID: ENG330007
POWER GEN AREA
North of Power
Genera on Building (East)
· Height: 16.2 FT
· Shape: Circular
· Diameter: 0.56 FT
· Temperature: 797 F
· Flow: 4662 CFM @ max load
· Velocity: 315.5 FPS
· Black Plume
#7 (le5 of 2)
STANDBY DIESEL GENERATOR
#7
EQ ID: ENG330012
HEADWORKS AREA
See Site Plan · Height: 17 FT
· Shape: Circular
· Diameter: 1.15 FT
· Temperature: 941 F
· Flow: 9535 CFM @ max load
· Velocity: 153.1 FPS
· Black Plume
#8 (le5 of 2)
STANDBY DIESEL GENERATOR
#8
EQ ID: ENG330013
HEADWORKS AREA
See Site Plan · Height: 17 FT
· Shape: Circular
· Diameter: 1.15 FT
· Temperature: 941 F
· Flow: 9535 CFM @ max load
· Velocity: 153.1 FPS
· Black Plume
#8 (right of 2)
STANDBY DIESEL GENERATOR
#9
EQ ID: DG340133A
BLOWER BUILDING AREA
See Site Plan · Height: 15.75 FT
· Shape: Circular
· Diameter: 1.33 FT
· Temperature: 896 F
· Flow: 16,103 CFM @ max load
· Velocity: 193 FPS
· Black Plume
#9 (far le5 of 3)
STANDBY DIESEL GENERATOR
#10
EQ ID: DG340133B
BLOWER BUILDING AREA
See Site Plan · Height: 15.75 FT
· Shape: Circular
· Diameter: 1.33 FT
· Temperature: 896 F
· Flow: 16,103 CFM @ max load
· Velocity: 193 FPS
· Black Plume
#9 (middle of 3)
STANDBY DIESEL GENERATOR
#11
EQ ID: DG340133C
BLOWER BUILDING AREA
See Site Plan · Height: 15.75 FT
· Shape: Circular
· Diameter: 1.33 FT
· Temperature: 896 F
· Flow: 16,103 CFM @ max load
· Velocity: 193 FPS
· Black Plume
#9 (far right of 3)
Stack Information

3
EMISSION UNIT LOCATION /
BUILDING
STACK PARAMETERS: (HEIGHT, DIAMETER,
PLUME, TEMPERATURE, ETC.)
FIGURE REFERENCE
WASTE GAS FLARE #1
EQ ID: BNR270221 (NORTH)
See Site Plan · Height: 27 FT
· Shape: Circular
· Diameter: 1 FT
· Temperature: N/A
· Flow: N/A
· Velocity: N/A
· Black Plume
#10 (rear of 2)
WASTE GAS FLARE #2
EQ ID: BNR270222
(SOUTH)
See Site Plan · Height: 27 FT
· Shape: Circular
· Diameter: 1 FT
· Temperature: N/A
· Flow: N/A
· Velocity: N/A
· Black Plume
#10 (front of 2)
WASTE OIL HEATER #1
EQ ID: HTR51

Maintenance Barn/Shed
Roof
· Height: 27 FT
· Shape: Circular
· Diameter: 0.65 FT
· Temperature: 198 F
· Flow: 58 CFS
· Velocity: 211 FPS
· Black Plume
#11
WASTE OIL HEATER #2
EQ ID: HTR52

Truck Barn/Shed Roof · Height: 27 FT
· Shape: Circular
· Diameter: 0.65 FT
· Temperature: 198 F
· Flow: 46 CFS
· Velocity: 211 FPS
· Black Plume
#12
WASTE OIL HEATER #3
EQ ID: HTR53

Equipment Barn/Shed
Roof
· Height: 27 FT
· Shape: Circular
· Diameter: 0.65 FT
· Temperature: 198 F
· Flow: 49 CFS
· Velocity: 211FPS
· Black Plume
#13
Stack Information

4

Figure 1. Boiler 1 Exhaust Stack

Figure 2. Boiler 2 Exhaust Stack

Figure 3. Jenbacher Generator 1 thru 3 Exhaust Stacks

Figure 4. Jenbacher Generator 2 thru 4 Exhaust Stacks

Figure 5. RSS Area Standby Generators

Figure 6. Admin Area Standby Generator

Figure 7. Cogen Area Standby Generators
Stack Information

5

Figure 8. Headworks Area Standby Generators

Figure 9. Blower Building Area Standby Generators

Figure 10. Waste Gas Flares

Figure 11. Waste Oil Heater 1 Stack (Maintenance Barn)

Figure 12. Waste Oil Heater 2 Stack (Truck Barn)

Figure 13. Waste Oil Heater 3 Stack (Equipment Barn)
Appendix B

Flow Diagrams
Jenbachers 1-4
Exhaust to
Atmosphere
Exhaust to
Atmosphere
Exhaust to
Atmosphere
Exhaust to
Atmosphere
En
g
i
n
e

E
x
h
a
u
s
t
En
g
i
n
e

E
x
h
a
u
s
t
En
g
i
n
e

E
x
h
a
u
s
t
En
g
i
n
e

E
x
h
a
u
s
t
Digester Gas and Cogen
System Flow Schematic
Exhaust Heat
Recovery (water)
Silencer
Silencer
Silencer
Silencer
Exhaust Heat
Recovery (water)
Exhaust Heat
Recovery (water)
Exhaust Heat
Recovery (water)
~1
0
,
0
0
0

A
C
F
M

@

m
a
x

o
u
t
p
u
t
~1
0
,
0
0
0

A
C
F
M

@

m
a
x

o
u
t
p
u
t
~1
0
,
0
0
0

A
C
F
M

@

m
a
x

o
u
t
p
u
t
~1
0
,
0
0
0

A
C
F
M

@

m
a
x

o
u
t
p
u
t
~14.5 MMBH @ max output
~14.5 MMBH @ max output
~14.5 MMBH @ max output
~14.5 MMBH @ max output
~0.8 MMBH @ max output
~0.8 MMBH @ max output
~0.8 MMBH @ max output
~0.8 MMBH @ max output
0
m
i
n

t
o

1
8

M
M
B
H

m
a
x
An
n
u
a
l

A
v
g

=

0
.
0
7

M
M
B
H
~ 18 MMBH
Annual Avg
Only operating 2 Engines at
any given time, typically at
~85% load.
NG
NG
NG
NG
Natural Gas Boilers Flow
Schematic
Exhaust to
Atmosphere
Exhaust to
Atmosphere
Natural Gas
Heat Recovery
(water)
Natural Gas
Natural Gas Boiler Exhaust
Boiler Exhaust
Boiler 1
Boiler 2
Heat Recovery
(water)
~1
0
0
0

S
C
F
M

@

ma
x

o
u
t
p
u
t
~6 MMBH @ max output
~6 MMBH @ max output
~1
0
0
0

S
C
F
M

@

ma
x

o
u
t
p
u
t
Belly Tank
Diesel Standby/Emergency
Generators Flow Schematic
Standby/Emergency Generator
2
Standby/Emergency Generator
3
Standby/Emergency Generator
5
Standby/Emergency Generator
6
Standby/Emergency Generator
4
Standby/Emergency Generator
7
Standby/Emergency Generator
8
Standby/Emergency Generator
9
Standby/Emergency Generator
10
Standby/Emergency Generator
11
ULS Diesel
ULS Diesel
ULS Diesel
ULS Diesel
ULS Diesel
ULS Diesel
ULS Diesel
ULS Diesel
ULS Diesel
ULS Diesel
RSS/UV Area
~
~
~
~
~
~
~
~
~
~
Admin Building
Power Gen Area
Headworks Area
Blower Building Area
Exhaust to
Atmosphere
Exhaust to
Atmosphere
Exhaust to
Atmosphere
Exhaust to
Atmosphere
Exhaust to
Atmosphere
Belly Tank
Belly Tank
Belly Tank
Belly Tank
Belly Tank
Belly Tank
Belly Tank
Belly Tank
Belly Tank
46 GPH @ Max Load
46 GPH @ Max Load
5085 CFM
@ Max Load
5085 CFM
@ Max Load
2160 CFM
@ Max Load
18 GPH @ Max Load
40 GPH @ Max Load
40 GPH @ Max Load
4662 CFM
@ Max Load
4662 CFM
@ Max Load
ENG330009
ENG330011
ENG330010
ENG330006
ENG330007
ENG330012
ENG330013
DG340133A
DG340133B
DG340133C
73 GPH @ Max Load
73 GPH @ Max Load
147 GPH @ Max Load
9535 CFM
@ Max Load
9535 CFM
@ Max Load
147 GPH @ Max Load
147 GPH @ Max Load
16,103 CFM @ Max Load16,103 CFM @ Max Load
16,103 CFM @ Max Load
Waste Oil Burners Flow Schematic
Waste Oil
Burner
Used Oil Tank
Exhaust to
Atmosphere
Heated Air
Maintenance Barn/Shed
Waste Oil
Burner
Used Oil Tank
Exhaust to
Atmosphere
Heated Air
Truck Barn/Shed
Waste Oil
Burner
Used Oil Tank
Exhaust to
Atmosphere
Heated Air
Equipment Barn/Shed
2.
5

G
P
H

M
a
x
35
0

M
B
H

M
a
x
2
G
P
H

M
a
x
28
0

M
B
H

M
a
x
2.
1

G
P
H

M
a
x
30
0

M
B
H

M
a
x
HTR51
HTR52
HTR53
49 SCFM
58 SCFM
46 SCFM
Appendix C

Process/Equipment Description
Emergency/Standby Diesel Generators
Emergency/Standby Diesel Generators are used a backup power source for critical processes,
equipment, and facilities. They only operate during a power system failure due to an issue with the
cogeneration system or due to outage on the utility power supply. They’re also operate briefly as
needed for maintenance and quarterly emission opacity observations (Method 9). There are
currently 10 standby generators on the site serving 5 areas. Most areas have two standby
generators, while Admin area only has one unit. The three newest standby generators for the Blower
Building area are not yet operational as we’re still awaiting the Approval Order from DAQ.
ENGINE 2 ENGINE 3 ENGINE 4 ENGINE 5 ENGINE 6
EQUIPMENT ID ENG330009 ENG330011 ENG330010 ENG330006 ENG330007
MAKE Caterpillar Caterpillar Caterpillar MTU MTU
MODEL 3412 3412 3306 12V1600 12V1600
SERIAL 166-8590 184-7678 220-5716 95010601350 95010601351
MANUFACTURED Jan 2004 Sep 2000 Jan 2005 2016 2016
STARTUP Jul 2004 Dec 2009 Jul 2005 May 2018 May 2018
FUEL ULS Diesel
FUEL CAPACITY 46 GPH 46 GPH 18 GPH 40 GPH 40 GPH
PRODUCTS Backup Power
RATED
PRODUCTION
896 / 668
H.P. / KW
896 / 668
H.P. / KW
349 / 230
H.P. / KW
800 / 600
H.P. / KW
800 / 600
H.P. / KW
OPERATION Operate only as needed. 100 hr max /yr per unit*
DAILY VAR None. Operate only as needed.
SEASONAL VAR None. Operate only as needed.
*Except in emergency situations.
**See 2023 Inventory in Appendix E for recent annual throughput data.

ENGINE 7 ENGINE 8 ENGINE 9 ENGINE 10 ENGINE 11
EQUIPMENT ID ENG330012 ENG330013 DG340133A DG340133B DG340133C
MAKE MTU MTU MTU MTU MTU
MODEL 16V2000 16V2000 16V4000 16V4000 16V4000
SERIAL 95020500768 95020500756 95030502504 95030502505 95030502506
MANUFACTURED 2015 2015 2023 2023 2023
STARTUP Nov 2019 Nov 2019 est. 2025 est. 2025 est. 2025
FUEL ULS Diesel
FUEL CAPACITY 73 GPH 73 GPH 147 GPH 147 GPH 147 GPH
PRODUCTS Backup Power
RATED
PRODUCTION
1341 / 1000
H.P. / KW
1341 / 1000
H.P. / KW
2680 / 2000
H.P. / KW
2680 / 2000
H.P. / KW
2680 / 2000
H.P. / KW
OPERATION** Operate only as needed. 100 hr max /yr per unit*
DAILY VAR None. Operate only as needed.
SEASONAL VAR None. Operate only as needed.
*Except in emergency situations.
**See 2023 Inventory in Appendix E for recent annual throughput data.

Jenbacher Gas Fired Generators
Jenbacher Gas Fired Generators are RICE units and are the main power and heat source for the
facility. The are normally fueled by a mixture of digester gas (biogas produced on-site) and
purchased natural gas. The power produced is supplemented with some purchased utility power.
The heat produced is captured from the engine and exhaust to be transferred to the heat reservoir
supply water loop which is used to heat processes/buildings throughout the facility. Two engines
run simultaneously under normal operating conditions. It’s anticipated that within the next 5 years
power requirements for new treatment systems will require running three engines under normal
operating conditions.
JMS ENGINE 1 JMS ENGINE 2 JMS ENGINE 3 JMS ENGINE 4
EQUIPMENT ID ENG330001 ENG330002 ENG330003 ENG330004
MAKE GEJenbacher GEJenbacher GEJenbacher GEJenbacher
MODEL JMS 612 GS-F28 JMS 612 GS-F28 JMS 612 GS-F28 JMS 612 GS-F28
SERIAL 1322399 1322416 1322432 1322446
MANUFACTURED 2017 2017 2017 2017
STARTUP Nov 2019 Jul 2020 Jul 2021 Jan 2022
FUEL Digester Gas / Natural Gas
FUEL HEAT
VALUE
600 / 1020 BTU/SCF
FUEL CAPACITY 14.5 MMBH 14.5 MMBH 14.5 MMBH 14.5 MMBH
PRODUCTS Power and Heat
RATED
PRODUCTION
2509 / 1872
H.P. / KW
2509 / 1872
H.P. / KW
2509 / 1872
H.P. / KW
2509 / 1872
H.P. / KW
OPERATION* Two units at about 85% load under normal operating conditions. Expected to
increase to 3 units by 2030.
DAILY VAR Fluctuates from about 75% load at night to 100 % load at peak flow during
the day. Follows diurnal influent flow pattern.
SEASONAL VAR No variation tied to seasons.
*See 2023 Inventory in Appendix E for recent annual throughput data.

Digester Gas Flares
Digester Gas Flares are used as a backup system to burn digester gas (biogas produced on-site) in
the event that it cannot be used for cogeneration of power and heat. The flares are a single system
with 2 (1+1) candlestick burners. The flare system is only used during cogen system outage.
FLARE 1 FLARE 2
EQUIPMENT ID BNR270221 BNR270222
MAKE Shand & Jurs Shand & Jurs
MODEL 97301-493732001 97301-493732001
TYPE Candlestick Candlestick
MANUFACTURED 2017 2017
STARTUP Jul 2021 Jul 2021
SIZE 12-inch 12-inch
WASTE GAS Digester Gas
WASTE GAS HEAT VALUE 600 BTU/SCF
WASTE GAS CAPACITY 218,600 CFH 218,600 CFH
ADDL FUEL (PILOT) Natural Gas
PRODUCTS CO2 Emissions
RATED PRODUCTION N/A
OPERATION* Operate only as needed.
DAILY VAR None. Operate only as needed.
SEASONAL VAR None. Operate only as needed.
*See 2023 Inventory in Appendix E for recent annual throughput data.

Natural Gas Fired Boilers
Natural Gas Fired Boilers are used to provide additional heat to the heat reservoir supply water loop
if needed. There are two (1+1) boilers which can operate simultaneously under extreme heat
demand conditions. The boilers are used primarily during the winter when heat demands are
highest.
BOILER 1 BOILER 2
EQUIPMENT ID BLR33140 BLR33142
MAKE KBC Burnham
MODEL L3W 150 G 4SPW-150-50-
0-WEB
SERIAL R6148 29955
MANUFACTURED 1984 2008
STARTUP 1988 2008
FUEL Natural Gas
FUEL HEAT
VALUE
1020 BTU/SCF
FUEL CAPACITY 6.28 MMBH 6.05 MMBH
PRODUCTS Hot Water
RATED
PRODUCTION
5.021 MMBH 5.021 MMBH
OPERATION* One unit online at near full load during winter
months with second unit at part load during
coldest days.
DAILY VAR None
SEASONAL VAR Operated only in winter.
*See 2023 Inventory in Appendix E for recent annual throughput data.

Waste Oil Heaters
Waste Oil Heaters are used in three remote barn/shed type structures where equipment, trucks,
and parts are stored. They are fueled with used lube oil collected throughout the year from engine
and vehicle maintenance. These units are only used in the winter to prevent freezing inside those
three buildings.
#1 (MAINTENANCE
BARN)
#2 (TRUCK BARN) #3 (EQUIPMENT
BARN)
EQUIPMENT ID HTR51 HTR52 HTR53
MAKE CLEAN BURN CLEAN BURN CLEAN BURN
MODEL CB3500 CB2800 CB 3250
SERIAL 279115 AP-1582 AM279115
MANUFACTURED 1992 1993 2015
STARTUP 1992 1993 2015
FUEL Used Oil
FUEL CAPACITY 0.35 MMBH @ 2.5 GPH 0.28 MMBH @ 2 GPH 0.3 MMBH @ 2.1 GPH
PRODUCTS Hot air
RATED
PRODUCTION
N/A N/A N/A
OPERATION* Each unit online during coldest winter months.
DAILY VAR None
SEASONAL VAR Operated only in winter.
*See 2023 Inventory in Appendix E for recent annual throughput data.

Appendix D

Potential Emissions
Emission Unit PM10 PM2.5 NOx CO**** SO2 VOC HAPs CO2e
Emergency Engines 2 & 3 0.063 0.063 2.15 0.49 0.0011 0.06 0.001 104
Emergency Engine 4 0.038 0.038 0.54 0.12 0.0002 0.04 0.000 20
Emergency Engines 5 & 6 0.056 0.056 0.74 0.03 0.0010 0.01 0.001 93
Emergency Engines 7 & 8 0.044 0.044 1.41 0.77 0.0016 0.09 0.001 156
Emergency Engines 9-11*0.035 0.035 4.77 0.40 0.0049 0.26 0.012 467
Natural Gas/Digester Gas Engines 1-4 2.91 1.94 53.30 242.27 0.181 29.07 22.21 43,463
Digester Gas Flares**0.00 0.00 0.02 0.11 0.00 0.24 72.26
Boiler #1 0.20 0.20 2.70 2.27 0.016 0.15 0.051 3,255
Boiler #2 0.20 0.20 2.60 2.18 0.016 0.14 0.049 3,136
Waste Oil Burners***0.14 0.14 0.06 0.01 0.196 0.004 0.022 65
Total*3.68 2.71 68.29 248.65 0.42 30.06 22.35 50831.13
DAQE-AN104140015-21 3.48 2.51 63.82 250.46 0.22 34.55 22.32 50209.31
Change in PTE 0.20 0.20 4.47 -1.81 0.20 -4.49 0.033 621.82
* Proposed to be added in 2023
** Updated with 2023 data
***Updated information obtained since last PTE submittal
**** CVWRF is a Major Source of CO due to theoretical PTE of our NG/Biogas Jenbacher Engines.
Point Source Emissions PTE Totals, TPY
Equipment Details
Backup Gen 2 (#ENG330009)896 hp Brake Specific Fuel Consumption
Backup Gen 3 (#ENG330011)896 hp 7000 BTU/hp-hr
Total Rating 1,792 hp = (1337.4 kw)
Operational Hours 100 hours/year
Sulfur Content 15 ppm or 0.0015%
Criteria Pollutant
Emission
Standards
(g/hp-hr)
Emission Factor
(lb/hp-hr)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year) Reference
NOX 0.024 43.01 2.15
CO 5.50E-03 9.86 0.49
PM10 7.00E-04 1.25 0.06
PM2.5 7.00E-04 1.25 0.06
VOC 6.42E-04 1.15 0.06
SO2 1.21E-05 0.02 0.00 AP-42 Table 3.4-1
HAP 0.02 0.00 See Below
Green House Gas Pollutant
Global
Warming
Potential
Emission Factor
(lb/hp-hr)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year) Reference
CO2 (mass basis)1 1.16 2,079 104
Methane (mass basis)25 6.35E-05 0 0
CO2e 104
Hazardous Air Pollutant
Emission Factor
(lb/MMBtu)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year) Reference
Benzene 7.76E-04 9.73E-03 4.87E-04
Toluene 2.81E-04 3.52E-03 1.76E-04
Xylenes 1.93E-04 2.42E-03 1.21E-04
1,3-Butadiene
Formaldehyde 7.89E-05 9.90E-04 4.95E-05
Acetaldehyde 2.52E-05 3.16E-04 1.58E-05
Acrolein 7.88E-06 9.88E-05 4.94E-06
Naphthalene 1.30E-04 1.63E-03 8.15E-05
Acenaphthylene 9.23E-06 1.16E-04 5.79E-06
Acenaphthene 4.68E-06 5.87E-05 2.94E-06
Fluorene 1.28E-05 1.61E-04 8.03E-06
Phenanthrene 4.08E-05 5.12E-04 2.56E-05
Anthracene 1.23E-06 1.54E-05 7.71E-07
Fluoranthene 4.03E-06 5.06E-05 2.53E-06
Pyrene 3.71E-06 4.65E-05 2.33E-06
Benz(a)anthracene 6.22E-07 7.80E-06 3.90E-07
Chrysene 1.53E-06 1.92E-05 9.60E-07
Benzo(b)fluoranthene 1.11E-06 1.39E-05 6.96E-07
Benzo(k)fluoranthene 2.18E-07 2.73E-06 1.37E-07
Benzo(a)pyrene 2.57E-07 3.22E-06 1.61E-07
Indeno(1,2,3-cd)pyrene 4.14E-07 5.19E-06 2.60E-07
Dibenz(a,h)anthracene 3.46E-07 4.34E-06 2.17E-07
Benzo(g,h,l)perylene 5.56E-07 6.97E-06 3.49E-07
Emergency Generators 2 & 3 (RSS)
Manufacturer Data,
AP-42 Table 3.3-1,
& Table 3.4-1
AP-42 Table 3.3-1
& Table 3.4-1
AP-42 Table 3.3-2,
Table 3.4-3, &
Table 3.4-4
Equipment Details
Backup Gen 4 (#ENG330010)349 hp Brake Specific Fuel Consumption
Total Rating 349 hp = (260.5 kw)7000 BTU/hp-hr
Operational Hours 100 hours/year
Sulfur Content 15 ppm or 0.0015%
Criteria Pollutant
Emission
Standards
(g/hp-hr)
Emission Factor
(lb/hp-hr)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year) Reference
NOX 0.031 10.82 0.54
CO 6.68E-03 2.33 0.12
PM10 2.20E-03 0.77 0.04
PM2.5 2.20E-03 0.77 0.04
VOC 2.51E-03 0.88 0.04
SO2 1.21E-05 0.00 0.00 AP-42 Table 3.4-1
HAP 0.01 0.00 See Below
Green House Gas Pollutant
Global
Warming
Potential
Emission Factor
(lb/hp-hr)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year) Reference
CO2 (mass basis)1 1.15 401 20
Methane (mass basis)25 0 0
CO2e 20
Hazardous Air Pollutant
Emission Factor
(lb/MMBtu)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year) Reference
Benzene 9.33E-04 2.28E-03 1.14E-04
Toluene 4.09E-04 9.99E-04 5.00E-05
Xylenes 2.85E-04 6.96E-04 3.48E-05
1,3-Butadiene 3.91E-05 9.55E-05 4.78E-06
Formaldehyde 1.18E-03 2.88E-03 1.44E-04
Acetaldehyde 7.67E-04 1.87E-03 9.37E-05
Acrolein 9.25E-05 2.26E-04 1.13E-05
Naphthalene 8.48E-05 2.07E-04 1.04E-05
Acenaphthylene 5.06E-06 1.24E-05 6.18E-07
Acenaphthene 1.42E-06 3.47E-06 1.73E-07
Fluorene 2.92E-05 7.13E-05 3.57E-06
Phenanthrene 2.94E-05 7.18E-05 3.59E-06
Anthracene 1.87E-06 4.57E-06 2.28E-07
Fluoranthene 7.61E-06 1.86E-05 9.30E-07
Pyrene 4.78E-06 1.17E-05 5.84E-07
Benz(a)anthracene 1.68E-06 4.10E-06 2.05E-07
Chrysene 3.53E-07 8.62E-07 4.31E-08
Benzo(b)fluoranthene 9.91E-08 2.42E-07 1.21E-08
Benzo(k)fluoranthene 1.55E-07 3.79E-07 1.89E-08
Benzo(a)pyrene 1.88E-07 4.59E-07 2.30E-08
Indeno(1,2,3-cd)pyrene 3.75E-07 9.16E-07 4.58E-08
Dibenz(a,h)anthracene 5.83E-07 1.42E-06 7.12E-08
Benzo(g,h,l)perylene 4.89E-07 1.19E-06 5.97E-08
Emergency Generator 4 (Admin)
Manufacturer Data,
AP-42 Table 3.3-1,
& Table 3.4-1
AP-42 Table 3.3-1
& Table 3.4-1
AP-42 Table 3.3-2,
Table 3.4-3, &
Table 3.4-4
Equipment Details
Backup Gen 5 (#ENG330006)800 hp Brake Specific Fuel Consumption
Backup Gen 6 (#ENG330007)800 hp 7000 BTU/hp-hr
Total Rating 1,600 hp = (1194.1 kw)
Operational Hours 100 hours/year
Sulfur Content 15 ppm or 0.0015%
Criteria Pollutant
Emission
Standards
(g/hp-hr)
Emission Factor
(lb/hp-hr)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year) Reference
NOX 14.79 0.74
CO 5.50E-03 0.57 0.03
PM10 7.00E-04 1.12 0.06
PM2.5 7.00E-04 1.12 0.06
VOC 6.42E-04 0.13 0.01
SO2 1.21E-05 0.02 0.00 AP-42 Table 3.4-1
HAP 0.02 0.00 See Below
Green House Gas Pollutant
Global
Warming
Potential
Emission Factor
(lb/hp-hr)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year) Reference
CO2 (mass basis)1 1.16 1,856 93
Methane (mass basis)25 6.35E-05 0 0
CO2e 93
Hazardous Air Pollutant
Emission Factor
(lb/MMBtu)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year) Reference
Benzene 7.76E-04 8.69E-03 4.35E-04
Toluene 2.81E-04 3.15E-03 1.57E-04
Xylenes 1.93E-04 2.16E-03 1.08E-04
1,3-Butadiene
Formaldehyde 7.89E-05 8.84E-04 4.42E-05
Acetaldehyde 2.52E-05 2.82E-04 1.41E-05
Acrolein 7.88E-06 8.83E-05 4.41E-06
Naphthalene 1.30E-04 1.46E-03 7.28E-05
Acenaphthylene 9.23E-06 1.03E-04 5.17E-06
Acenaphthene 4.68E-06 5.24E-05 2.62E-06
Fluorene 1.28E-05 1.43E-04 7.17E-06
Phenanthrene 4.08E-05 4.57E-04 2.28E-05
Anthracene 1.23E-06 1.38E-05 6.89E-07
Fluoranthene 4.03E-06 4.51E-05 2.26E-06
Pyrene 3.71E-06 4.16E-05 2.08E-06
Benz(a)anthracene 6.22E-07 6.97E-06 3.48E-07
Chrysene 1.53E-06 1.71E-05 8.57E-07
Benzo(b)fluoranthene 1.11E-06 1.24E-05 6.22E-07
Benzo(k)fluoranthene 2.18E-07 2.44E-06 1.22E-07
Benzo(a)pyrene 2.57E-07 2.88E-06 1.44E-07
Indeno(1,2,3-cd)pyrene 4.14E-07 4.64E-06 2.32E-07
Dibenz(a,h)anthracene 3.46E-07 3.88E-06 1.94E-07
Benzo(g,h,l)perylene 5.56E-07 6.23E-06 3.11E-07
Emergency Generators 5 & 6 (Power Gen)
Manufacturer Data,
AP-42 Table 3.3-1,
& Table 3.4-1
AP-42 Table 3.3-1
& Table 3.4-1
AP-42 Table 3.3-2,
Table 3.4-3, &
Table 3.4-4
Equipment Details
Backup Gen 7 (#ENG330012)1,341 hp Brake Specific Fuel Consumption
Backup Gen 8 (#ENG330013)1,341 hp 7000 BTU/hp-hr
Total Rating 2,682 hp = (2001.5 kw)
Operational Hours 100 hours/year
Sulfur Content 15 ppm or 0.0015%
Criteria Pollutant
Emission
Standards
(g/hp-hr)
Emission Factor
(lb/hp-hr)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year) Reference
NOX 4.77 28.20 1.41
CO 2.61 15.43 0.77
PM10 0.15 0.89 0.04
PM2.5 0.15 0.89 0.04
VOC 6.42E-04 1.72 0.09
SO2 1.21E-05 0.03 0.00 AP-42 Table 3.4-1
HAP 0.03 0.00 See Below
Green House Gas Pollutant
Global
Warming
Potential
Emission Factor
(lb/hp-hr)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year) Reference
CO2 (mass basis)1 1.16 3,111 156
Methane (mass basis)25 6.35E-05 0 0
CO2e 156
Hazardous Air Pollutant
Emission Factor
(lb/MMBtu)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year) Reference
Benzene 7.76E-04 1.46E-02 7.28E-04
Toluene 2.81E-04 5.28E-03 2.64E-04
Xylenes 1.93E-04 3.62E-03 1.81E-04
1,3-Butadiene
Formaldehyde 7.89E-05 1.48E-03 7.41E-05
Acetaldehyde 2.52E-05 4.73E-04 2.37E-05
Acrolein 7.88E-06 1.48E-04 7.40E-06
Naphthalene 1.30E-04 2.44E-03 1.22E-04
Acenaphthylene 9.23E-06 1.73E-04 8.66E-06
Acenaphthene 4.68E-06 8.79E-05 4.39E-06
Fluorene 1.28E-05 2.40E-04 1.20E-05
Phenanthrene 4.08E-05 7.66E-04 3.83E-05
Anthracene 1.23E-06 2.31E-05 1.15E-06
Fluoranthene 4.03E-06 7.57E-05 3.78E-06
Pyrene 3.71E-06 6.97E-05 3.48E-06
Benz(a)anthracene 6.22E-07 1.17E-05 5.84E-07
Chrysene 1.53E-06 2.87E-05 1.44E-06
Benzo(b)fluoranthene 1.11E-06 2.08E-05 1.04E-06
Benzo(k)fluoranthene 2.18E-07 4.09E-06 2.05E-07
Benzo(a)pyrene 2.57E-07 4.82E-06 2.41E-07
Indeno(1,2,3-cd)pyrene 4.14E-07 7.77E-06 3.89E-07
Dibenz(a,h)anthracene 3.46E-07 6.50E-06 3.25E-07
Benzo(g,h,l)perylene 5.56E-07 1.04E-05 5.22E-07
Emergency Generators 7 & 8 (Headworks)
Tier 2 limits,
AP-42 Table 3.3-1,
& Table 3.4-1
AP-42 Table 3.3-1
& Table 3.4-1
AP-42 Table 3.3-2,
Table 3.4-3, &
Table 3.4-4
Equipment Details
Backup Gen 9 (#TBD)2,680 hp Brake Specific Fuel Consumption
Backup Gen 10 (#TBD)2,680 hp 7000 BTU/hp-hr
Backup Gen 11 (#TBD)2,680 hp
Total Rating 8,040 hp = (6000 kw)
Operational Hours 100 hours/year
Sulfur Content 15 ppm or 0.0015%
Criteria Pollutant
Emission
Standards
(g/hp-hr)
Emission Factor
(lb/hp-hr)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year) Reference
NOX 5.38 95.36 4.77
CO 0.45 7.98 0.40
PM10 0.04 0.71 0.035
PM2.5 0.04 0.71 0.035
VOC 6.42E-04 5.16 0.26
SO2 1.21E-05 0.10 0.005 AP-42 Table 3.4-1
HAP 0.25 0.01 See Below
Green House Gas Pollutant
Global
Warming
Potential
Emission Factor
(lb/hp-hr)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year) Reference
CO2 (mass basis)1 1.16 9,326 466
Methane (mass basis)25 6.35E-05 1 0.03
CO2e 467
Hazardous Air Pollutant
Emission Factor
(lb/MMBtu)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year) Reference
Benzene 7.76E-04 4.37E-02 2.18E-03
Toluene 2.81E-04 1.58E-02 7.91E-04
Xylenes 1.93E-04 1.09E-02 5.43E-04
Propylene 2.79E-03 1.57E-01 7.85E-03
Formaldehyde 7.89E-05 4.44E-03 2.22E-04
Acetaldehyde 2.52E-05 1.42E-03 7.09E-05
Acrolein 7.88E-06 4.43E-04 2.22E-05
Naphthalene 1.30E-04 7.32E-03 3.66E-04
Acenaphthylene 9.23E-06 5.19E-04 2.60E-05
Acenaphthene 4.68E-06 2.63E-04 1.32E-05
Fluorene 1.28E-05 7.20E-04 3.60E-05
Phenanthrene 4.08E-05 2.30E-03 1.15E-04
Anthracene 1.23E-06 6.92E-05 3.46E-06
Fluoranthene 4.03E-06 2.27E-04 1.13E-05
Pyrene 3.71E-06 2.09E-04 1.04E-05
Benz(a)anthracene 6.22E-07 3.50E-05 1.75E-06
Chrysene 1.53E-06 8.61E-05 4.31E-06
Benzo(b)fluoranthene 1.11E-06 6.25E-05 3.12E-06
Benzo(k)fluoranthene 2.18E-07 1.23E-05 6.13E-07
Benzo(a)pyrene 2.57E-07 1.45E-05 7.23E-07
Indeno(1,2,3-cd)pyrene 4.14E-07 2.33E-05 1.16E-06
Dibenz(a,h)anthracene 3.46E-07 1.95E-05 9.74E-07
Benzo(g,h,l)perylene 5.56E-07 3.13E-05 1.56E-06
Emergency Generators 9 - 11 (Blower Bldg)
Manufacturer Data
AP-42 Table 3.3-1,
& Table 3.4-1
AP-42 Table 3.3-1
& Table 3.4-1
AP-42 Table 3.3-2,
Table 3.4-3, &
Table 3.4-4
Equipment Details
Rating 2,509 hp = (1872.4 kw) <-- 4 engines (#ENG330001 -#ENG330004)Brake Specific Fuel Consumption
Operational Hours 8,760 hours/year 7000 BTU/hp-hr
Engine Type
Criteria Pollutant
*Emission
Standards
(g/hp-hr)
Emission Factor
(lb/MMBtu)
Emission
Rate
(lbs/hr)
Emission/engine
(tons/year)
Emission from four
engines
(tons/year) Reference
NOX 0.55 3.04 13.32 53.30
CO 2.5 13.83 60.57 242.27
PM10 0.03 0.17 0.73 2.91
PM2.5 0.02 0.11 0.48 1.94
VOC 0.3 1.66 7.27 29.07
SO2 5.88E-04 0.01 0.05 0.18
HAP 1.27 5.55 22.21 See Below
Green House Gas Pollutant
Global
Warming
Potential
Emission Factor
(lb/MMBtu)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year) Reference
CO2 (mass basis)1 1.10E+02 1,932 8,462 33,847
Methane (mass basis)25 1.25E+00 22 96 385
CO2e 10,866 43,463
Hazardous Air Pollutant Emission Factor Emission Emission Reference
1,1,2,2-Tetrachloroethane 4.00E-05 7.03E-04 3.08E-03
1,1,2-Trichloroethane 3.18E-05 5.59E-04 2.45E-03
1,3-Butadiene 2.67E-04 4.69E-03 2.05E-02
1,3-Dichloropropene 2.64E-05 4.64E-04 2.03E-03
2,2,4-Trimethylpentane 2.50E-04 4.39E-03 1.92E-02
2-Methylnaphthalene 3.32E-05 5.83E-04 2.55E-03
Acenaphthene 1.25E-06 2.20E-05 9.62E-05
Acenaphthylene 5.53E-06 9.71E-05 4.25E-04
Acetaldehyde 8.36E-03 1.47E-01 6.43E-01
Acrolein 5.14E-03 9.03E-02 3.95E-01
Benzene 4.40E-04 7.73E-03 3.38E-02
Benzo(b)fluoranthene 1.66E-07 2.92E-06 1.28E-05
Benzo(e)pyrene 4.15E-07 7.29E-06 3.19E-05
benzo(g,h,i)perylene 4.14E-07 7.27E-06 3.18E-05
Biphenyl 2.12E-04 3.72E-03 1.63E-02
Carbon Tetrachloride 3.67E-05 6.45E-04 2.82E-03
Chlorobenzene 3.04E-05 5.34E-04 2.34E-03
Chloroform 2.85E-05 5.01E-04 2.19E-03
Chrysene 6.93E-07 1.22E-05 5.33E-05
Ethylbenzene 3.97E-05 6.97E-04 3.05E-03
Ethylene Dibromide 4.43E-05 7.78E-04 3.41E-03
Fluoranthene 1.11E-06 1.95E-05 8.54E-05
Fluorene 5.67E-06 9.96E-05 4.36E-04
Formaldehyde 5.28E-02 9.27E-01 4.06E+00
Methanol 2.50E-03 4.39E-02 1.92E-01
Methylene Chloride 2.00E-05 3.51E-04 1.54E-03
n-Hexane 1.11E-03 1.95E-02 8.54E-02
Naphthalene 7.44E-05 1.31E-03 5.72E-03
PAH 2.69E-05 4.72E-04 2.07E-03
Phenanthrene 1.04E-05 1.83E-04 8.00E-04
Phenol 2.40E-05 4.22E-04 1.85E-03
Pyrene 1.36E-06 2.39E-05 1.05E-04
Styrene 2.36E-05 4.14E-04 1.82E-03
Tetrachloroethane 2.48E-06 4.36E-05 1.91E-04
Toluene 4.08E-04 7.17E-03 3.14E-02
Vinyl Chloride 1.49E-05 2.62E-04 1.15E-03
Xylene 1.84E-04 3.23E-03 1.42E-02
Manufacturer Data,
AP-42 Table 3.2-1,
Table 3.2-2, &
Table 3.2-3
AP-42 Table 3.2-1,
Table 3.2-2, &
Table 3.2-3
AP-42 Table 3.2-1,
Table 3.2-2, &
Table 3.2-3
Biogas / Natural Gas-Fired Engines 1 - 4
4-Stroke Lean-Burn
* Manufacturer's specifcations see Central Valley NOI dated Feb 15, 2017
Equipment Details
Average Monthly Flow Rate 100,317 scf/month updated per 2023 throughput
Annual Flare Flow rate 1,203,804 scf/yr
HHV Digester Gas 600 BTU/scf
Hourly Flow Rate 0.08 MMBtu/hr
Operational Hours 8,760 hours/year
Criteria Pollutant
Emission Factor
(lb/MMBtu)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year) Reference
NOX 0.068 0.01 0.02
CO 0.31 0.03 0.11
PM10 0.00E+00 0.00 0.00
PM2.5 0.00E+00 0.00 0.00
VOC 0.66 0.05 0.24
SO2 0.00E+00 0.00 0.00
Green House Gas Pollutant
Global
Warming
Potential
Emission Factor
(lb/10^6 scf)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year) Reference
CO2 (mass basis)1 120,000 16 72
Methane (mass basis)25 2.3 0.0003 0.0014
CO2e 2.2 72
AP-42 Table 3.3-1
& Table 3.4-1
AP-42 Table 13.5-1,
& Table 13.5-2
Digester Gas Flares (2)
Equipment Details
Rating (Max Firing Range Gas)6.28 MMBtu/hour Max heat output rating is 5.021
Operational Hours 8,760 hours/year HV of Natural Gas
Firing Normal 1020 BTU/scf
Criteria Pollutant
Concentration
(ppm)
Emission
Factor
(lb/10^6 scf)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year) Reference
NOX 100 0.62 2.70
CO 84 0.52 2.27
PM10 7.6 0.05 0.20
PM2.5 7.6 0.05 0.20
VOC 5.5 0.03 0.15
SO2 0.6 0.00 0.02
Lead 0.0005 0.00 0.00
HAP 0.01 0.05 See Below
Green House Gas Pollutant
Global
Warming
Potential
Emission
Factor
(lb/10^6 scf)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year) Reference
CO2 (mass basis)1 120,000 738.8 3,236
Methane (mass basis)25 2.3 0.014 0.062
N2O (mass basis)298 2.2 0.014 0.059
CO2e 3,255.3
Hazardous Air Pollutant
Emission
Factor
(lb/10^6 scf)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year) Reference
2-Methylnaphthalene 2.40E-05 1.48E-07 6.47E-07
3-Methylchloranthrene 1.80E-06 1.11E-08 4.85E-08
7,12-Dimethylbenz(a)anthracene 1.60E-05 9.85E-08 4.31E-07
Acenaphthene 1.80E-06 1.11E-08 4.85E-08
Acenaphthylene 1.80E-06 1.11E-08 4.85E-08
Anthracene 2.40E-06 1.48E-08 6.47E-08
Benz(a)anthracene 1.80E-06 1.11E-08 4.85E-08
Benzene 2.10E-03 1.29E-05 5.66E-05
Benzo(a)pyrene 1.20E-06 7.39E-09 3.24E-08
Benzo(b)fluoranthene 1.80E-06 1.11E-08 4.85E-08
Benzo(g,h,i)perylene 1.20E-06 7.39E-09 3.24E-08
Benzo(k)fluoranthene 1.80E-06 1.11E-08 4.85E-08
Chrysene 1.80E-06 1.11E-08 4.85E-08
Dibenzo(a,h)anthracene 1.20E-06 7.39E-09 3.24E-08
Dichlorobenzene 1.20E-03 7.39E-06 3.24E-05
Fluoranthene 3.00E-06 1.85E-08 8.09E-08
Fluorene 2.80E-06 1.72E-08 7.55E-08
Formaldehyde 7.50E-02 4.62E-04 2.02E-03
Hexane 1.80E+00 1.11E-02 4.85E-02
Indeno(1,2,3-cd)pyrene 1.80E-06 1.11E-08 4.85E-08
Naphthalene 6.10E-04 3.76E-06 1.64E-05
Phenanathrene 1.70E-05 1.05E-07 4.58E-07
Pyrene 5.00E-06 3.08E-08 1.35E-07
Toluene 3.40E-03 2.09E-05 9.17E-05
Arsenic 2.00E-04 1.23E-06 5.39E-06
Beryllium 1.20E-05 7.39E-08 3.24E-07
Cadmium 1.10E-03 6.77E-06 2.97E-05
Chromium 1.40E-03 8.62E-06 3.78E-05
Cobalt 8.40E-05 5.17E-07 2.27E-06
Manganese 3.80E-04 2.34E-06 1.02E-05
Mercury 2.60E-04 1.60E-06 7.01E-06
Nickel 2.10E-03 1.29E-05 5.66E-05
Selenium 2.40E-05 1.48E-07 6.47E-07
AP-42 Table 1.4-4
Natural Gas-Fired Boiler #1
Manufacturer Data
or AP-42 Table 1.4-1
AP-42 Table 1.4-2
AP-42 Table 1.4-2
&
Table A-1 to
Subpart A of Part 98
AP-42 Table 1.4-3
Equipment Details
Rating (max gas input)6.05 MMBtu/hour Max heat output rating is 5.021
Operational Hours 8,760 hours/year HV of Natural Gas
Firing Normal 1020 BTU/scf
Criteria Pollutant
Concentration
(ppm)
Emission
Factor
(lb/10^6 scf)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year) Reference
NOX 100 0.59 2.60
CO 84 0.50 2.18
PM10 7.6 0.05 0.197
PM2.5 7.6 0.05 0.197
VOC 5.5 0.03 0.14
SO2 0.6 0.00 0.02
Lead 0.0005 0.00 0.00
HAP 0.01 0.05 See Below
Green House Gas Pollutant
Global
Warming
Potential
Emission
Factor
(lb/10^6 scf)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year) Reference
CO2 (mass basis)1 120,000 711.8 3,118
Methane (mass basis)25 2.3 0.014 0.060
N2O (mass basis)298 2.2 0.013 0.057
CO2e 3,136.1
Hazardous Air Pollutant
Emission
Factor
(lb/10^6 scf)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year) Reference
2-Methylnaphthalene 2.40E-05 1.42E-07 6.24E-07
3-Methylchloranthrene 1.80E-06 1.07E-08 4.68E-08
7,12-Dimethylbenz(a)anthracene 1.60E-05 9.49E-08 4.16E-07
Acenaphthene 1.80E-06 1.07E-08 4.68E-08
Acenaphthylene 1.80E-06 1.07E-08 4.68E-08
Anthracene 2.40E-06 1.42E-08 6.24E-08
Benz(a)anthracene 1.80E-06 1.07E-08 4.68E-08
Benzene 2.10E-03 1.25E-05 5.46E-05
Benzo(a)pyrene 1.20E-06 7.12E-09 3.12E-08
Benzo(b)fluoranthene 1.80E-06 1.07E-08 4.68E-08
Benzo(g,h,i)perylene 1.20E-06 7.12E-09 3.12E-08
Benzo(k)fluoranthene 1.80E-06 1.07E-08 4.68E-08
Chrysene 1.80E-06 1.07E-08 4.68E-08
Dibenzo(a,h)anthracene 1.20E-06 7.12E-09 3.12E-08
Dichlorobenzene 1.20E-03 7.12E-06 3.12E-05
Fluoranthene 3.00E-06 1.78E-08 7.79E-08
Fluorene 2.80E-06 1.66E-08 7.27E-08
Formaldehyde 7.50E-02 4.45E-04 1.95E-03
Hexane 1.80E+00 1.07E-02 4.68E-02
Indeno(1,2,3-cd)pyrene 1.80E-06 1.07E-08 4.68E-08
Naphthalene 6.10E-04 3.62E-06 1.58E-05
Phenanathrene 1.70E-05 1.01E-07 4.42E-07
Pyrene 5.00E-06 2.97E-08 1.30E-07
Toluene 3.40E-03 2.02E-05 8.83E-05
Arsenic 2.00E-04 1.19E-06 5.20E-06
Beryllium 1.20E-05 7.12E-08 3.12E-07
Cadmium 1.10E-03 6.52E-06 2.86E-05
Chromium 1.40E-03 8.30E-06 3.64E-05
Cobalt 8.40E-05 4.98E-07 2.18E-06
Manganese 3.80E-04 2.25E-06 9.87E-06
Mercury 2.60E-04 1.54E-06 6.75E-06
Nickel 2.10E-03 1.25E-05 5.46E-05
Selenium 2.40E-05 1.42E-07 6.24E-07
AP-42 Table 1.4-4
Natural Gas-Fired Boiler #2
Manufacturer Data
or AP-42 Table 1.4-1
AP-42 Table 1.4-2
AP-42 Table 1.4-2
&
Table A-1 to
Subpart A of Part 98
AP-42 Table 1.4-3
Equipment Details
Model CB3500 0.35 MMBtu/hr*Maintenance Barn
Model CB 3250 0.33 MMBtu/hr*Equipment Barn
Model CB2800 0.28 MMBtu/hr*Truck Barn
Total Rating 0.96 MMBtu/hour
Model CB3500 2.30 gal/hr
Model CB 3250 2.10 gal/hr
Model CB2800 1.70 gal/hr
Total Fuel Consumption 6.10 gal/hr
Operational Hours 1,200 hours/year <-- Assuming 10 hour shifts, 5 days per week, 6 months
Criteria Pollutant
Emission
Factor
(lb/10^3 gal)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year) Reference
NOX 16 9.76E-02 5.86E-02
AP-42 Table 1.11-2
CO 2.1 1.28E-02 7.69E-03 AP-42 Table 1.11-2
PM10 37.05 2.26E-01 1.36E-01 AP-42 Table 1.11-1 0.65% Ash assumed
PM2.5 37.05 2.26E-01 1.36E-01 AP-42 Table 1.11-1 conservative assumption
VOC 1 6.10E-03 3.66E-03 AP-42 Table 1.11-3
SO2 53.5 3.26E-01 1.96E-01 AP-42 Table 1.11-2 0.5% Sulfur assumed
Lead 5.5 3.36E-02 2.01E-02 AP-42 Table 1.11-1 0.11% Lead assumed
HAPs 3.64E-02 2.18E-02
Green House Gas Pollutant
Global
Warming
Potential
Emission Factor
(lb/10^3 gal)
Emission
Total
(tons/year) Reference
CO2 (mass basis)1 22,000 409
Methane (mass basis)25 0.475 0.01
N2O (mass basis)298 0.53 0.01
CO2e 65
Hazardous Air Pollutant
Emission
Factor
(lb/10^3 gal)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year) Reference
Phenol 2.80E-03 1.71E-05 1.02E-05
Dichlorobenzene 0.00E+00 0.00E+00 0.00E+00
Naphthalene 9.20E-05 5.61E-07 3.37E-07
Phenanthrene/anthracene 1.00E-04 6.10E-07 3.66E-07
Dibutylphthalate 3.40E-05 2.07E-07 1.24E-07
Butylbenzylphthalate 0.00E+00 0.00E+00 0.00E+00
Bis(2-ethylhexyl)phthalate 0.00E+00 0.00E+00 0.00E+00
Pyrene 8.30E-06 5.06E-08 3.04E-08
Benz(a)anthracene/chrysene 0.00E+00 0.00E+00 0.00E+00
Benzo(a)pyrene 0.00E+00 0.00E+00 0.00E+00
Trichloroethylene 0.00E+00 0.00E+00 0.00E+00
Arsenic 6.00E-02 3.66E-04 2.20E-04
Beryllium 1.80E-03 1.10E-05 6.59E-06
Cadmium 1.20E-02 7.32E-05 4.39E-05
Chromium 1.80E-01 1.10E-03 6.59E-04
Lead 0.00E+00 0.00E+00 0.00E+00
Mercury 0.00E+00 0.00E+00 0.00E+00
Manganese 5.00E-02 3.05E-04 1.83E-04
Nickel 1.60E-01 9.76E-04 5.86E-04
Selenium 0.00E+00 0.00E+00 0.00E+00
Waste Oil Burners
AP-42 Table 1.11-5
and 1.11-4
AP-42 Table 1.11-3,
AP-42 Table 1.3-3,8
& Table A-1 to
Subpart A of Part 98
*nominal rating of the
burner, but based on No
2 fuel oil, actual BTU/hr
with waste oil unknown,
but likely slightly less
Appendix E

Insignificant Emissions
List of Insignificant Emissions Units
2023 Emission Inventory attached
Coatings:
· Acrylic
· Aerosols
· Epoxy
· Thinner
Composting:
· Aerated-Static Compost Piles
· Green Waste Pile
Fuel Tanks:
· Diesel Fuel Storage Tanks
· Unleaded Fuel Storage Tank
Rolling Stock and Portable Units:
· Big Blue Trash Pump
· Boom Truck
· Case Backhoe
· Cover Placement Machine (Tarp
Winder)
· Go Bagger
· Godwin Trash Pumps
· Grove Crane Truck
· JLG Lift (Unleaded)
· JLG Lift (Propane)
· John Deere Tractors
· Kubota Tractor
· McCloskey Trommel Screener
· Portable Generators/Welders and
Other Small Gas Equipment
· Mini Excavator
· On-Site Diesel Pickup Trucks
· On-site Pickup Trucks
· Peterbuilt Truck (Rotomix)
· Peterson Wood Grinder
· Power Wash Trailers (Unleaded)
· Power Wash Trailers (Diesel)
· Power Wash Trailers (Propane)
· Scarab (Compost Turner)
· Service Trucks (Unleaded)
· Service Trucks (Diesel)
· Skid Steer Loaders
· Sullair Portable Compressor
· Telehandler
· Vermeer Vactor Trailer
· Yamaha ATV
Wastewater Treatment Process Fugitive
Emissions*
Unpaved Roads

*CVWRF is constructing a new biological
wastewater treatment process that is
expected to become operational in the
fall of 2025. At that time, a portion of our
existing biological process will be
decommissioned. This change is
expected to have a minor e8ect on facility
emissions.
Signature Page
Signed By
Bryan Mansell
URL
https://sleis.deq.utah.gov/Document/Sign
Agreement #1
I am the owner of the account used to perform the electronic submission.
Agreement #2
I have the authority to submit the data on behalf of the facility I am representing.
Agreement #3
I have reviewed the electronic report being submitted in its entirety, and agree to the validity and accuracy of the
information contained within it to the best of my knowledge.
Confirmation Number
S20240415111736-F10414-R2023
SLEIS signed on: 4/15/2024 11:19:03 AM. See
document signature for details.
2023 Emissions Inventory Report
Central Valley Water Reclamation Facility Wastewater Treatment Plant (10414)
Emissions Summary
CRITERIA AIR POLLUTANT (CAP) EMISSIONS TOTALS
Pollutant Code/CAS #Pollutant Name Emissions
(tons, excluding
tailpipe)
Tailpipe
Emissions
(tons)
Total Emissions
(tons)*
PM10-PRI PM10 Primary (Filt + Cond)2.87976 0.02368 2.90344
PM10-FIL PM10 Filterable 1.6744 <.00001 1.6744
PM25-PRI PM2.5 Primary (Filt + Cond)1.799 0.02187 1.82087
PM25-FIL PM2.5 Filterable 0.59364 <.00001 0.59364
PM-CON PM Condensible 1.20038 <.00001 1.20038
SO2 Sulfur Dioxide 2.42548 0.00097 2.42645
NOX Nitrogen Oxides 17.56438 0.63619 18.20057
VOC Volatile Organic Compounds 16.51811 0.07096 16.58907
CO Carbon Monoxide 75.62875 1.07051 76.69926
7439921 Lead 0.00417 <.00001 0.00417
NH3 Ammonia 14.69761 <.00001 14.69761

HAZARDOUS AIR POLLUTANT (HAP) and/or OTHER POLLUTANT EMISSIONS TOTALS
Pollutant Code/CAS #Pollutant Name Is VOC/PM? Total Emissions
(tons)*
75070 Acetaldehyde (HAP)VOC 0.00004
107028 Acrolein (HAP)VOC 0.00001
7440360 Antimony (HAP)PM 0.00001
7440382 Arsenic (HAP)PM 0.00012
71432 Benzene (HAP)VOC 0.00014
7440417 Beryllium (HAP)PM <.00001
106990 1,3-Butadiene (HAP)VOC <.00001
7440439 Cadmium (HAP)PM 0.00002
7440473 Chromium (HAP)PM 0.00037
7440484 Cobalt (HAP)PM 0.00001
84742 Dibutyl Phthalate (HAP)VOC <.00001
50000 Formaldehyde (HAP)VOC 0.00006
7439965 Manganese (HAP)PM 0.0001
91203 Naphthalene (HAP)VOC 0.00002
1/64
7440020 Nickel (HAP)PM 0.00033
108952 Phenol (HAP)VOC <.00001
130498292 PAH, total (HAP)PM 0.00003
108883 Toluene (HAP)VOC 0.00005
1330207 Xylenes (Mixed Isomers) (HAP)VOC 0.00004

Pollutant Code/CAS #Pollutant Name Is VOC/PM? Total Emissions
(tons)*
*Rounded to 5 digits past the decimal point. Note that where rounding results in 0, <.00001 is indicated.
2/64
2023 Emissions Inventory Report
Central Valley Water Reclamation Facility Wastewater Treatment Plant (10414)
FACILITY
Facility Identifier:10414 Facility Name:Central Valley Water Reclamation Facility Wastewater Treatment Plant
Description:
Status:OP - Operating Status Year:2014
NAICS:221320 (Primary) - Sewage Treatment Facilities
Comments:

CONTACTS
Emissions Contact:Bryan Mansell
Email [e-mail]
Phone [phone]

ADDRESS
Location Address:800 W Central Valley Road
Salt Lake City, UT 84119-3379 Mailing Address:800 W Central Valley Road
Salt Lake City, UT 84119-3379

LOCATION
Latitude (decimal degress):40.706 Longitude (decimal degress):-111.916
UTM X (meters):422600 UTM Y (meters):4506500 UTM Zone:12

ADDITIONAL INFORMATION
Field Name Field Value
Customer ID VC0000169197
Owner Name Central Valley Water Reclamation Facility

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RELEASE POINTS
ID Type Description Status Details Location
952 Vertical w ith
Rain Cap KBC Boiler Stack (South)OP Height: 42.0 FEET, Shape: Circular, Diameter: 1.67 FEET, Temperature:
400.0 F, Flow Rate: 16.6 ACFS, Velocity: 7.57854 FPS Uses Facility Site Location
17032 Vertical w ith
Rain Cap Waste Oil Burner Maintenance OP Height: 27.0 FEET, Shape: Circular, Diameter: 0.65 FEET, Temperature:
198.0 F, Flow Rate: 70.0 ACFS, Velocity: 210.95093 FPS Uses Facility Site Location
181601 Vertical w ith
Rain Cap RSS #9 Standby generator Stack OP Height: 11.5 FEET, Shape: Circular, Diameter: 0.83 FEET, Temperature:
176.0 F, Flow Rate: 84.75 ACFS, Velocity: 156.63674 FPS Uses Facility Site Location
181602 Vertical w ith
Rain Cap RSS #11 Standby generator Stack OP Height: 11.5 FEET, Shape: Circular, Diameter: 0.88 FEET, Temperature:
111.0 F, Flow Rate: 85.0 ACFS, Velocity: 139.75382 FPS Uses Facility Site Location
181603 Horizontal Admin #10 Standby generator Stack OP Height: 11.0 FEET, Shape: Circular, Diameter: 0.53 FEET, Temperature:
130.0 F, Flow Rate: 36.0 ACFS, Velocity: 163.17773 FPS Uses Facility Site Location
184138 Vertical Jenbacher IC Engine 1 Stack OP in 2019 Height: 45.0 FEET, Shape: Circular, Diameter: 1.67 FEET, Temperature:
239.0 F, Flow Rate: 157.55 ACFS, Velocity: 72.0 FPS Uses Facility Site Location
184139 Vertical Jenbacher IC Engine 2 Stack OP in 2020 Height: 45.0 FEET, Shape: Circular, Diameter: 1.67 FEET, Temperature:
322.0 F, Flow Rate: 168.0 ACFS, Velocity: 77.0 FPS Uses Facility Site Location
184140 Vertical Burnham Boiler Stack (North)OP in 2009 Height: 42.0 FEET, Shape: Circular, Diameter: 1.7 FEET, Temperature:
400.0 F, Flow Rate: 16.6 ACFS, Velocity: 7.31342 FPS Uses Facility Site Location
184141 Fugitive Area Gas System Waste Gas Flares OP in 2020 Fugitive Height: 12.0 FEET, Fugitive Width: , Fugitive Length: , Fugitive
Angle:Uses Facility Site Location
184182 Vertical w ith
Rain Cap Pow er Gen #6 Standby Generator Stack OP in 2018 Height: 14.9 FEET, Shape: Circular, Diameter: 0.56 FEET, Temperature:
220.0 F, Flow Rate: 77.7 ACFS, Velocity: 312.66991 FPS Uses Facility Site Location
184183 Vertical w ith
Rain Cap Pow er Gen #7 Standby Generator Stack OP in 2018 Height: 16.2 FEET, Shape: Circular, Diameter: 0.56 FEET, Temperature:
180.0 F, Flow Rate: 77.7 ACFS, Velocity: 315.46783 FPS Uses Facility Site Location
184192 Vertical w ith
Rain Cap Headw orks #12 Standby diesel fueled engine generator OP in 2020 Height: 17.0 FEET, Shape: Circular, Diameter: 1.15 FEET, Temperature:
210.0 F, Flow Rate: 159.0 ACFS, Velocity: 153.07757 FPS Uses Facility Site Location
184193 Vertical w ith
Rain Cap Headw orks #13 Standby diesel fueled engine generator OP in 2021 Height: 17.0 FEET, Shape: Circular, Diameter: 1.15 FEET, Temperature:
142.0 F, Flow Rate: 159.0 ACFS, Velocity: 153.07757 FPS Uses Facility Site Location
184456 Vertical Jenbacher IC Engine 3 Stack OP in 2021 Height: 45.0 FEET, Shape: Circular, Diameter: 1.67 FEET, Temperature:
365.0 F, Flow Rate: 168.0 ACFS, Velocity: 77.0 FPS Uses Facility Site Location
184620 Vertical Jenbacher IC Engine 4 Stack OP in 2022 Height: 45.0 FEET, Shape: Circular, Diameter: 1.67 FEET, Temperature:
365.0 F, Flow Rate: 168.0 ACFS, Velocity: 76.69843 FPS Uses Facility Site Location
925064 Fugitive Area Aerosols OP in 2019 Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
925086 Fugitive Area Thinner OP Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
947008 Fugitive Area Portable Generators/Welders and Other Small Gas
Equipment OP Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
948576 Fugitive Area Scarab (Compost Turner)OP Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
948577 Fugitive Area Peterson Wood Grinder OP Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
948580 Fugitive Area Sullair Portable Compressor OP Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
948581 Fugitive Area Big Blue Trash Pump OP Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
948582 Fugitive Area Case Backhoe OP Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
948586 Fugitive Area Acrylic OP Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
4/64
948587 Fugitive Area Anaerobic Digester 1 (Floating Cover) Gap PS in 2023 Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
Comment: Combining this w ith the Overall Treatment Process, since it's part of treatment process-related f ugitive emissions. Accounted for in that EF calculation.
948588 Fugitive Area Anaerobic Digester 2 (Floating Cover) Gap PS in 2023 Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
Comment: Combining this w ith the Overall Treatment Process, since it's part of treatment process-related f ugitive emissions. Accounted for in that EF calculation.
948589 Fugitive Area Anaerobic Digester 3 (Floating Cover) Gap PS in 2023 Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
Comment: Combining this w ith the Overall Treatment Process, since it's part of treatment process-related f ugitive emissions. Accounted for in that EF calculation.
948591 Fugitive Area Anaerobic Digester 4 (Floating Cover) Gap PS in 2023 Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
Comment: Combining this w ith the Overall Treatment Process, since it's part of treatment process-related f ugitive emissions. Accounted for in that EF calculation.
948601 Vertical w ith
Rain Cap Waste Oil Burner Truck Barn OP Height: 28.0 FEET, Shape: Circular, Diameter: 0.61 FEET, Temperature:
190.0 F, Flow Rate: 45.0 ACFS, Velocity: 153.97952 FPS Uses Facility Site Location
948969 Fugitive Area Epoxy OP Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
953828 Fugitive Area John Deere Tractors OP Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
967043 Fugitive Area Aerated-Static Compost Piles OP Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
967070 Fugitive Area Peterbuilt Truck (Rotomix)OP Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
967152 Fugitive Area Skid Steer Loaders OP Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
967159 Fugitive Area Cover Placement Machine (Tarp Winder)OP Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
967160 Fugitive Area McCloskey Trommel Compost Screener OP Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
967161 Fugitive Area Belt Filter Presses (3)PS in 2023 Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
Comment: Combining this w ith the Overall Treatment Process, since it's part of treatment process-related f ugitive emissions. Accounted for in that EF calculation.
967175 Fugitive Area Anaerobic Digester 5 (Floating Cover) Gap PS in 2023 Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
Comment: Combining this w ith the Overall Treatment Process, since it's part of treatment process-related f ugitive emissions. Accounted for in that EF calculation.
970914 Fugitive Area Unpaved Roads OP in 2020 Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
Comment: Undergoing constructions - some roads temporarily unpaved
970929 Vertical w ith
Rain Cap Waste Oil Burner Dew atering Equipment Barn OP in 2015 Height: 27.0 FEET, Shape: Circular, Diameter: 0.65 FEET, Temperature:
120.0 F, Flow Rate: 55.0 ACFS, Velocity: 165.74716 FPS Uses Facility Site Location
970931 Fugitive Area Telehandler OP in 2019 Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
970932 Fugitive Area Biof ilter Bed PS in 2023 Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
Comment: Combining this w ith the Overall Treatment Process, since it's part of treatment process-related f ugitive emissions. Accounted for in that EF calculation.
970934 Fugitive Area Go Bagger OP in 2022 Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
970994 Fugitive Area Mini Excavator OP in 2019 Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
970995 Fugitive Area Boom Truck OP in 1995 Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
970997 Fugitive Area Service Trucks OP in 2001 Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
970998 Fugitive Area Kubota Tractor OP in 2018 Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
970999 Fugitive Area Godw in Trash Pumps OP in 2019 Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
971000 Fugitive Area On-site Pickup Trucks OP in 2016 Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
ID Type Description Status Details Location
5/64
Additional Information: Company Stack Description: Kevin's Truck and Operations Truck
971001 Fugitive Area JLG Lift OP in 2004 Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
971002 Fugitive Area Pow er Wash Trailers OP in 2012 Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
971003 Fugitive Area Vermeer Vactor Trailer OP in 2016 Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
971004 Fugitive Area Grove Crane Truck OP in 2018 Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
971005 Fugitive Area MadVac Sw eeper PS in 2023 Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
Comment: Sold
971071 Fugitive Area Diesel Fuel Storage Tanks OP in 2017 Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
971113 Fugitive Area Unleaded Fuel Storage Tank OP in 2017 Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
971247 Fugitive Area Wastew ater Treatment Process Fugitive Emissions OP Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
971519 Fugitive Area Yamaha ATV OP in 2021 Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
971634 Fugitive Area On-site Diesel Pickup Trucks OP in 2022 Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
Additional Information: Company Stack Description: Ford F550 Plow Truck
971996 Fugitive Area Green Waste Pile OP in 2023 Fugitive Height: , Fugitive Width: , Fugitive Length: , Fugitive Angle:Uses Facility Site Location
ID Type Description Status Details Location
6/64
CONTROL DEVICES
ID Description Status Control Measure Controlled Pollutants
1 Compost Micro-pore cover OP 99 - Other Control Device VOC-Volatile Organic Compounds: 95.0%
2 Dust Suppression by Watering and Calcium Chloride OP in 2020 217 - Dust Suppression PM10-PRI-PM10 Primary (Filt + Cond): 50.0%, PM10-FIL-PM10 Filterable: 50.0%, PM25-PRI-PM2.5 Primary
(Filt + Cond): 50.0%, PM25-FIL-PM2.5 Filterable: 50.0%
Comment: from USBR air quality assessment
3 biof ilter PS in 2023 302 - Biofilter VOC-Volatile Organic Compounds: 90.0%, NH3-Ammonia: 90.0%, 7783064-Hydrogen Sulfide: 99.5%
Comment: Combining this w ith the Overall Treatment Process, since it's part of treatment process-related f ugitive emissions. Accounted for in that EF calculation.
7/64
EMISSION UNITS
ID Type Description Status Details
3959 100 - Boiler - Fuel Comb. Equipment Burnham Boiler (North)OP Operation Start: , Design Capacity: 6.05 E6BTU/HR
21903 290 - Other combustion - Fuel Comb. Equipment (includes
space heaters, asphalt kettle heaters, etc.)
Portable Generators/Welders and Other Small Gas
Equipment OP Operation Start: , Design Capacity:
Comment: Count already accounted for in throughput.
168759 290 - Other combustion - Fuel Comb. Equipment (includes
space heaters, asphalt kettle heaters, etc.)Scarab (Compost Turner)OP Operation Start: , Design Capacity:
168760 290 - Other combustion - Fuel Comb. Equipment (includes
space heaters, asphalt kettle heaters, etc.)Peterson Wood Grinder OP Operation Start: , Design Capacity:
168763 290 - Other combustion - Fuel Comb. Equipment (includes
space heaters, asphalt kettle heaters, etc.)Sullair Portable Compressor OP Operation Start: , Design Capacity:
168764 290 - Other combustion - Fuel Comb. Equipment (includes
space heaters, asphalt kettle heaters, etc.)Big Blue Trash Pump OP Operation Start: , Design Capacity:
168765 290 - Other combustion - Fuel Comb. Equipment (includes
space heaters, asphalt kettle heaters, etc.)Case Backhoe OP Operation Start: , Design Capacity:
168769 490 - Other evaporative sources Acrylic OP Operation Start: , Design Capacity:
168770 690 - Other process equipment Anaerobic Digester 4 (Floating Cover)PS in 2023 Operation Start: 01/01/2021, Design Capacity:
Comment: Combining this w ith the Overall Treatment Process, since it's part of treatment process-related f ugitive emissions. Accounted for in that EF calculation.
168771 690 - Other process equipment Anaerobic Digester 2 (Floating Cover)PS in 2023 Operation Start: , Design Capacity:
Comment: Combining this w ith the Overall Treatment Process, since it's part of treatment process-related f ugitive emissions. Accounted for in that EF calculation.
168772 690 - Other process equipment Anaerobic Digester 3 (Floating Cover)PS in 2023 Operation Start: 01/01/2021, Design Capacity:
Comment: Combining this w ith the Overall Treatment Process, since it's part of treatment process-related f ugitive emissions. Accounted for in that EF calculation.
168773 690 - Other process equipment Anaerobic Digester 5 (Floating Cover)PS in 2023 Operation Start: , Design Capacity:
Comment: Combining this w ith the Overall Treatment Process, since it's part of treatment process-related f ugitive emissions. Accounted for in that EF calculation.
168774 690 - Other process equipment Anaerobic Digester 1 (Floating Cover)PS in 2023 Operation Start: , Design Capacity:
Comment: Combining this w ith the Overall Treatment Process, since it's part of treatment process-related f ugitive emissions. Accounted for in that EF calculation.
168779 290 - Other combustion - Fuel Comb. Equipment (includes
space heaters, asphalt kettle heaters, etc.)Waste Oil Burner Maintenance OP Operation Start: , Design Capacity:
168784 290 - Other combustion - Fuel Comb. Equipment (includes
space heaters, asphalt kettle heaters, etc.)Waste Oil Burner Truck Barn OP Operation Start: , Design Capacity:
169159 490 - Other evaporative sources Epoxy OP Operation Start: , Design Capacity:
174104 290 - Other combustion - Fuel Comb. Equipment (includes
space heaters, asphalt kettle heaters, etc.)John Deere Tractors OP Operation Start: , Design Capacity:
Comment: Count already accounted for in throughput.
174272 490 - Other evaporative sources Aerosols OP Operation Start: , Design Capacity:
174276 490 - Other evaporative sources Thinner OP Operation Start: , Design Capacity:
181164 390 - Other f ugitive - Fugitive Areas Aerated-Static Compost Piles OP Operation Start: , Design Capacity:
Comment: Count already accounted for in throughput.
8/64
181195 640 - Mixer or Blender - Process Equipment Peterbuilt Truck (Rotomix)OP Operation Start: , Design Capacity:
Additional Information: Equipment Count: 1
181196 790 - Other bulk material equipment - BMH Equipment Cover Placement Machine (Tarp Winder)OP Operation Start: , Design Capacity:
Additional Information: Equipment Count: 1
181197 760 - Conveyor - BMH Equipment McCloskey Trommel Compost Screener OP Operation Start: , Design Capacity:
181203 350 - Process Equipment Fugitive Leaks - Fugitive Areas Belt Filter Presses PS in 2023 Operation Start: , Design Capacity:
Comment: Combining this w ith the Overall Treatment Process, since it's part of treatment process-related f ugitive emissions. Accounted for in that EF calculation.
181207 290 - Other combustion - Fuel Comb. Equipment (includes
space heaters, asphalt kettle heaters, etc.)RSS #9 standby diesel f ueled engine generator OP Operation Start: , Design Capacity: 896.0 HP
Additional Information: Equipment Count: 1
181208 290 - Other combustion - Fuel Comb. Equipment (includes
space heaters, asphalt kettle heaters, etc.)RSS #11 standby diesel f ueled engine generator OP Operation Start: , Design Capacity: 896.0 HP
Additional Information: Equipment Count: 1
181209 290 - Other combustion - Fuel Comb. Equipment (includes
space heaters, asphalt kettle heaters, etc.)Admin #10 standby diesel fueled engine generator OP Operation Start: , Design Capacity: 349.0 HP
Additional Information: Equipment Count: 1
181213 OHMT - Off Highw ay Mobile Tailpipe Skid Steer Loaders OP Operation Start: , Design Capacity:
Comment: Count already accounted for in throughput.
185524 400 - Storage Tank - Evaporative Sources Sludge Equalization Tank PS in 2023 Operation Start: , Design Capacity: 359,088.0 GAL
Comment: Combining this w ith the Overall Treatment Process, since it's part of treatment process-related f ugitive emissions. Accounted for in that EF calculation.
185529 290 - Other combustion - Fuel Comb. Equipment (includes
space heaters, asphalt kettle heaters, etc.)Waste Oil Burner Dew atering Equipment Barn OP Operation Start: 01/01/2015, Design Capacity:
185531 400 - Storage Tank - Evaporative Sources Digested Sludge Blend Tank PS in 2023 Operation Start: , Design Capacity: 426,417.0 GAL
Comment: Combining this w ith the Overall Treatment Process, since it's part of treatment process-related f ugitive emissions. Accounted for in that EF calculation.
185573 160 - Reciprocating IC Engine - Fuel Comb. Equipment Pow er Gen #6 Standby diesel fueled engine generator OP in 2018 Operation Start: , Design Capacity: 805.0 HP
185574 160 - Reciprocating IC Engine - Fuel Comb. Equipment Pow er Gen #7 Standby diesel fueled engine generator OP in 2018 Operation Start: , Design Capacity: 800.0 HP
185604 280 - Flare - Fuel Comb. Equipment Gas System Waste Gas Flares OP Operation Start: 09/01/2020, Design Capacity:
Comment: Count already accounted for in throughput.
185615 160 - Reciprocating IC Engine - Fuel Comb. Equipment Jenbacher IC Engine 1 OP Operation Start: 11/22/2019, Design Capacity: 2,509.0 HP
Additional Information: Equipment Count: 1
185617 160 - Reciprocating IC Engine - Fuel Comb. Equipment Jenbacher IC Engine 2 OP Operation Start: 07/21/2020, Design Capacity: 2,509.0 HP
185624 160 - Reciprocating IC Engine - Fuel Comb. Equipment Headw orks #12 Standby diesel f ueled engine generator OP Operation Start: 05/08/2020, Design Capacity: 1,341.0 HP
185625 160 - Reciprocating IC Engine - Fuel Comb. Equipment Headw orks #13 Standby diesel f ueled engine generator OP Operation Start: 01/05/2021, Design Capacity: 1,341.0 HP
185652 400 - Storage Tank - Evaporative Sources Diesel Fuel Storage Tanks OP in 2017 Operation Start: , Design Capacity: 18,000.0 GAL
Comment: Count already accounted for in throughput.
185667 100 - Boiler - Fuel Comb. Equipment KBC Boiler (South)OP Operation Start: , Design Capacity: 6.28 E6BTU/HR
ID Type Description Status Details
9/64
185668
300 - Open Air Fugitive Source - Fugitive Areas (Landfills,
Runw ays, Feedlots, Settling Ponds, WWTreatment units,
Equipment Leaks, Haul Roads etc.)
Unpaved Roads OP Operation Start: 01/01/2020, Design Capacity:
185718 OHMT - Off Highw ay Mobile Tailpipe Telehandler OP Operation Start: 03/01/2019, Design Capacity:
185719 790 - Other bulk material equipment - BMH Equipment Go Bagger OP in 2022 Operation Start: 01/01/2013, Design Capacity:
Additional Information: Equipment Count: 1
185720 OHMT - Off Highw ay Mobile Tailpipe Mini Excavator OP Operation Start: 04/03/2019, Design Capacity:
185721 OHMT - Off Highw ay Mobile Tailpipe Boom Truck OP Operation Start: 01/01/1995, Design Capacity:
185723 OHMT - Off Highw ay Mobile Tailpipe Service Trucks OP Operation Start: 01/01/2001, Design Capacity:
Comment: Count already accounted for in throughput.
185724 OHMT - Off Highw ay Mobile Tailpipe Kubota Tractor OP Operation Start: 12/01/2018, Design Capacity:
185725 OHMT - Off Highw ay Mobile Tailpipe On-site Pickup Trucks OP Operation Start: 10/31/2016, Design Capacity:
Comment: Count already accounted for in throughput.
185726 OHMT - Off Highw ay Mobile Tailpipe JLG Lif t OP Operation Start: 01/01/2004, Design Capacity:
185727 290 - Other combustion - Fuel Comb. Equipment (includes
space heaters, asphalt kettle heaters, etc.)Pow er Wash Trailers OP Operation Start: 01/01/2012, Design Capacity:
Comment: Count already accounted for in throughput.
185728 OHMT - Off Highw ay Mobile Tailpipe Vermeer Vactor Trailer OP Operation Start: 12/28/2016, Design Capacity:
185729 OHMT - Off Highw ay Mobile Tailpipe Grove Crane Truck OP Operation Start: 03/01/2018, Design Capacity:
185730 OHMT - Off Highw ay Mobile Tailpipe MadVac Sw eeper PS in 2023 Operation Start: 01/01/2023, Design Capacity:
185732 290 - Other combustion - Fuel Comb. Equipment (includes
space heaters, asphalt kettle heaters, etc.)Godw in Trash Pumps OP Operation Start: 10/01/2019, Design Capacity:
Comment: Count already accounted for in throughput.
185733 400 - Storage Tank - Evaporative Sources Unleaded Fuel Storage Tank OP Operation Start: 01/01/2017, Design Capacity: 2,000.0 GAL
185954 1773 - Waste Water Lif t Station - POTW unit type Wastew ater Treatment Process OP Operation Start: 01/01/1985, Design Capacity:
186373 160 - Reciprocating IC Engine - Fuel Comb. Equipment Jenbacher IC Engine 3 OP in 2021 Operation Start: 07/06/2021, Design Capacity: 2,509.0 HP
Additional Information: Equipment Count: 1
186377 OHMT - Off Highw ay Mobile Tailpipe Yamaha ATV OP in 2021 Operation Start: 01/01/2021, Design Capacity:
186664 160 - Reciprocating IC Engine - Fuel Comb. Equipment Jenbacher IC Engine 4 OP in 2022 Operation Start: 01/27/2022, Design Capacity: 2,509.0 HP
Additional Information: Equipment Count: 1
186665 OHMT - Off Highw ay Mobile Tailpipe On-site Diesel Pickup Trucks OP in 2022 Operation Start: 06/30/2021, Design Capacity:
Comment: Count already accounted for in throughput.
187449 390 - Other f ugitive - Fugitive Areas Green Waste Pile OP in 2023 Operation Start: 01/01/2023, Design Capacity:
ID Type Description Status Details
10/64
UNIT PROCESSES
Emission Unit ID Unit Process ID SCC Description Status Details
3959
Burnham Boiler
(North)
1 10200603 Burnham Boiler (North)OP
Control Approach
Controlled?: No
Description: No Process Controls
Release Point Apportionment:
184140 - Burnham Boiler Stack (North): 100.0%
21903
Portable
Generators/Welders
and Other Small Gas
Equipment
1 2265006025 Portable Generators/Welders and Other Small Gas Equipment OP
Control Approach
Controlled?: No
Description: No Process Controls
Release Point Apportionment:
947008 - Portable Generators/Welders and Other Small Gas Equipment: 100.0%
168759
Scarab (Compost
Turner)
1 2270003050 Scarab (Compost Turner)OP
Control Approach
Controlled?: No
Description: No Process Controls
Release Point Apportionment:
948576 - Scarab (Compost Turner): 100.0%
168760
Peterson Wood
Grinder
1 2270003050 Peterson Wood Grinder OP
Control Approach
Controlled?: No
Description: No Process Controls
Release Point Apportionment:
948577 - Peterson Wood Grinder: 100.0%
168763
Sullair Portable
Compressor
1 2270006015 Sullair Portable Compressor OP
Control Approach
Controlled?: No
Description: No Process Controls
Release Point Apportionment:
948580 - Sullair Portable Compressor: 100.0%
168764
Big Blue Trash Pump 1 2270006010 Big Blue Trash Pump OP
Control Approach
Controlled?: No
Description: No Process Controls
Release Point Apportionment:
948581 - Big Blue Trash Pump: 100.0%
168765
Case Backhoe 1 2270002066 Case Backhoe OP
Control Approach
Controlled?: No
Description: No Process Controls
Release Point Apportionment:
948582 - Case Backhoe: 100.0%
168769
Acrylic 1 40200201 Acrylic OP
Control Approach
Controlled?: No
Description: No Process Controls
Release Point Apportionment:
948586 - Acrylic: 100.0%
11/64
168770
Anaerobic Digester 4
(Floating Cover)
1 20300706 Anaerobic Digester 4 (Floating Cover)PS in 2023
Control Approach
Controlled?: No
Description: No Process Controls
Release Point Apportionment:
948591 - Anaerobic Digester 4 (Floating Cover) Gap: 100.0%
Comment: Combining this w ith the Overall Treatment Process, since it's part of treatment process-related fugitive emissions. Accounted for in that EF calculation.
168771
Anaerobic Digester 2
(Floating Cover)
1 20300706 Anaerobic Digester 2 (Floating Cover)PS in 2023
Control Approach
Controlled?: No
Description: No Process Controls
Release Point Apportionment:
948588 - Anaerobic Digester 2 (Floating Cover) Gap: 100.0%
Comment: Combining this w ith the Overall Treatment Process, since it's part of treatment process-related fugitive emissions. Accounted for in that EF calculation.
168772
Anaerobic Digester 3
(Floating Cover)
1 20300706 Anaerobic Digester 3 (Floating Cover)PS in 2023
Control Approach
Controlled?: No
Description: No Process Controls
Release Point Apportionment:
948589 - Anaerobic Digester 3 (Floating Cover) Gap: 100.0%
Comment: Combining this w ith the Overall Treatment Process, since it's part of treatment process-related fugitive emissions. Accounted for in that EF calculation.
168773
Anaerobic Digester 5
(Floating Cover)
1 20300706 Anaerobic Digester 5 (Floating Cover)PS in 2023
Control Approach
Controlled?: No
Description: No Process Controls
Release Point Apportionment:
967175 - Anaerobic Digester 5 (Floating Cover) Gap: 100.0%
Comment: Combining this w ith the Overall Treatment Process, since it's part of treatment process-related fugitive emissions. Accounted for in that EF calculation.
168774
Anaerobic Digester 1
(Floating Cover)
1 20300706 Anaerobic Digester 1 (Floating Cover)PS in 2023
Control Approach
Controlled?: No
Description: No Process Controls
Release Point Apportionment:
948587 - Anaerobic Digester 1 (Floating Cover) Gap: 100.0%
Comment: Combining this w ith the Overall Treatment Process, since it's part of treatment process-related fugitive emissions. Accounted for in that EF calculation.
168779
Waste Oil Burner
Maintenance
1 10500113 Waste Oil Burner Maintenance OP
Control Approach
Controlled?: No
Description: No Process Controls
Release Point Apportionment:
17032 - Waste Oil Burner Maintenance: 100.0%
168784
Waste Oil Burner
Truck Barn
1 10500113 Waste Oil Burner Truck Barn OP
Control Approach
Controlled?: No
Description: No Process Controls
Release Point Apportionment:
948601 - Waste Oil Burner Truck Barn: 100.0%
Emission Unit ID Unit Process ID SCC Description Status Details
12/64
169159
Epoxy 1 40200101 Epoxy OP
Control Approach
Controlled?: No
Description: No Process Controls
Release Point Apportionment:
948969 - Epoxy: 100.0%
174104
John Deere Tractors 1 2270002066 John Deere Tractors OP
Control Approach
Controlled?: No
Description: No Process Controls
Release Point Apportionment:
953828 - John Deere Tractors: 100.0%
174272
Aerosols 1 40200101 Aerosols OP
Control Approach
Controlled?: No
Description: No Process Controls
Release Point Apportionment:
925064 - Aerosols: 100.0%
174276
Thinner 1 40200201 Thinner OP
Control Approach
Controlled?: No
Description: No Process Controls
Release Point Apportionment:
925086 - Thinner: 100.0%
181164
Aerated-Static
Compost Piles
1 50100407 Aerated-Static Compost Piles OP
Control Approach
Controlled?: Yes
Description: micro-pore cover
Control Devices:
1 - Compost Micro-pore cover
Release Point Apportionment:
967043 - Aerated-Static Compost Piles: 100.0%
181195
Peterbuilt Truck
(Rotomix)
1 2270003050 Peterbuilt Truck (Rotomix)OP
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
967070 - Peterbuilt Truck (Rotomix): 100.0%
181196
Cover Placement
Machine (Tarp
Winder)
1 2270003050 Cover Placement Machine (Tarp Winder)OP
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
967159 - Cover Placement Machine (Tarp Winder): 100.0%
181197
McCloskey Trommel
Compost Screener
1 2270003050 McCloskey Trommel Compost Screener OP
Control Approach
Controlled?: No
Description: compost screener
Release Point Apportionment:
967160 - McCloskey Trommel Compost Screener: 100.0%
Emission Unit ID Unit Process ID SCC Description Status Details
13/64
181203
Belt Filter Presses 1 50100769 Belt Filter Presses (3) sludge dew atering PS in 2023
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
967161 - Belt Filter Presses (3): 100.0%
Comment: Combining this w ith the Overall Treatment Process, since it's part of treatment process-related fugitive emissions. Accounted for in that EF calculation.
181207
RSS #9 standby
diesel fueled engine
generator
1 20200401 RSS #9 Standby diesel fueled engine generator OP
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
181601 - RSS #9 Standby generator Stack: 100.0%
181208
RSS #11 standby
diesel fueled engine
generator
1 20200401 RSS #11 Standby diesel fueled engine generator OP
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
181602 - RSS #11 Standby generator Stack: 100.0%
181209
Admin #10 standby
diesel fueled engine
generator
1 20300101 Admin #10 Standby diesel f ueled engine generator OP
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
181603 - Admin #10 Standby generator Stack: 100.0%
181213
Skid Steer Loaders 1 2270002072 Skid Steer Loaders OP
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
967152 - Skid Steer Loaders: 100.0%
185529
Waste Oil Burner
Dew atering
Equipment Barn
1 10500113 Waste Oil Burner Dew atering Equipment Barn OP
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
970929 - Waste Oil Burner Dew atering Equipment Barn: 100.0%
185573
Pow er Gen #6
Standby diesel
f ueled engine
generator
1 20200401 Pow er Gen #6 Standby diesel fueled engine generator OP
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
184182 - Pow er Gen #6 Standby Generator Stack: 100.0%
185574
Pow er Gen #7
Standby diesel
f ueled engine
generator
1 20200401 Pow er Gen #7 Standby diesel fueled engine generator OP
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
184183 - Pow er Gen #7 Standby Generator Stack: 100.0%
Emission Unit ID Unit Process ID SCC Description Status Details
14/64
185604
Gas System Waste
Gas Flares
1 50100410 Gas System Waste Gas Flares OP
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
184141 - Gas System Waste Gas Flares: 100.0%
185615
Jenbacher IC Engine
1
1 20200702 Jenbacher IC Engine 1 Digester Gas OP
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
184138 - Jenbacher IC Engine 1 Stack: 100.0%
Comment: Used Blended Digester and Natural Gas. Blend is accounted for in EF.
185617
Jenbacher IC Engine
2
1 20200702 Jenbacher IC Engine 2 Digester Gas OP
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
184139 - Jenbacher IC Engine 2 Stack: 100.0%
Comment: Used Blended Digester and Natural Gas. Blend is accounted for in EF.
185624
Headw orks #12
Standby diesel
f ueled engine
generator
1 20200401 Headw orks #12 Standby diesel f ueled engine generator OP
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
184192 - Headw orks #12 Standby diesel f ueled engine generator: 100.0%
185625
Headw orks #13
Standby diesel
f ueled engine
generator
1 20200401 Headw orks #13 Standby diesel f ueled engine generator OP
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
184193 - Headw orks #13 Standby diesel f ueled engine generator: 100.0%
185652
Diesel Fuel Storage
Tanks
1 40400414 Diesel Fuel Storage Tanks - Working Loss OP
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
971071 - Diesel Fuel Storage Tanks: 100.0%
Comment: Not actually underground.
185652
Diesel Fuel Storage
Tanks
2 40400413 Diesel Fuel Storage Tanks - Standing Loss OP in 2023
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
971071 - Diesel Fuel Storage Tanks: 100.0%
Emission Unit ID Unit Process ID SCC Description Status Details
15/64
185667
KBC Boiler (South)1 10200603 KBC Boiler (South)OP
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
952 - KBC Boiler Stack (South): 100.0%
185668
Unpaved Roads 1 50100401 Unpaved Roads OP
Control Approach
Controlled?: Yes
Description: Dust Wetting
Control Devices:
2 - Dust Suppression by Watering and Calcium Chloride
Release Point Apportionment:
970914 - Unpaved Roads: 100.0%
185718
Telehandler 1 2270003010 Telehandler OP
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
970931 - Telehandler: 100.0%
185719
Go Bagger 1 2270003050 Go Bagger OP in 2022
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
970934 - Go Bagger: 100.0%
185720
Mini Excavator 1 2270005055 Mini Excavator OP
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
970994 - Mini Excavator: 100.0%
185721
Boom Truck 1 2230072370 Boom Truck OP
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
970995 - Boom Truck: 100.0%
185723
Service Trucks 1 2201070370 Service Trucks OP
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
970997 - Service Trucks: 100.0%
185723
Service Trucks 2 2230072370 Service Trucks OP in 2023
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
970997 - Service Trucks: 100.0%
Emission Unit ID Unit Process ID SCC Description Status Details
16/64
185724
Kubota Tractor 1 2270005015 Kubota Tractor OP
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
970998 - Kubota Tractor: 100.0%
185725
On-site Pickup
Trucks
1 2201020370 On-site Pickup Trucks OP
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
971000 - On-site Pickup Trucks: 100.0%
185726
JLG Lif t 1 2265003010 JLG Lift OP
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
971001 - JLG Lif t: 100.0%
185727
Pow er Wash Trailers 1 2265006030 Pow er Wash Trailers (Unleaded)OP
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
971002 - Pow er Wash Trailers: 100.0%
185727
Pow er Wash Trailers 2 2270006030 Pow er Wash Trailers (Diesel)OP
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
971002 - Pow er Wash Trailers: 100.0%
185727
Pow er Wash Trailers 3 2267006030 Pow er Wash Trailers (Propane)OP in 2023
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
971002 - Pow er Wash Trailers: 100.0%
185728
Vermeer Vactor
Trailer
1 2270006035 Vermeer Vactor Trailer OP
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
971003 - Vermeer Vactor Trailer: 100.0%
185729
Grove Crane Truck 1 2270002045 Grove Crane Truck OP
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
971004 - Grove Crane Truck: 100.0%
Emission Unit ID Unit Process ID SCC Description Status Details
17/64
185730
MadVac Sw eeper 1 2270003030 MadVac Sw eeper PS in 2023
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
971005 - MadVac Sw eeper: 100.0%
Comment: Sold
185732
Godw in Trash
Pumps
1 2270006010 Godw in Trash Pumps OP
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
970999 - Godw in Trash Pumps: 100.0%
185733
Unleaded Fuel
Storage Tank
1 40400406 Unleaded Fuel Storage Tank - Working Loss OP
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
971113 - Unleaded Fuel Storage Tank: 100.0%
Comment: Not actually underground
185733
Unleaded Fuel
Storage Tank
2 40400405 Unleaded Fuel Storage Tanks - Standing Loss OP in 2023
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
971113 - Unleaded Fuel Storage Tank: 100.0%
185954
Wastew ater
Treatment Process
1 50100701 Wastew ater Treatment Process OP
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
971247 - Wastew ater Treatment Process Fugitive Emissions: 100.0%
Comment: Some process emissions routed through biofilter, w hich is already accounted for in that EF calculation.
186373
Jenbacher IC Engine
3
1 20200702 Jenbacher IC Engine 3 Digester Gas OP in 2021
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
184456 - Jenbacher IC Engine 3 Stack: 100.0%
Comment: Used Blended Digester and Natural Gas. Blend is accounted for in EF.
186377
Yamaha ATV 1 2265001030 Yamaha ATV OP in 2021
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
971519 - Yamaha ATV: 100.0%
Emission Unit ID Unit Process ID SCC Description Status Details
18/64
186664
Jenbacher IC Engine
4
1 20200702 Jenbacher IC Engine 4 Digester Gas OP in 2022
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
184620 - Jenbacher IC Engine 4 Stack: 100.0%
Comment: Used Blended Digester and Natural Gas. Blend is accounted for in EF.
186665
On-site Diesel Pickup
Trucks
1 2230072370 On-site Diesel Pickup Trucks OP in 2022
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
971634 - On-site Diesel Pickup Trucks: 100.0%
187449
Green Waste Pile 1 50100407 Green Waste Pile OP in 2023
Control Approach
Controlled?: No
Description:
Release Point Apportionment:
971996 - Green Waste Pile: 100.0%
Emission Unit ID Unit Process ID SCC Description Status Details
19/64
PROCESS EMISSIONS
Emission Unit ID Unit Process ID Throughput Operations
3959
Burnham Boiler
(North)
1
Burnham Boiler
(North)
Annual Throughput: 3.53 MILLION CUBIC FEET (Natural Gas) (Input)
Start Time: 12:00 AM, Stop Time: 11:59 PM
Average Hours/Day: 24.0, Days/Week: 5.0, Weeks/Year: 26.0
Actual Days/Year: 130.0
Actual Hours/Year: 3,120.0
Monthly Operations: Jan: 23.0%, Feb: 25.0%, Mar: 9.6%, Apr: 1.9%, May: 0.0%, Jun: 0.0%, Jul: 0.0%, Aug:
0.0%, Sep: 0.0%, Oct: 7.5%, Nov: 11.2%, Dec: 21.8%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)7.6 E6FT3 - MILLION CUBIC FEET 8_2 - EPA WebFIRE Emission Factor (pre-control)0.013413999999999
Overall Control Efficiency: 0.0%
PM10-FIL - PM10 Filterable 1.9 E6FT3 - MILLION CUBIC FEET 8_2 - EPA WebFIRE Emission Factor (pre-control)0.003353499999999
Overall Control Efficiency: 0.0%
PM25-PRI - PM2.5 Primary (Filt + Cond)7.6 E6FT3 - MILLION CUBIC FEET 8_2 - EPA WebFIRE Emission Factor (pre-control)0.013413999999999
Overall Control Efficiency: 0.0%
PM25-FIL - PM2.5 Filterable 1.9 E6FT3 - MILLION CUBIC FEET 8_2 - EPA WebFIRE Emission Factor (pre-control)0.003353499999999
Overall Control Efficiency: 0.0%
PM-CON - PM Condensible 5.7 E6FT3 - MILLION CUBIC FEET 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0100605
Overall Control Efficiency: 0.0%
SO2 - Sulf ur Dioxide 1.5 E6FT3 - MILLION CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.0026475
Overall Control Efficiency: 0.0%
Emission Comment: calculated using NG sulfur content
NOX - Nitrogen Oxides 100.0 E6FT3 - MILLION CUBIC FEET 8_2 - EPA WebFIRE Emission Factor (pre-control)0.1765
Overall Control Efficiency: 0.0%
VOC - Volatile Organic Compounds 5.5 E6FT3 - MILLION CUBIC FEET 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0097075
Overall Control Efficiency: 0.0%
CO - Carbon Monoxide 84.0 E6FT3 - MILLION CUBIC FEET 8_2 - EPA WebFIRE Emission Factor (pre-control)0.14826
Overall Control Efficiency: 0.0%
NH3 - Ammonia 3.2 E6FT3 - MILLION CUBIC FEET 8_2 - EPA WebFIRE Emission Factor (pre-control)0.005647999999999
Overall Control Efficiency: 0.0%
Emission Unit ID Unit Process ID Throughput Operations
20/64
21903
Portable
Generators/Welder
s and Other Small
Gas Equipment
1
Portable
Generators/Welder
s and Other Small
Gas Equipment
Annual Throughput: 59.2 GALLONS (Gasoline) (Input)
Start Time: 08:00 AM, Stop Time: 04:00 PM
Average Hours/Day: 2.0, Days/Week: 2.0, Weeks/Year: 20.0
Actual Days/Year: 40.0
Actual Hours/Year: 80.0
Monthly Operations: Jan: 9.1%, Feb: 7.4%, Mar: 8.7%, Apr: 8.9%, May: 8.6%, Jun: 8.4%, Jul: 6.8%, Aug:
12.3%, Sep: 6.9%, Oct: 6.6%, Nov: 9.3%, Dec: 6.9%
Emission Unit ID Unit Process ID Throughput Operations
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.002323702421 GAL - GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000068781591661
Overall Control Efficiency: 0.0%
Emission Comment: Non-road SCC value 2265006025
PM25-PRI - PM2.5 Primary (Filt + Cond)0.0021378062273 GAL - GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000063279064328
Overall Control Efficiency: 0.0%
Emission Comment: Non-road SCC value 2265006025
SO2 - Sulf ur Dioxide 0.00035534147925 GAL - GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000010518107785
Overall Control Efficiency: 0.0%
Emission Comment: Non-road SCC value 2265006025
NOX - Nitrogen Oxides 0.051015966206 GAL - GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.001510072599697
Overall Control Efficiency: 0.0%
Emission Comment: Non-road SCC value 2265006025
VOC - Volatile Organic Compounds 0.093305792205 GAL - GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.002761851449268
Overall Control Efficiency: 0.0%
Emission Comment: Non-road SCC value 2265006025
CO - Carbon Monoxide 4.3680657701 GAL - GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.12929474679496
Overall Control Efficiency: 0.0%
Emission Comment: Non-road SCC value 2265006025
Emission Unit ID Unit Process ID Throughput Operations
168759
Scarab (Compost
Turner)
1
Scarab (Compost
Turner)
Annual Throughput: 600.0 GALLONS (Distillate Oil (Diesel)) (Input)
Start Time: 09:00 AM, Stop Time: 12:00 PM
Average Hours/Day: 1.0, Days/Week: 2.0, Weeks/Year: 50.0
Actual Days/Year: 100.0
Actual Hours/Year: 100.0
Monthly Operations: Jan: 7.1%, Feb: 6.0%, Mar: 9.7%, Apr: 7.5%, May: 10.5%, Jun: 8.2%, Jul: 9.5%, Aug:
10.7%, Sep: 11.2%, Oct: 6.2%, Nov: 7.1%, Dec: 6.3%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.0065 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00195
21/64
Emission Comment: Non-road Tier 3
PM25-PRI - PM2.5 Primary (Filt + Cond)0.006 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.0018
Emission Comment: Non-road Tier 3
SO2 - Sulf ur Dioxide 0.0002 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00006
Emission Comment: SO2 calculated from fuel sulfur content
NOX - Nitrogen Oxides 0.1236 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.037079999999999
Emission Comment: Non-road Tier 3
VOC - Volatile Organic Compounds 0.0065 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00195
Emission Comment: Non-road Tier 3
CO - Carbon Monoxide 0.1138 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.03414
Emission Comment: Non-road Tier 3
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
Emission Unit ID Unit Process ID Throughput Operations
168760
Peterson Wood
Grinder
1
Peterson Wood
Grinder
Annual Throughput: 1,900.0 GALLONS (Distillate Oil (Diesel)) (Input)
Start Time: 07:00 AM, Stop Time: 04:00 PM
Average Hours/Day: 5.0, Days/Week: 1.0, Weeks/Year: 20.0
Actual Days/Year: 20.0
Actual Hours/Year: 100.0
Monthly Operations: Jan: 7.1%, Feb: 6.0%, Mar: 9.7%, Apr: 7.5%, May: 10.5%, Jun: 8.2%, Jul: 9.5%, Aug:
10.7%, Sep: 11.2%, Oct: 6.2%, Nov: 7.1%, Dec: 6.3%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.0065 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.006175
Emission Comment: Non-road Tier 2 emissions
PM25-PRI - PM2.5 Primary (Filt + Cond)0.006 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.0057
Emission Comment: Non-road Tier 2 emissions
SO2 - Sulf ur Dioxide 0.0002 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00019
Emission Comment: SO2 calculated from fuel sulfur content
NOX - Nitrogen Oxides 0.1978 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.18791
Emission Comment: Non-road Tier 2 emissions
VOC - Volatile Organic Compounds 0.0104 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.009879999999999
Emission Comment: Non-road Tier 2 emissions
CO - Carbon Monoxide 0.1138 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.10811
Emission Comment: Non-road Tier 2 emissions
Emission Unit ID Unit Process ID Throughput Operations
22/64
168763
Sullair Portable
Compressor
1
Sullair Portable
Compressor
Annual Throughput: 33.0 GALLONS (Distillate Oil (Diesel)) (Input)
Start Time: 08:30 AM, Stop Time: 10:30 AM
Average Hours/Day: 2.0, Days/Week: 1.0, Weeks/Year: 20.0
Actual Days/Year: 20.0
Actual Hours/Year: 40.0
Monthly Operations: Jan: 7.1%, Feb: 6.0%, Mar: 9.7%, Apr: 7.5%, May: 10.5%, Jun: 8.2%, Jul: 9.5%, Aug:
10.7%, Sep: 11.2%, Oct: 6.2%, Nov: 7.1%, Dec: 6.3%
Emission Unit ID Unit Process ID Throughput Operations
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.013 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.0002145
Emission Comment: Non-road Tier 2 emissions
PM25-PRI - PM2.5 Primary (Filt + Cond)0.012 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.000198
Emission Comment: Non-road Tier 2 emissions
SO2 - Sulf ur Dioxide 0.0002 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.0000033
Emission Comment: SO2 calculated from fuel sulfur content
NOX - Nitrogen Oxides 0.2317 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.003823049999999
Emission Comment: Non-road Tier 2 emissions
VOC - Volatile Organic Compounds 0.0122 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.0002013
Emission Comment: Non-road Tier 2 emissions
CO - Carbon Monoxide 0.1626 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.0026829
Emission Comment: Non-road Tier 2 emissions
Emission Unit ID Unit Process ID Throughput Operations
168764
Big Blue Trash
Pump
1
Big Blue Trash
Pump
Annual Throughput: 200.1 GALLONS (Distillate Oil (Diesel)) (Input)
Start Time: 08:00 AM, Stop Time: 04:00 PM
Average Hours/Day: 5.0, Days/Week: 1.0, Weeks/Year: 4.0
Actual Days/Year: 4.0
Actual Hours/Year: 20.0
Monthly Operations: Jan: 7.1%, Feb: 6.0%, Mar: 9.7%, Apr: 7.5%, May: 10.5%, Jun: 8.2%, Jul: 9.5%, Aug:
10.7%, Sep: 11.2%, Oct: 6.2%, Nov: 7.1%, Dec: 6.3%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.016006832324 GAL - GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.001601483574016
Overall Control Efficiency: 0.0%
Emission Comment: Non-road SCC value 2270006010
PM25-PRI - PM2.5 Primary (Filt + Cond)0.015526627354 GAL - GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.001553439066767
Overall Control Efficiency: 0.0%
Emission Comment: Non-road SCC value 2270006010
SO2 - Sulf ur Dioxide 0.00020067329267 GAL - GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000020077362931
23/64
Overall Control Efficiency: 0.0%
Emission Comment: Non-road SCC value 2270006010
NOX - Nitrogen Oxides 0.19306128417 GAL - GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.019315781481208
Overall Control Efficiency: 0.0%
Emission Comment: Non-road SCC value 2270006010
VOC - Volatile Organic Compounds 0.02057296325 GAL - GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.002058324973162
Overall Control Efficiency: 0.0%
Emission Comment: Non-road SCC value 2270006010
CO - Carbon Monoxide 0.090531871105 GAL - GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.009057713704055
Overall Control Efficiency: 0.0%
Emission Comment: Non-road SCC value 2270006010
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
Emission Unit ID Unit Process ID Throughput Operations
168765
Case Backhoe
1
Case Backhoe
Annual Throughput: 37.5 GALLONS (Distillate Oil (Diesel)) (Input)
Start Time: 08:00 AM, Stop Time: 04:00 PM
Average Hours/Day: 1.0, Days/Week: 1.0, Weeks/Year: 20.0
Actual Days/Year: 20.0
Actual Hours/Year: 20.0
Monthly Operations: Jan: 7.2%, Feb: 7.4%, Mar: 9.9%, Apr: 7.0%, May: 9.7%, Jun: 8.5%, Jul: 9.5%, Aug:
9.5%, Sep: 6.3%, Oct: 6.0%, Nov: 7.7%, Dec: 11.4%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.013 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00024375
Emission Comment: Non-road Tier 2 emissions
PM25-PRI - PM2.5 Primary (Filt + Cond)0.012 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.000225
Emission Comment: Non-road Tier 2 emissions
SO2 - Sulf ur Dioxide 0.0002 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00000375
Emission Comment: SO2 calculated from fuel sulfur content
NOX - Nitrogen Oxides 0.2317 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.004344374999999
Emission Comment: Non-road Tier 2 emissions
VOC - Volatile Organic Compounds 0.0122 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00022875
Emission Comment: Non-road Tier 2 emissions
CO - Carbon Monoxide 0.1626 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00304875
Emission Comment: Non-road Tier 2 emissions
Emission Unit ID Unit Process ID Throughput Operations
24/64
168769
Acrylic
1
Acrylic
Annual Throughput: 90.0 GALLONS (Coating) (Input)
Start Time: 08:00 AM, Stop Time: 04:00 PM
Average Hours/Day: 8.0, Days/Week: 5.0, Weeks/Year: 50.0
Actual Days/Year: 250.0
Actual Hours/Year: 2,000.0
Monthly Operations: Jan: 8.1%, Feb: 7.7%, Mar: 8.8%, Apr: 8.1%, May: 8.5%, Jun: 8.5%, Jul: 8.1%, Aug:
8.8%, Sep: 8.5%, Oct: 8.1%, Nov: 8.5%, Dec: 8.5%
Emission Unit ID Unit Process ID Throughput Operations
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
VOC - Volatile Organic Compounds 2.0078 GAL - GALLONS 11_2 - Vendor Provided (pre-control EF)0.090351
Overall Control Efficiency: 0.0%
Emission Comment: based on volume-w eighted average of product VOC content
Emission Unit ID Unit Process ID Throughput Operations
168779
Waste Oil Burner
Maintenance
1
Waste Oil Burner
Maintenance
Annual Throughput: 3.155 1000 GALLONS (Waste Oil) (Input)
Supplemental Calculation Parameters
% Ash: 5.0, % Sulfur: 0.03
Start Time: 08:30 AM, Stop Time: 11:30 PM
Average Hours/Day: 10.9, Days/Week: 4.2, Weeks/Year: 27.0
Actual Days/Year: 116.0
Actual Hours/Year: 1,262.0
Monthly Operations: Jan: 23.0%, Feb: 22.3%, Mar: 19.7%, Apr: 10.5%, May: 0.1%, Jun: 0.0%, Jul: 0.0%,
Aug: 0.0%, Sep: 0.0%, Oct: 0.4%, Nov: 7.2%, Dec: 16.9%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)286.5 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.451953749999999
Overall Control Efficiency: 0.0%
PM10-FIL - PM10 Filterable 285.0 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.4495875
Overall Control Efficiency: 0.0%
PM25-PRI - PM2.5 Primary (Filt + Cond)229.2 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.361562999999999
Overall Control Efficiency: 0.0%
PM25-FIL - PM2.5 Filterable 227.7 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.359196749999999
Overall Control Efficiency: 0.0%
PM-CON - PM Condensible 1.5 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.00236625
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
SO2 - Sulf ur Dioxide 3.21 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.005063775
Overall Control Efficiency: 0.0%
NOX - Nitrogen Oxides 16.0 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.02524
Overall Control Efficiency: 0.0%
VOC - Volatile Organic Compounds 1.0 E3GAL - 1000 GALLONS 8_4 - EPA Emission Factor (pre-control)0.0015775
25/64
Overall Control Efficiency: 0.0%
CO - Carbon Monoxide 2.1 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.003312749999999
Overall Control Efficiency: 0.0%
7439921 - Lead 2.0 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.003155
Overall Control Efficiency: 0.0%
7440360 - Antimony 0.0045 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000007098749999
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
7440382 - Arsenic 0.06 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000094649999999
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
7440417 - Beryllium 0.0018 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000002839499999
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
7440439 - Cadmium 0.012 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.00001893
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
7440473 - Chromium 0.18 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.00028395
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
7440484 - Cobalt 0.0052 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000008202999999
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
84742 - Dibutyl Phthalate 0.000034 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000000053635
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
7439965 - Manganese 0.05 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000078875
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
91203 - Naphthalene 0.00094 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.00000148285
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
7440020 - Nickel 0.16 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0002524
Overall Control Efficiency: 0.0%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
26/64
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
108952 - Phenol 0.000028 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.00000004417
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
Emission Unit ID Unit Process ID Throughput Operations
168784
Waste Oil Burner
Truck Barn
1
Waste Oil Burner
Truck Barn
Annual Throughput: 0.46 1000 GALLONS (Waste Oil) (Input)
Supplemental Calculation Parameters
% Ash: 5.0, % Sulfur: 0.03
Start Time: 12:00 AM, Stop Time: 11:30 PM
Average Hours/Day: 4.3, Days/Week: 4.1, Weeks/Year: 13.0
Actual Days/Year: 53.0
Actual Hours/Year: 230.0
Monthly Operations: Jan: 23.0%, Feb: 22.3%, Mar: 19.7%, Apr: 10.5%, May: 0.1%, Jun: 0.0%, Jul: 0.0%,
Aug: 0.0%, Sep: 0.0%, Oct: 0.4%, Nov: 7.2%, Dec: 16.9%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)286.5 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.065894999999999
Overall Control Efficiency: 0.0%
PM10-FIL - PM10 Filterable 285.0 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.06555
Overall Control Efficiency: 0.0%
PM25-PRI - PM2.5 Primary (Filt + Cond)229.2 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.052716
Overall Control Efficiency: 0.0%
PM25-FIL - PM2.5 Filterable 227.7 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.052371
Overall Control Efficiency: 0.0%
PM-CON - PM Condensible 1.5 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000345
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
SO2 - Sulf ur Dioxide 3.21 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0007383
Overall Control Efficiency: 0.0%
NOX - Nitrogen Oxides 16.0 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.00368
Overall Control Efficiency: 0.0%
VOC - Volatile Organic Compounds 1.0 E3GAL - 1000 GALLONS 8_4 - EPA Emission Factor (pre-control)0.00023
Overall Control Efficiency: 0.0%
CO - Carbon Monoxide 2.1 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000483
Overall Control Efficiency: 0.0%
7439921 - Lead 2.0 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.00046
Overall Control Efficiency: 0.0%
7440360 - Antimony 0.0045 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000001034999999
27/64
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
7440382 - Arsenic 0.06 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0000138
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
7440417 - Beryllium 0.0018 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000000414
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
7440439 - Cadmium 0.012 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.00000276
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
7440473 - Chromium 0.18 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0000414
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
7440484 - Cobalt 0.0052 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000001196
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
84742 - Dibutyl Phthalate 0.000034 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.00000000782
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
7439965 - Manganese 0.05 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0000115
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
91203 - Naphthalene 0.00094 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0000002162
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
7440020 - Nickel 0.16 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0000368
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
108952 - Phenol 0.000028 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.00000000644
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
Emission Unit ID Unit Process ID Throughput Operations
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169159
Epoxy
1
Epoxy
Annual Throughput: 6.0 GALLONS (Coating) (Input)
Start Time: 08:00 AM, Stop Time: 05:00 PM
Average Hours/Day: 8.0, Days/Week: 5.0, Weeks/Year: 50.0
Actual Days/Year: 250.0
Actual Hours/Year: 2,000.0
Monthly Operations: Jan: 8.1%, Feb: 7.7%, Mar: 8.8%, Apr: 8.1%, May: 8.5%, Jun: 8.5%, Jul: 8.1%, Aug:
8.8%, Sep: 8.5%, Oct: 8.1%, Nov: 8.5%, Dec: 8.5%
Emission Unit ID Unit Process ID Throughput Operations
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
VOC - Volatile Organic Compounds 0.4703 GAL - GALLONS 11_2 - Vendor Provided (pre-control EF)0.0014109
Overall Control Efficiency: 0.0%
Emission Comment: based on volume-w eighted average of product VOC content
Emission Unit ID Unit Process ID Throughput Operations
174104
John Deere
Tractors
1
John Deere
Tractors
Annual Throughput: 3,432.3 GALLONS (Distillate Oil (Diesel)) (Input)
Start Time: 07:00 AM, Stop Time: 04:00 PM
Average Hours/Day: 5.5, Days/Week: 4.0, Weeks/Year: 50.0
Actual Days/Year: 200.0
Actual Hours/Year: 1,100.0
Monthly Operations: Jan: 7.1%, Feb: 6.0%, Mar: 9.7%, Apr: 7.5%, May: 10.5%, Jun: 8.2%, Jul: 9.5%, Aug:
10.7%, Sep: 11.2%, Oct: 6.2%, Nov: 7.1%, Dec: 6.3%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.0061 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.010468515
Emission Comment: Non-road Tier 1
PM25-PRI - PM2.5 Primary (Filt + Cond)0.0056 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00961044
Emission Comment: Non-road Tier 1
SO2 - Sulf ur Dioxide 0.0002 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00034323
Emission Comment: SO2 calculated from fuel sulfur content
NOX - Nitrogen Oxides 0.1453 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.249356595
Emission Comment: Non-road Tier 1
VOC - Volatile Organic Compounds 0.0183 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.031405545
Emission Comment: Non-road Tier 1
CO - Carbon Monoxide 0.1995 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.342371925
Emission Comment: Non-road Tier 1
Emission Unit ID Unit Process ID Throughput Operations
29/64
174272
Aerosols
1
Aerosols
Annual Throughput: 4.0 GALLONS (Coating) (Input)
Start Time: 08:00 AM, Stop Time: 04:00 AM
Average Hours/Day: 8.0, Days/Week: 5.0, Weeks/Year: 50.0
Actual Days/Year: 250.0
Actual Hours/Year: 2,000.0
Monthly Operations: Jan: 8.1%, Feb: 7.7%, Mar: 8.8%, Apr: 8.1%, May: 8.5%, Jun: 8.5%, Jul: 8.1%, Aug:
8.8%, Sep: 8.5%, Oct: 8.1%, Nov: 8.5%, Dec: 8.5%
Emission Unit ID Unit Process ID Throughput Operations
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
VOC - Volatile Organic Compounds 4.49 GAL - GALLONS 11_2 - Vendor Provided (pre-control EF)0.00898
Overall Control Efficiency: 0.0%
Emission Comment: based on product VOC content
Emission Unit ID Unit Process ID Throughput Operations
174276
Thinner
1
Thinner
Annual Throughput: 1.0 GALLONS (Coating) (Input)
Start Time: 08:00 AM, Stop Time: 05:00 PM
Average Hours/Day: 8.0, Days/Week: 5.0, Weeks/Year: 50.0
Actual Days/Year: 250.0
Actual Hours/Year: 2,000.0
Monthly Operations: Jan: 8.1%, Feb: 7.7%, Mar: 8.8%, Apr: 8.1%, May: 8.5%, Jun: 8.5%, Jul: 8.1%, Aug:
8.8%, Sep: 8.5%, Oct: 8.1%, Nov: 8.5%, Dec: 8.5%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
VOC - Volatile Organic Compounds 0.209 GAL - GALLONS 2_2 - Engineering Judgement (pre-control EF)0.000104499999999
Overall Control Efficiency: 0.0%
Emission Comment: based on volume-w eighted average of product VOC content f rom w ebsearch
Emission Unit ID Unit Process ID Throughput Operations
181164
Aerated-Static
Compost Piles
1
Aerated-Static
Compost Piles
Annual Throughput: 8,822.0 TONS (Sludge) (Input)
Start Time: 12:00 AM, Stop Time: 11:30 PM
Average Hours/Day: 24.0, Days/Week: 7.0, Weeks/Year: 52.0
Actual Days/Year: 365.0
Actual Hours/Year: 8,760.0
Monthly Operations: Jan: 10.4%, Feb: 10.4%, Mar: 6.6%, Apr: 6.5%, May: 14.1%, Jun: 3.5%, Jul: 10.2%,
Aug: 10.4%, Sep: 7.0%, Oct: 10.5%, Nov: 3.5%, Dec: 7.0%
Comment: compost is sludge mixed w ith w ood chips and heated in a static air-ventilated pile, emissions based on San Joaquin Valley "Compost Emission Factors" published September 2010. Throughput and emission f actor
are based on w et tons (including bulking agent).
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
VOC - Volatile Organic Compounds 1.78 TON - TONS 2_2 - Engineering Judgement (pre-control EF)0.392579
Overall Control Efficiency: 95.0%
Emission Comment: Table 1 of Compost Emission Factor Report, San Joaquin Valley APCD, Revised 3/21/2023
NH3 - Ammonia 2.93 TON - TONS 2_2 - Engineering Judgement (pre-control EF)12.92423
30/64
Overall Control Efficiency: 0.0%
Emission Comment: Table 1 of Compost Emission Factor Report, San Joaquin Valley APCD, Revised 3/21/2023
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
Emission Unit ID Unit Process ID Throughput Operations
181195
Peterbuilt Truck
(Rotomix)
1
Peterbuilt Truck
(Rotomix)
Annual Throughput: 810.3 GALLONS (Distillate Oil (Diesel)) (Input)
Start Time: 07:30 AM, Stop Time: 10:30 AM
Average Hours/Day: 8.0, Days/Week: 2.0, Weeks/Year: 31.3
Actual Days/Year: 62.5
Actual Hours/Year: 500.0
Monthly Operations: Jan: 7.1%, Feb: 6.0%, Mar: 9.7%, Apr: 7.5%, May: 10.5%, Jun: 8.2%, Jul: 9.5%, Aug:
10.7%, Sep: 11.2%, Oct: 6.2%, Nov: 7.1%, Dec: 6.3%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.0003 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.000121544999999
Emission Comment: Engine tag has PM value
PM25-PRI - PM2.5 Primary (Filt + Cond)0.0003 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.000121544999999
Emission Comment: Engine tag has PM value
SO2 - Sulf ur Dioxide 0.0002 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00008103
Emission Comment: SO2 calculated from fuel sulfur content
NOX - Nitrogen Oxides 0.0065 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.002633474999999
Emission Comment: Engine tag
VOC - Volatile Organic Compounds 0.0033 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.001336995
Emission Comment: On-road State EFs - Single Unit Short-haul Truck, assumed 10mi/gal
CO - Carbon Monoxide 0.0267 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.010817505
Emission Comment: On-road State EFs - Single Unit Short-haul Truck, assumed 10mi/gal
Emission Unit ID Unit Process ID Throughput Operations
181196
Cover Placement
Machine (Tarp
Winder)
1
Cover Placement
Machine (Tarp
Winder)
Annual Throughput: 20.0 GALLONS (Distillate Oil (Diesel)) (Input)
Start Time: 09:00 AM, Stop Time: 12:00 PM
Average Hours/Day: 5.0, Days/Week: 2.0, Weeks/Year: 40.0
Actual Days/Year: 80.0
Actual Hours/Year: 400.0
Monthly Operations: Jan: 7.1%, Feb: 6.0%, Mar: 9.7%, Apr: 7.5%, May: 10.5%, Jun: 8.2%, Jul: 9.5%, Aug:
10.7%, Sep: 11.2%, Oct: 6.2%, Nov: 7.1%, Dec: 6.3%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.0094 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.000094
Emission Comment: Engine Tag has PM Value
PM25-PRI - PM2.5 Primary (Filt + Cond)0.0087 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.000087
Emission Comment: Engine Tag has PM Value
SO2 - Sulf ur Dioxide 0.0002 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.000002
31/64
Emission Comment: SO2 calculated from fuel sulfur content
NOX - Nitrogen Oxides 0.1823 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.001823
Emission Comment: Engine Tag has NMHC/NOx Value
VOC - Volatile Organic Compounds 0.0096 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.000095999999999
Emission Comment: Engine Tag has NMHC/NOx Value
CO - Carbon Monoxide 0.1626 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.001625999999999
Emission Comment: Non-road Tier 2
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
Emission Unit ID Unit Process ID Throughput Operations
181197
McCloskey
Trommel Compost
Screener
1
McCloskey
Trommel Compost
Screener
Annual Throughput: 825.0 GALLONS (Distillate Oil (Diesel)) (Input)
Start Time: 07:30 AM, Stop Time: 03:00 PM
Average Hours/Day: 4.4, Days/Week: 2.5, Weeks/Year: 50.0
Actual Days/Year: 125.0
Actual Hours/Year: 550.0
Monthly Operations: Jan: 7.1%, Feb: 6.0%, Mar: 9.7%, Apr: 7.5%, May: 10.5%, Jun: 8.2%, Jul: 9.5%, Aug:
10.7%, Sep: 11.2%, Oct: 6.2%, Nov: 7.1%, Dec: 6.3%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.0007 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00028875
Emission Comment: Non-road Tier 4 Interim
PM25-PRI - PM2.5 Primary (Filt + Cond)0.0006 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.000247499999999
Emission Comment: Non-road Tier 4 Interim
SO2 - Sulf ur Dioxide 0.0002 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.0000825
Emission Comment: SO2 calculated from fuel sulfur content
NOX - Nitrogen Oxides 0.1236 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.050985
Emission Comment: Non-road Tier 4 Interim
VOC - Volatile Organic Compounds 0.0065 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00268125
Emission Comment: Non-road Tier 4 Interim
CO - Carbon Monoxide 0.1138 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.0469425
Emission Comment: Non-road Tier 4 Interim
Emission Unit ID Unit Process ID Throughput Operations
181207
RSS #9 standby
diesel fueled
engine generator
1
RSS #9 Standby
diesel fueled
engine generator
Annual Throughput: 6,756.0 HORSEPOWER-HOURS (Energy) (Output)
Start Time: 12:00 AM, Stop Time: 11:30 PM
Average Hours/Day: 3.0, Days/Week: 1.1, Weeks/Year: 7.0
Actual Days/Year: 8.0
Actual Hours/Year: 24.0
Monthly Operations: Jan: 0.0%, Feb: 0.0%, Mar: 0.0%, Apr: 0.0%, May: 20.8%, Jun: 0.0%, Jul: 29.2%, Aug:
0.0%, Sep: 8.3%, Oct: 41.7%, Nov: 0.0%, Dec: 0.0%
32/64
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.0002 HP-HR - HORSEPOWER-HOURS 11_2 - Vendor Provided (pre-control EF)0.0006756
Overall Control Efficiency: 0.0%
Emission Comment: calculated from engine manufacturer data at typical load
PM25-PRI - PM2.5 Primary (Filt + Cond)0.0002 HP-HR - HORSEPOWER-HOURS 11_2 - Vendor Provided (pre-control EF)0.0006756
Overall Control Efficiency: 0.0%
Emission Comment: calculated from engine manufacturer data at typical load
SO2 - Sulf ur Dioxide 0.0000809 HP-HR - HORSEPOWER-HOURS 2_2 - Engineering Judgement (pre-control EF)0.0002732802
Overall Control Efficiency: 0.0%
Emission Comment: calculated from sulfur content of diesel f uel
NOX - Nitrogen Oxides 0.019 HP-HR - HORSEPOWER-HOURS 11_2 - Vendor Provided (pre-control EF)0.064182
Overall Control Efficiency: 0.0%
Emission Comment: calculated from engine manufacturer data at typical load
VOC - Volatile Organic Compounds 0.0001 HP-HR - HORSEPOWER-HOURS 11_2 - Vendor Provided (pre-control EF)0.0003378
Overall Control Efficiency: 0.0%
Emission Comment: calculated from engine manufacturer data at typical load
CO - Carbon Monoxide 0.0014 HP-HR - HORSEPOWER-HOURS 11_2 - Vendor Provided (pre-control EF)0.004729199999999
Overall Control Efficiency: 0.0%
Emission Comment: calculated from engine manufacturer data at typical load
7439921 - Lead 2_0 - Engineering Judgement (no EF)0.0
NH3 - Ammonia 2_0 - Engineering Judgement (no EF)0.0
75070 - Acetaldehyde 0.0000001764 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000000595879199
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
107028 - Acrolein 0.00000005516 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.00000018633048
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
71432 - Benzene 0.000005432 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000018349296
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
50000 - Formaldehyde 0.0000005523 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0000018656694
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
91203 - Naphthalene 0.00000091 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.00000307398
Overall Control Efficiency: 0.0%
33/64
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
130498292 - PAH, total 0.000001484 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000005012952
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
108883 - Toluene 0.000001967 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000006644526
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
1330207 - Xylenes (Mixed Isomers)0.000001351 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000004563678
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
Emission Unit ID Unit Process ID Throughput Operations
181208
RSS #11 standby
diesel fueled
engine generator
1
RSS #11 Standby
diesel fueled
engine generator
Annual Throughput: 7,239.0 HORSEPOWER-HOURS (Energy) (Output)
Start Time: 12:00 AM, Stop Time: 11:30 PM
Average Hours/Day: 3.4, Days/Week: 1.1, Weeks/Year: 7.0
Actual Days/Year: 8.0
Actual Hours/Year: 27.0
Monthly Operations: Jan: 0.0%, Feb: 0.0%, Mar: 0.0%, Apr: 0.0%, May: 22.2%, Jun: 0.0%, Jul: 33.3%, Aug:
0.0%, Sep: 7.4%, Oct: 37.0%, Nov: 0.0%, Dec: 0.0%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.0002 HP-HR - HORSEPOWER-HOURS 11_2 - Vendor Provided (pre-control EF)0.0007239
Overall Control Efficiency: 0.0%
Emission Comment: calculated from engine manufacturer data at typical load
PM25-PRI - PM2.5 Primary (Filt + Cond)0.0002 HP-HR - HORSEPOWER-HOURS 11_2 - Vendor Provided (pre-control EF)0.0007239
Overall Control Efficiency: 0.0%
Emission Comment: calculated from engine manufacturer data at typical load
SO2 - Sulf ur Dioxide 0.0000106 HP-HR - HORSEPOWER-HOURS 2_2 - Engineering Judgement (pre-control EF)0.0000383667
Overall Control Efficiency: 0.0%
Emission Comment: calculated from sulfur content of diesel f uel
NOX - Nitrogen Oxides 0.019 HP-HR - HORSEPOWER-HOURS 11_2 - Vendor Provided (pre-control EF)0.0687705
Overall Control Efficiency: 0.0%
Emission Comment: calculated from engine manufacturer data at typical load
VOC - Volatile Organic Compounds 0.0001 HP-HR - HORSEPOWER-HOURS 11_2 - Vendor Provided (pre-control EF)0.00036195
Overall Control Efficiency: 0.0%
Emission Comment: calculated from engine manufacturer data at typical load
CO - Carbon Monoxide 0.0014 HP-HR - HORSEPOWER-HOURS 11_2 - Vendor Provided (pre-control EF)0.0050673
34/64
Overall Control Efficiency: 0.0%
Emission Comment: calculated from engine manufacturer data at typical load
7439921 - Lead 2_0 - Engineering Judgement (no EF)0.0
NH3 - Ammonia 2_0 - Engineering Judgement (no EF)0.0
75070 - Acetaldehyde 0.0000001764 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0000006384798
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
107028 - Acrolein 0.00000005516 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.00000019965162
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
71432 - Benzene 0.000005432 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000019661124
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
50000 - Formaldehyde 0.0000005523 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000001999049849
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
91203 - Naphthalene 0.00000091 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000003293744999
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
130498292 - PAH, total 0.000001484 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000005371337999
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
108883 - Toluene 0.000001967 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0000071195565
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
1330207 - Xylenes (Mixed Isomers)0.000001351 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0000048899445
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
Emission Unit ID Unit Process ID Throughput Operations
181209
Admin #10 standby
diesel fueled
engine generator
1
Admin #10
Standby diesel
f ueled engine
generator
Annual Throughput: 12,895.0 HORSEPOWER-HOURS (Energy) (Output)
Start Time: 12:00 AM, Stop Time: 11:30 PM
Average Hours/Day: 2.9, Days/Week: 1.2, Weeks/Year: 15.0
Actual Days/Year: 18.0
Actual Hours/Year: 52.0
Monthly Operations: Jan: 0.0%, Feb: 1.9%, Mar: 0.0%, Apr: 0.0%, May: 11.5%, Jun: 0.0%, Jul: 15.4%, Aug:
19.2%, Sep: 7.7%, Oct: 21.2%, Nov: 5.8%, Dec: 17.3%
35/64
Emission Unit ID Unit Process ID Throughput Operations
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.0003 HP-HR - HORSEPOWER-HOURS 2_2 - Engineering Judgement (pre-control EF)0.001934249999999
Overall Control Efficiency: 0.0%
Emission Comment: EPA Offroad Diesel Tier Table for 225-450kW and year 2005
PM25-PRI - PM2.5 Primary (Filt + Cond)0.0003 HP-HR - HORSEPOWER-HOURS 2_2 - Engineering Judgement (pre-control EF)0.001934249999999
Overall Control Efficiency: 0.0%
Emission Comment: EPA Offroad Diesel Tier Table for 225-450kW and year 2005
SO2 - Sulf ur Dioxide 0.0000106 HP-HR - HORSEPOWER-HOURS 2_2 - Engineering Judgement (pre-control EF)0.0000683435
Overall Control Efficiency: 0.0%
Emission Comment: calculated from sulfur content of diesel f uel
NOX - Nitrogen Oxides 0.0101 HP-HR - HORSEPOWER-HOURS 2_2 - Engineering Judgement (pre-control EF)0.065119749999999
Overall Control Efficiency: 0.0%
Emission Comment: EPA Offroad Diesel Tier Table for 225-450kW and year 2005. Assumes 95% NOx and 5% VOC from combined EF.
VOC - Volatile Organic Compounds 0.0005 HP-HR - HORSEPOWER-HOURS 2_2 - Engineering Judgement (pre-control EF)0.00322375
Overall Control Efficiency: 0.0%
Emission Comment: EPA Offroad Diesel Tier Table for 225-450kW and year 2005. Assumes 95% NOx and 5% VOC from combined EF.
CO - Carbon Monoxide 0.0057 HP-HR - HORSEPOWER-HOURS 2_2 - Engineering Judgement (pre-control EF)0.03675075
Overall Control Efficiency: 0.0%
Emission Comment: EPA Offroad Diesel Tier Table for 225-450kW and year 2005.
7439921 - Lead 2_0 - Engineering Judgement (no EF)0.0
NH3 - Ammonia 2_0 - Engineering Judgement (no EF)0.0
75070 - Acetaldehyde 0.000005369 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000034616627499
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
107028 - Acrolein 0.0000006475 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.00000417475625
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
71432 - Benzene 0.000006531 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0000421086225
Overall Control Efficiency: 0.0%
36/64
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
106990 - 1,3-Butadiene 0.0000002737 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.00000176468075
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
50000 - Formaldehyde 0.00000826 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.00005325635
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
91203 - Naphthalene 0.0000005936 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000003827236
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
130498292 - PAH, total 0.000001176 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.00000758226
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
108883 - Toluene 0.000002863 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0000184591925
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
1330207 - Xylenes (Mixed Isomers)0.000001995 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000012862762499
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
Emission Unit ID Unit Process ID Throughput Operations
181213
Skid Steer Loaders
1
Skid Steer Loaders
Annual Throughput: 218.7 GALLONS (Distillate Oil (Diesel)) (Input)
Start Time: 07:00 AM, Stop Time: 03:00 PM
Average Hours/Day: 4.0, Days/Week: 1.2, Weeks/Year: 50.0
Actual Days/Year: 60.0
Actual Hours/Year: 240.0
Monthly Operations: Jan: 7.1%, Feb: 6.0%, Mar: 9.7%, Apr: 7.5%, May: 10.5%, Jun: 8.2%, Jul: 9.5%, Aug:
10.7%, Sep: 11.2%, Oct: 6.2%, Nov: 7.1%, Dec: 6.3%
Comment: thoughput for the total of 6 loaders
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.01 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.001093499999999
Emission Comment: Non-road Tier 3
PM25-PRI - PM2.5 Primary (Filt + Cond)0.0092 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.001006019999999
Emission Comment: Non-road Tier 3
SO2 - Sulf ur Dioxide 0.0002 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00002187
37/64
Emission Comment: SO2 calculated from fuel sulfur content
NOX - Nitrogen Oxides 0.1669 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.018250514999999
Emission Comment: Non-road Tier 3
VOC - Volatile Organic Compounds 0.0088 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00096228
Emission Comment: Non-road Tier 3
CO - Carbon Monoxide 0.1748 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.01911438
Emission Comment: Non-road Tier 3
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
Emission Unit ID Unit Process ID Throughput Operations
185529
Waste Oil Burner
Dew atering
Equipment Barn
1
Waste Oil Burner
Dew atering
Equipment Barn
Annual Throughput: 0.55 1000 GALLONS (Waste Oil) (Input)
Supplemental Calculation Parameters
% Ash: 5.0, % Sulfur: 0.03
Start Time: 12:00 AM, Stop Time: 11:30 PM
Average Hours/Day: 6.4, Days/Week: 4.1, Weeks/Year: 10.0
Actual Days/Year: 41.0
Actual Hours/Year: 262.0
Monthly Operations: Jan: 23.0%, Feb: 22.3%, Mar: 19.7%, Apr: 10.5%, May: 0.1%, Jun: 0.0%, Jul: 0.0%,
Aug: 0.0%, Sep: 0.0%, Oct: 0.4%, Nov: 7.2%, Dec: 16.9%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)286.5 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0787875
Overall Control Efficiency: 0.0%
PM10-FIL - PM10 Filterable 285.0 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.078375
Overall Control Efficiency: 0.0%
PM25-PRI - PM2.5 Primary (Filt + Cond)229.2 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.06303
Overall Control Efficiency: 0.0%
PM25-FIL - PM2.5 Filterable 227.7 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0626175
Overall Control Efficiency: 0.0%
PM-CON - PM Condensible 1.5 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0004125
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
SO2 - Sulf ur Dioxide 3.21 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.00088275
Overall Control Efficiency: 0.0%
NOX - Nitrogen Oxides 16.0 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0044
Overall Control Efficiency: 0.0%
VOC - Volatile Organic Compounds 1.0 E3GAL - 1000 GALLONS 8_4 - EPA Emission Factor (pre-control)0.000275
Overall Control Efficiency: 0.0%
CO - Carbon Monoxide 2.1 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0005775
Overall Control Efficiency: 0.0%
38/64
7439921 - Lead 2.0 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.00055
Overall Control Efficiency: 0.0%
7440360 - Antimony 0.0045 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0000012375
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
7440382 - Arsenic 0.06 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0000165
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
7440417 - Beryllium 0.0018 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000000495
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
7440439 - Cadmium 0.012 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0000033
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
7440473 - Chromium 0.18 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0000495
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
7440484 - Cobalt 0.0052 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.00000143
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
84742 - Dibutyl Phthalate 0.000034 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.00000000935
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
7439965 - Manganese 0.05 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.00001375
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
91203 - Naphthalene 0.00094 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0000002585
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
7440020 - Nickel 0.16 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000044
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
108952 - Phenol 0.000028 E3GAL - 1000 GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0000000077
Overall Control Efficiency: 0.0%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
39/64
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
Emission Unit ID Unit Process ID Throughput Operations
185573
Pow er Gen #6
Standby diesel
f ueled engine
generator
1
Pow er Gen #6
Standby diesel
f ueled engine
generator
Annual Throughput: 6,166.0 HORSEPOWER-HOURS (Energy) (Output)
Start Time: 12:00 AM, Stop Time: 11:30 PM
Average Hours/Day: 2.7, Days/Week: 1.2, Weeks/Year: 5.0
Actual Days/Year: 6.0
Actual Hours/Year: 16.0
Monthly Operations: Jan: 0.0%, Feb: 0.0%, Mar: 0.0%, Apr: 0.0%, May: 32.1%, Jun: 0.0%, Jul: 15.5%, Aug:
0.0%, Sep: 1.0%, Oct: 51.4%, Nov: 0.0%, Dec: 0.0%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.0001 HP-HR - HORSEPOWER-HOURS 11_2 - Vendor Provided (pre-control EF)0.0003083
Overall Control Efficiency: 0.0%
Emission Comment: calculated from engine manufacturer data at typical load
PM25-PRI - PM2.5 Primary (Filt + Cond)0.0001 HP-HR - HORSEPOWER-HOURS 11_2 - Vendor Provided (pre-control EF)0.0003083
Overall Control Efficiency: 0.0%
Emission Comment: calculated from engine manufacturer data at typical load
SO2 - Sulf ur Dioxide 0.0000106 HP-HR - HORSEPOWER-HOURS 2_2 - Engineering Judgement (pre-control EF)0.0000326798
Overall Control Efficiency: 0.0%
Emission Comment: calculated from sulfur content of diesel f uel
NOX - Nitrogen Oxides 0.0058 HP-HR - HORSEPOWER-HOURS 11_2 - Vendor Provided (pre-control EF)0.0178814
Overall Control Efficiency: 0.0%
Emission Comment: calculated from engine manufacturer data at typical load
VOC - Volatile Organic Compounds 0.00036 HP-HR - HORSEPOWER-HOURS 11_2 - Vendor Provided (pre-control EF)0.00110988
Overall Control Efficiency: 0.0%
Emission Comment: calculated from engine manufacturer data at typical load
CO - Carbon Monoxide 0.0012 HP-HR - HORSEPOWER-HOURS 11_2 - Vendor Provided (pre-control EF)0.0036996
Overall Control Efficiency: 0.0%
Emission Comment: calculated from engine manufacturer data at typical load
7439921 - Lead 2_0 - Engineering Judgement (no EF)0.0
NH3 - Ammonia 2_0 - Engineering Judgement (no EF)0.0
75070 - Acetaldehyde 0.0000001764 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000000543841199
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
107028 - Acrolein 0.00000005516 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000000170058279
Overall Control Efficiency: 0.0%
40/64
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
71432 - Benzene 0.000005432 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000016746856
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
50000 - Formaldehyde 0.0000005523 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0000017027409
Overall Control Efficiency: 0.0%
91203 - Naphthalene 0.00000091 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.00000280553
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
130498292 - PAH, total 0.000001484 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000004575172
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
108883 - Toluene 0.000001967 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000006064261
Overall Control Efficiency: 0.0%
1330207 - Xylenes (Mixed Isomers)0.000001351 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000004165133
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
Emission Unit ID Unit Process ID Throughput Operations
185574
Pow er Gen #7
Standby diesel
f ueled engine
generator
1
Pow er Gen #7
Standby diesel
f ueled engine
generator
Annual Throughput: 5,920.0 HORSEPOWER-HOURS (Energy) (Output)
Start Time: 12:00 AM, Stop Time: 11:30 PM
Average Hours/Day: 2.7, Days/Week: 1.0, Weeks/Year: 6.0
Actual Days/Year: 6.0
Actual Hours/Year: 16.0
Monthly Operations: Jan: 0.0%, Feb: 0.0%, Mar: 0.0%, Apr: 0.0%, May: 26.7%, Jun: 0.0%, Jul: 15.4%, Aug:
0.0%, Sep: 0.6%, Oct: 57.3%, Nov: 0.0%, Dec: 0.0%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.0001 HP-HR - HORSEPOWER-HOURS 11_2 - Vendor Provided (pre-control EF)0.000296
Overall Control Efficiency: 0.0%
Emission Comment: calculated from engine manufacturer data at typical load
PM25-PRI - PM2.5 Primary (Filt + Cond)0.0001 HP-HR - HORSEPOWER-HOURS 11_2 - Vendor Provided (pre-control EF)0.000296
Overall Control Efficiency: 0.0%
Emission Comment: calculated from engine manufacturer data at typical load
SO2 - Sulf ur Dioxide 0.0000106 HP-HR - HORSEPOWER-HOURS 2_2 - Engineering Judgement (pre-control EF)0.000031376
Overall Control Efficiency: 0.0%
Emission Comment: calculated from sulfur content of diesel f uel
41/64
NOX - Nitrogen Oxides 0.0058 HP-HR - HORSEPOWER-HOURS 11_2 - Vendor Provided (pre-control EF)0.017168
Overall Control Efficiency: 0.0%
Emission Comment: calculated from engine manufacturer data at typical load
VOC - Volatile Organic Compounds 0.00036 HP-HR - HORSEPOWER-HOURS 11_2 - Vendor Provided (pre-control EF)0.0010656
Overall Control Efficiency: 0.0%
Emission Comment: calculated from engine manufacturer data at typical load
CO - Carbon Monoxide 0.0012 HP-HR - HORSEPOWER-HOURS 11_2 - Vendor Provided (pre-control EF)0.003551999999999
Overall Control Efficiency: 0.0%
Emission Comment: calculated from engine manufacturer data at typical load
7439921 - Lead 2_0 - Engineering Judgement (no EF)0.0
NH3 - Ammonia 2_0 - Engineering Judgement (no EF)0.0
75070 - Acetaldehyde 0.0000001764 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000000522144
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
107028 - Acrolein 0.00000005516 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0000001632736
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
71432 - Benzene 0.000005432 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.00001607872
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
50000 - Formaldehyde 0.0000005523 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000001634808
Overall Control Efficiency: 0.0%
91203 - Naphthalene 0.00000091 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0000026936
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
130498292 - PAH, total 0.000001484 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000004392639999
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
108883 - Toluene 0.000001967 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.00000582232
Overall Control Efficiency: 0.0%
1330207 - Xylenes (Mixed Isomers)0.000001351 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.00000399896
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
42/64
Emission Unit ID Unit Process ID Throughput Operations
185604
Gas System Waste
Gas Flares
1
Gas System Waste
Gas Flares
Annual Throughput: 1.2 MILLION STANDARD CUBIC FEET (Methane) (Input)
Start Time: 12:00 AM, Stop Time: 11:30 PM
Average Hours/Day: 1.0, Days/Week: 1.7, Weeks/Year: 23.0
Actual Days/Year: 39.0
Actual Hours/Year: 39.0
Monthly Operations: Jan: 0.0%, Feb: 6.4%, Mar: 0.0%, Apr: 0.7%, May: 14.2%, Jun: 2.8%, Jul: 23.0%, Aug:
0.0%, Sep: 10.2%, Oct: 33.4%, Nov: 0.0%, Dec: 9.3%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)17.0 E6FT3S - MILLION STANDARD
CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.010199999999999
Overall Control Efficiency: 0.0%
Emission Comment: Factor taken from AP-42 Table 2.4-5 (11/98). The 1998 version of this chapter w as utilized as the 2008 version has not been
finalized.
PM25-PRI - PM2.5 Primary (Filt + Cond)17.0 E6FT3S - MILLION STANDARD
CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.010199999999999
Overall Control Efficiency: 0.0%
Emission Comment: Per note b of AP-42 Table 2.4-5, most of the PM w ill be < 2.5 microns in diameter. Therefore, the emission factor provided can be
used f or PM-10 and PM-2.5
PM-CON - PM Condensible 17.0 E6FT3S - MILLION STANDARD
CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.010199999999999
Overall Control Efficiency: 0.0%
Emission Comment: assumed all PM is condensable, since little if any is greater than 2.5 microns per AP-42 Table 2.4-5.
SO2 - Sulf ur Dioxide 16.64 E6FT3S - MILLION STANDARD
CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.009984
Overall Control Efficiency: 0.0%
Emission Comment: calculated using H2S from digester gas from most recent gas analysis
NOX - Nitrogen Oxides 40.8 E6FT3S - MILLION STANDARD
CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.02448
Overall Control Efficiency: 0.0%
Emission Comment: emission factors are taken f rom AP-42, Tables 13.5-1 and 13.5-2 (02/18)
VOC - Volatile Organic Compounds 76.4 E6FT3S - MILLION STANDARD
CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.04584
Overall Control Efficiency: 0.0%
Emission Comment: emission factors are taken f rom AP-42, Tables 13.5-1 and 13.5-2 (02/18)
CO - Carbon Monoxide 169.0 E6FT3S - MILLION STANDARD
CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.101399999999999
Overall Control Efficiency: 0.0%
Emission Comment: emission factors are taken f rom AP-42, Tables 13.5-1 and 13.5-2 (02/18)
43/64
7439921 - Lead 0.0005 E6FT3S - MILLION STANDARD
CUBIC FEET 8_4 - EPA Emission Factor (pre-control)0.0000003
Overall Control Efficiency: 0.0%
NH3 - Ammonia 3.2 E6FT3S - MILLION STANDARD
CUBIC FEET 8_4 - EPA Emission Factor (pre-control)0.001919999999999
Overall Control Efficiency: 0.0%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
Emission Unit ID Unit Process ID Throughput Operations
185615
Jenbacher IC
Engine 1
1
Jenbacher IC
Engine 1 Digester
Gas
Annual Throughput: 80.04 MILLION CUBIC FEET (Process Gas) (Input)
Start Time: 12:00 AM, Stop Time: 11:30 PM
Average Hours/Day: 21.0, Days/Week: 4.9, Weeks/Year: 37.0
Actual Days/Year: 180.0
Actual Hours/Year: 3,771.0
Monthly Operations: Jan: 2.6%, Feb: 1.5%, Mar: 1.4%, Apr: 2.6%, May: 14.7%, Jun: 6.4%, Jul: 6.0%, Aug:
14.5%, Sep: 14.8%, Oct: 19.8%, Nov: 11.7%, Dec: 3.9%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)6.43 E6FT3 - MILLION CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.2573286
Overall Control Efficiency: 0.0%
Emission Comment: PM value from Manufacturer guaranteed emissions limits per hp-hr - converted to limits per MMSCF based on blended gas makeup
PM10-FIL - PM10 Filterable 0.05 E6FT3 - MILLION CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.002001
Overall Control Efficiency: 0.0%
Emission Comment: calculated from PM10 Pri and PM Cond
PM25-PRI - PM2.5 Primary (Filt + Cond)6.43 E6FT3 - MILLION CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.2573286
Overall Control Efficiency: 0.0%
Emission Comment: Assumed equal to PM 10 per AP-42 Table 3.2-2, Uncontrolled emission factors for 4-stroke lean-burn engines
PM25-FIL - PM2.5 Filterable 0.05 E6FT3 - MILLION CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.002001
Overall Control Efficiency: 0.0%
Emission Comment: calculated from PM25 Pri and PM Cond
PM-CON - PM Condensible 6.38 E6FT3 - MILLION CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.2553276
Overall Control Efficiency: 0.0%
Emission Comment: ratio of primary based on AP-42 Uncontrolled emission f actors f or 4-stroke lean-burn engines
SO2 - Sulf ur Dioxide 13.04 E6FT3 - MILLION CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.5218608
Overall Control Efficiency: 0.0%
Emission Comment: calculated from blended gas sulf ur content
NOX - Nitrogen Oxides 115.67 E6FT3 - MILLION CUBIC FEET 4_2 - Stack Test (pre-control EF)4.6291134
Stack Test Date: 06/28/2022
Overall Control Efficiency: 0.0%
44/64
VOC - Volatile Organic Compounds 17.14 E6FT3 - MILLION CUBIC FEET 4_2 - Stack Test (pre-control EF)0.6859428
Stack Test Date: 06/28/2022
Overall Control Efficiency: 0.0%
CO - Carbon Monoxide 428.42 E6FT3 - MILLION CUBIC FEET 4_2 - Stack Test (pre-control EF)17.1453684
Stack Test Date: 06/28/2022
Overall Control Efficiency: 0.0%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
Emission Unit ID Unit Process ID Throughput Operations
185617
Jenbacher IC
Engine 2
1
Jenbacher IC
Engine 2 Digester
Gas
Annual Throughput: 87.26 MILLION CUBIC FEET (Process Gas) (Input)
Start Time: 12:00 AM, Stop Time: 11:30 PM
Average Hours/Day: 20.3, Days/Week: 4.4, Weeks/Year: 45.0
Actual Days/Year: 204.0
Actual Hours/Year: 4,131.0
Monthly Operations: Jan: 12.7%, Feb: 0.0%, Mar: 12.7%, Apr: 12.7%, May: 12.0%, Jun: 7.9%, Jul: 7.8%,
Aug: 8.1%, Sep: 9.7%, Oct: 0.7%, Nov: 2.4%, Dec: 13.4%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)6.43 E6FT3 - MILLION CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.2805409
Overall Control Efficiency: 0.0%
Emission Comment: PM value from Manufacturer guaranteed emissions limits per hp-hr - converted to limits per MMSCF based on blended gas makeup
PM10-FIL - PM10 Filterable 0.05 E6FT3 - MILLION CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.0021815
Overall Control Efficiency: 0.0%
Emission Comment: calculated from PM10 Pri and PM Cond
PM25-PRI - PM2.5 Primary (Filt + Cond)6.43 E6FT3 - MILLION CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.2805409
Overall Control Efficiency: 0.0%
Emission Comment: Assumed equal to PM 10 per AP-42 Table 3.2-2, Uncontrolled emission factors for 4-stroke lean-burn engines
PM25-FIL - PM2.5 Filterable 0.05 E6FT3 - MILLION CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.0021815
Overall Control Efficiency: 0.0%
Emission Comment: calculated from PM25 Pri and PM Cond
PM-CON - PM Condensible 6.38 E6FT3 - MILLION CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.278359399999999
Overall Control Efficiency: 0.0%
Emission Comment: ratio of primary based on AP-42 Uncontrolled emission f actors f or 4-stroke lean-burn engines
SO2 - Sulf ur Dioxide 13.04 E6FT3 - MILLION CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.5689352
Overall Control Efficiency: 0.0%
Emission Comment: calculated from blended gas sulf ur content
NOX - Nitrogen Oxides 85.68 E6FT3 - MILLION CUBIC FEET 4_2 - Stack Test (pre-control EF)3.7382184
Stack Test Date: 12/15/2023
45/64
Overall Control Efficiency: 0.0%
VOC - Volatile Organic Compounds 34.27 E6FT3 - MILLION CUBIC FEET 4_2 - Stack Test (pre-control EF)1.4952001
Stack Test Date: 12/15/2023
Overall Control Efficiency: 0.0%
CO - Carbon Monoxide 404.85 E6FT3 - MILLION CUBIC FEET 4_2 - Stack Test (pre-control EF)17.6636055
Stack Test Date: 12/15/2023
Overall Control Efficiency: 0.0%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
Emission Unit ID Unit Process ID Throughput Operations
185624
Headw orks #12
Standby diesel
f ueled engine
generator
1
Headw orks #12
Standby diesel
f ueled engine
generator
Annual Throughput: 6,945.0 HORSEPOWER-HOURS (Energy) (Output)
Start Time: 12:00 AM, Stop Time: 11:30 PM
Average Hours/Day: 3.3, Days/Week: 1.0, Weeks/Year: 8.0
Actual Days/Year: 8.0
Actual Hours/Year: 26.0
Monthly Operations: Jan: 0.0%, Feb: 0.0%, Mar: 0.0%, Apr: 0.0%, May: 17.5%, Jun: 0.0%, Jul: 35.89%, Aug:
0.0%, Sep: 0.2%, Oct: 46.3%, Nov: 0.0%, Dec: 0.2%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.0002 HP-HR - HORSEPOWER-HOURS 11_2 - Vendor Provided (pre-control EF)0.0006945
Overall Control Efficiency: 0.0%
Emission Comment: calculated from engine manufacturer data at typical load
PM25-PRI - PM2.5 Primary (Filt + Cond)0.0002 HP-HR - HORSEPOWER-HOURS 11_2 - Vendor Provided (pre-control EF)0.0006945
Overall Control Efficiency: 0.0%
Emission Comment: calculated from engine manufacturer data at typical load
SO2 - Sulf ur Dioxide 0.000106 HP-HR - HORSEPOWER-HOURS 2_2 - Engineering Judgement (pre-control EF)0.000368085
Overall Control Efficiency: 0.0%
Emission Comment: calculated from sulfur content of diesel f uel
NOX - Nitrogen Oxides 0.0115 HP-HR - HORSEPOWER-HOURS 11_2 - Vendor Provided (pre-control EF)0.03993375
Overall Control Efficiency: 0.0%
Emission Comment: calculated from engine manufacturer data at typical load
VOC - Volatile Organic Compounds 0.00115 HP-HR - HORSEPOWER-HOURS 11_2 - Vendor Provided (pre-control EF)0.003993374999999
Overall Control Efficiency: 0.0%
Emission Comment: calculated from engine manufacturer data at typical load
CO - Carbon Monoxide 0.0049 HP-HR - HORSEPOWER-HOURS 11_2 - Vendor Provided (pre-control EF)0.01701525
Overall Control Efficiency: 0.0%
Emission Comment: calculated from engine manufacturer data at typical load
7439921 - Lead 2_0 - Engineering Judgement (no EF)0.0
46/64
NH3 - Ammonia 2_0 - Engineering Judgement (no EF)0.0
75070 - Acetaldehyde 0.0000001764 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000000612549
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
107028 - Acrolein 0.00000005516 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0000001915431
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
71432 - Benzene 0.000005432 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.00001886262
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
50000 - Formaldehyde 0.0000005523 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000001917861749
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
91203 - Naphthalene 0.00000091 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000003159974999
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
130498292 - PAH, total 0.000001484 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000005153189999
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
108883 - Toluene 0.000001967 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0000068304075
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
1330207 - Xylenes (Mixed Isomers)0.000001351 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0000046913475
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
Emission Unit ID Unit Process ID Throughput Operations
185625
Headw orks #13
Standby diesel
f ueled engine
generator
1
Headw orks #13
Standby diesel
f ueled engine
generator
Annual Throughput: 3,417.0 HORSEPOWER-HOURS (Energy) (Output)
Start Time: 12:00 AM, Stop Time: 11:30 PM
Average Hours/Day: 3.0, Days/Week: 1.0, Weeks/Year: 8.0
Actual Days/Year: 8.0
Actual Hours/Year: 24.0
Monthly Operations: Jan: 0.0%, Feb: 0.0%, Mar: 0.0%, Apr: 0.0%, May: 30.9%, Jun: 0.0%, Jul: 21.3%, Aug:
0.0%, Sep: 1.4%, Oct: 44.8%, Nov: 0.0%, Dec: 1.6%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.0002 HP-HR - HORSEPOWER-HOURS 11_2 - Vendor Provided (pre-control EF)0.0003417
47/64
Overall Control Efficiency: 0.0%
Emission Comment: calculated from engine manufacturer data at typical load
PM25-PRI - PM2.5 Primary (Filt + Cond)0.0002 HP-HR - HORSEPOWER-HOURS 11_2 - Vendor Provided (pre-control EF)0.0003417
Overall Control Efficiency: 0.0%
Emission Comment: calculated from engine manufacturer data at typical load
SO2 - Sulf ur Dioxide 0.0000106 HP-HR - HORSEPOWER-HOURS 2_2 - Engineering Judgement (pre-control EF)0.0000181101
Overall Control Efficiency: 0.0%
Emission Comment: calculated from sulfur content of diesel f uel
NOX - Nitrogen Oxides 0.0115 HP-HR - HORSEPOWER-HOURS 11_2 - Vendor Provided (pre-control EF)0.01964775
Overall Control Efficiency: 0.0%
Emission Comment: calculated from engine manufacturer data at typical load
VOC - Volatile Organic Compounds 0.00115 HP-HR - HORSEPOWER-HOURS 11_2 - Vendor Provided (pre-control EF)0.001964774999999
Overall Control Efficiency: 0.0%
Emission Comment: calculated from engine manufacturer data at typical load
CO - Carbon Monoxide 0.0049 HP-HR - HORSEPOWER-HOURS 11_2 - Vendor Provided (pre-control EF)0.00837165
Overall Control Efficiency: 0.0%
Emission Comment: calculated from engine manufacturer data at typical load
7439921 - Lead 2_0 - Engineering Judgement (no EF)0.0
NH3 - Ammonia 2_0 - Engineering Judgement (no EF)0.0
75070 - Acetaldehyde 0.0000001764 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000000301379399
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
107028 - Acrolein 0.00000005516 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.00000009424086
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
71432 - Benzene 0.000005432 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000009280571999
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
50000 - Formaldehyde 0.0000005523 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.00000094360455
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
91203 - Naphthalene 0.00000091 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000001554735
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
48/64
130498292 - PAH, total 0.000001484 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000002535414
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
108883 - Toluene 0.000001967 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000003360619499
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
1330207 - Xylenes (Mixed Isomers)0.000001351 HP-HR - HORSEPOWER-HOURS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.0000023081835
Overall Control Efficiency: 0.0%
Emission Comment: Pollutant and meta-data def aulted f rom Emission Factor ref erence source.
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
Emission Unit ID Unit Process ID Throughput Operations
185652
Diesel Fuel Storage
Tanks
1
Diesel Fuel Storage
Tanks - Working
Loss
Annual Throughput: 53.982 1000 GALLONS (Distillate Oil (No. 2)) (Input)
Supplemental Calculation Parameters
% VOC: 0.01, Density (lbs/unit): 7,100.0
Start Time: 08:00 AM, Stop Time: 04:00 PM
Average Hours/Day: 1.0, Days/Week: 1.0, Weeks/Year: 6.0
Actual Days/Year: 6.0
Actual Hours/Year: 6.0
Monthly Operations: Jan: 16.6%, Feb: 0.0%, Mar: 0.0%, Apr: 17.6%, May: 0.0%, Jun: 14.9%, Jul: 0.0%, Aug:
17.6%, Sep: 16.7%, Oct: 0.0%, Nov: 0.0%, Dec: 16.6%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
VOC - Volatile Organic Compounds 0.01882 E3GAL - 1000 GALLONS 2_1 - Engineering Judgement (post-control EF)0.00050797062
Emission Comment: calculated using approved method
Emission Unit ID Unit Process ID Throughput Operations
185652
Diesel Fuel Storage
Tanks
2
Diesel Fuel Storage
Tanks - Standing
Loss
Annual Throughput: 53.982 1000 GALLONS (Distillate Oil (No. 2)) (Input)
Start Time: 12:00 AM, Stop Time: 11:30 PM
Average Hours/Day: 24.0, Days/Week: 7.0, Weeks/Year: 52.0
Actual Days/Year: 365.0
Actual Hours/Year: 8,760.0
Monthly Operations: Jan: 8.5%, Feb: 7.7%, Mar: 8.5%, Apr: 8.2%, May: 8.5%, Jun: 8.2%, Jul: 8.5%, Aug:
8.5%, Sep: 8.2%, Oct: 8.5%, Nov: 8.2%, Dec: 8.5%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
VOC - Volatile Organic Compounds 0.04542 E3GAL - 1000 GALLONS 2_1 - Engineering Judgement (post-control EF)0.00122593122
Emission Comment: calculated using approved method
Emission Unit ID Unit Process ID Throughput Operations
49/64
185667
KBC Boiler (South)
1
KBC Boiler (South)
Annual Throughput: 0.06 MILLION CUBIC FEET (Natural Gas) (Input)
Start Time: 12:00 AM, Stop Time: 11:59 PM
Average Hours/Day: 24.0, Days/Week: 1.7, Weeks/Year: 10.0
Actual Days/Year: 17.0
Actual Hours/Year: 408.0
Monthly Operations: Jan: 74.1%, Feb: 6.2%, Mar: 0.5%, Apr: 0.0%, May: 0.0%, Jun: 0.0%, Jul: 0.0%, Aug:
0.0%, Sep: 0.0%, Oct: 12.6%, Nov: 5.8%, Dec: 0.8%
Emission Unit ID Unit Process ID Throughput Operations
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)7.6 E6FT3 - MILLION CUBIC FEET 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000228
Overall Control Efficiency: 0.0%
PM10-FIL - PM10 Filterable 1.9 E6FT3 - MILLION CUBIC FEET 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000057
Overall Control Efficiency: 0.0%
PM25-PRI - PM2.5 Primary (Filt + Cond)7.6 E6FT3 - MILLION CUBIC FEET 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000228
Overall Control Efficiency: 0.0%
PM25-FIL - PM2.5 Filterable 1.9 E6FT3 - MILLION CUBIC FEET 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000057
Overall Control Efficiency: 0.0%
PM-CON - PM Condensible 5.7 E6FT3 - MILLION CUBIC FEET 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000170999999999
Overall Control Efficiency: 0.0%
SO2 - Sulf ur Dioxide 1.5 E6FT3 - MILLION CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.000044999999999
Overall Control Efficiency: 0.0%
Emission Comment: calculated from NG sulfur content
NOX - Nitrogen Oxides 100.0 E6FT3 - MILLION CUBIC FEET 8_2 - EPA WebFIRE Emission Factor (pre-control)0.003
Overall Control Efficiency: 0.0%
VOC - Volatile Organic Compounds 5.5 E6FT3 - MILLION CUBIC FEET 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000164999999999
Overall Control Efficiency: 0.0%
CO - Carbon Monoxide 84.0 E6FT3 - MILLION CUBIC FEET 8_2 - EPA WebFIRE Emission Factor (pre-control)0.00252
Overall Control Efficiency: 0.0%
NH3 - Ammonia 3.2 E6FT3 - MILLION CUBIC FEET 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000096
Overall Control Efficiency: 0.0%
Emission Unit ID Unit Process ID Throughput Operations
50/64
185668
Unpaved Roads
1
Unpaved Roads
Annual Throughput: 3,120.0 MILES (Vehicle) (Input)
Supplemental Calculation Parameters
% Silt: 5.0, Mean Vehicle Weight: 30.0, Precipitation days: 105.0
Start Time: 07:00 AM, Stop Time: 05:00 PM
Average Hours/Day: 10.0, Days/Week: 5.0, Weeks/Year: 50.0
Actual Days/Year: 250.0
Actual Hours/Year: 2,500.0
Monthly Operations: Jan: 8.5%, Feb: 7.7%, Mar: 8.8%, Apr: 7.7%, May: 8.8%, Jun: 8.5%, Jul: 8.1%, Aug:
8.8%, Sep: 8.1%, Oct: 8.5%, Nov: 8.5%, Dec: 8.1%
Emission Unit ID Unit Process ID Throughput Operations
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)1.36956177138819 MILE - MILES 8_2 - EPA WebFIRE Emission Factor (pre-control)1.06825818168279
Overall Control Efficiency: 50.0%
PM10-FIL - PM10 Filterable 1.36956177138819 MILE - MILES 8_2 - EPA WebFIRE Emission Factor (pre-control)1.06825818168279
Overall Control Efficiency: 50.0%
PM25-PRI - PM2.5 Primary (Filt + Cond)0.136956177138819 MILE - MILES 8_2 - EPA WebFIRE Emission Factor (pre-control)0.106825818168278
Overall Control Efficiency: 50.0%
PM25-FIL - PM2.5 Filterable 0.136956177138819 MILE - MILES 8_2 - EPA WebFIRE Emission Factor (pre-control)0.106825818168278
Overall Control Efficiency: 50.0%
Emission Unit ID Unit Process ID Throughput Operations
185718
Telehandler
1
Telehandler
Annual Throughput: 344.1 GALLONS (Distillate Oil (Diesel)) (Input)
Start Time: 08:00 AM, Stop Time: 04:00 PM
Average Hours/Day: 2.0, Days/Week: 2.7, Weeks/Year: 50.0
Actual Days/Year: 135.0
Actual Hours/Year: 270.0
Monthly Operations: Jan: 7.1%, Feb: 6.0%, Mar: 9.7%, Apr: 7.5%, May: 10.5%, Jun: 8.2%, Jul: 9.5%, Aug:
10.7%, Sep: 11.2%, Oct: 6.2%, Nov: 7.1%, Dec: 6.3%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.0013 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.000223665
Emission Comment: Engine Tag has PM value
PM25-PRI - PM2.5 Primary (Filt + Cond)0.0012 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00020646
Emission Comment: Engine Tag has PM value
SO2 - Sulf ur Dioxide 0.0002 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00003441
Emission Comment: SO2 calculated from fuel sulfur content
NOX - Nitrogen Oxides 0.013 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00223665
Emission Comment: Non-road Tier 4
VOC - Volatile Organic Compounds 0.0062 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00106671
Emission Comment: Non-road Tier 4
CO - Carbon Monoxide 0.1626 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.02797533
51/64
Emission Comment: Non-road Tier 4
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
Emission Unit ID Unit Process ID Throughput Operations
185719
Go Bagger
1
Go Bagger
Annual Throughput: 15.0 GALLONS (Distillate Oil (Diesel)) (Input)
Start Time: 08:00 AM, Stop Time: 04:00 PM
Average Hours/Day: 2.0, Days/Week: 1.0, Weeks/Year: 10.0
Actual Days/Year: 10.0
Actual Hours/Year: 20.0
Monthly Operations: Jan: 7.1%, Feb: 6.0%, Mar: 9.7%, Apr: 7.5%, May: 10.5%, Jun: 8.2%, Jul: 9.5%, Aug:
10.7%, Sep: 11.2%, Oct: 6.2%, Nov: 7.1%, Dec: 6.3%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.013 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.000097499999999
Emission Comment: Non-road Tier 4
PM25-PRI - PM2.5 Primary (Filt + Cond)0.012 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.000089999999999
Emission Comment: Non-road Tier 4
SO2 - Sulf ur Dioxide 0.0002 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.0000015
Emission Comment: SO2 calculated from fuel sulfur content
NOX - Nitrogen Oxides 0.2317 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00173775
Emission Comment: Non-road Tier 4
VOC - Volatile Organic Compounds 0.0122 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.0000915
Emission Comment: Non-road Tier 4
CO - Carbon Monoxide 0.2602 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.0019515
Emission Comment: Non-road Tier 4
Emission Unit ID Unit Process ID Throughput Operations
185720
Mini Excavator
1
Mini Excavator
Annual Throughput: 25.2 GALLONS (Diesel) (Input)
Start Time: 08:00 AM, Stop Time: 04:00 PM
Average Hours/Day: 3.0, Days/Week: 2.0, Weeks/Year: 5.0
Actual Days/Year: 10.0
Actual Hours/Year: 30.0
Monthly Operations: Jan: 7.1%, Feb: 6.0%, Mar: 9.7%, Apr: 7.5%, May: 10.5%, Jun: 8.2%, Jul: 9.5%, Aug:
10.7%, Sep: 11.2%, Oct: 6.2%, Nov: 7.1%, Dec: 6.3%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.001 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.0000126
Emission Comment: Non-road Tier 4
PM25-PRI - PM2.5 Primary (Filt + Cond)0.0009 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00001134
Emission Comment: Non-road Tier 4
SO2 - Sulf ur Dioxide 0.0002 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00000252
Emission Comment: SO2 calculated from fuel sulfur content
52/64
NOX - Nitrogen Oxides 0.1452 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.001829519999999
Emission Comment: Non-road Tier 4
VOC - Volatile Organic Compounds 0.0076 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.000095759999999
Emission Comment: Non-road Tier 4
CO - Carbon Monoxide 0.1789 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00225414
Emission Comment: Non-road Tier 4
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
Emission Unit ID Unit Process ID Throughput Operations
185721
Boom Truck
1
Boom Truck
Annual Throughput: 16.2 GALLONS (Diesel) (Input)
Start Time: 08:00 AM, Stop Time: 04:00 PM
Average Hours/Day: 2.0, Days/Week: 1.0, Weeks/Year: 15.0
Actual Days/Year: 15.0
Actual Hours/Year: 30.0
Monthly Operations: Jan: 7.1%, Feb: 6.0%, Mar: 9.7%, Apr: 7.5%, May: 10.5%, Jun: 8.2%, Jul: 9.5%, Aug:
10.7%, Sep: 11.2%, Oct: 6.2%, Nov: 7.1%, Dec: 6.3%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.0261 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00021141
Emission Comment: On-road State EFs - Single Unit Short-haul Truck
PM25-PRI - PM2.5 Primary (Filt + Cond)0.024 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.000194399999999
Emission Comment: On-road State EFs - Single Unit Short-haul Truck
SO2 - Sulf ur Dioxide 0.0002 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00000162
Emission Comment: SO2 calculated from fuel sulfur content
NOX - Nitrogen Oxides 0.3521 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00285201
Emission Comment: On-road State EFs - Single Unit Short-haul Truck
VOC - Volatile Organic Compounds 0.0369 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00029889
Emission Comment: On-road State EFs - Single Unit Short-haul Truck
CO - Carbon Monoxide 0.1239 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00100359
Emission Comment: On-road State EFs - Single Unit Short-haul Truck
Emission Unit ID Unit Process ID Throughput Operations
185723
Service Trucks
1
Service Trucks
Annual Throughput: 20.65 GALLONS (Gasoline) (Input)
Start Time: 08:00 AM, Stop Time: 04:00 PM
Average Hours/Day: 2.0, Days/Week: 2.0, Weeks/Year: 30.0
Actual Days/Year: 60.0
Actual Hours/Year: 120.0
Monthly Operations: Jan: 9.1%, Feb: 7.4%, Mar: 8.7%, Apr: 8.9%, May: 8.6%, Jun: 8.4%, Jul: 6.8%, Aug:
12.3%, Sep: 6.9%, Oct: 6.6%, Nov: 9.3%, Dec: 6.9%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.0139 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.0001435175
53/64
Emission Comment: On-road State EFs - Single Unit Short-haul Truck, assumed 10mi/gal
PM25-PRI - PM2.5 Primary (Filt + Cond)0.0128 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00013216
Emission Comment: On-road State EFs - Single Unit Short-haul Truck, assumed 10mi/gal
SO2 - Sulf ur Dioxide 0.0001 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.0000010325
Emission Comment: SO2 calculated from fuel sulfur content
NOX - Nitrogen Oxides 0.2337 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.002412952499999
Emission Comment: On-road State EFs - Single Unit Short-haul Truck, assumed 10mi/gal
VOC - Volatile Organic Compounds 0.0371 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.000383057499999
Emission Comment: On-road State EFs - Single Unit Short-haul Truck, assumed 10mi/gal
CO - Carbon Monoxide 0.1219 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.0012586175
Emission Comment: On-road State EFs - Single Unit Short-haul Truck, assumed 10mi/gal
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
Emission Unit ID Unit Process ID Throughput Operations
185723
Service Trucks
2
Service Trucks
Annual Throughput: 16.6 GALLONS (Diesel) (Input)
Start Time: 08:00 AM, Stop Time: 04:00 PM
Average Hours/Day: 4.0, Days/Week: 3.0, Weeks/Year: 10.0
Actual Days/Year: 30.0
Actual Hours/Year: 120.0
Monthly Operations: Jan: 7.1%, Feb: 6.0%, Mar: 9.7%, Apr: 7.5%, May: 10.5%, Jun: 8.2%, Jul: 9.5%, Aug:
10.7%, Sep: 11.2%, Oct: 6.2%, Nov: 7.1%, Dec: 6.3%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.0001 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00000083
Emission Comment: On-road State EFs - Single Unit Short-haul Truck, assumed 10mi/gal
PM25-PRI - PM2.5 Primary (Filt + Cond)0.0001 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00000083
Emission Comment: On-road State EFs - Single Unit Short-haul Truck, assumed 10mi/gal
SO2 - Sulf ur Dioxide 0.0002 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00000166
Emission Comment: SO2 calculated from fuel sulfur content
NOX - Nitrogen Oxides 0.022 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.0001826
Emission Comment: On-road State EFs - Single Unit Short-haul Truck, assumed 10mi/gal
VOC - Volatile Organic Compounds 0.0021 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00001743
Emission Comment: On-road State EFs - Single Unit Short-haul Truck, assumed 10mi/gal
CO - Carbon Monoxide 0.0198 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00016434
Emission Comment: On-road State EFs - Single Unit Short-haul Truck, assumed 10mi/gal
Emission Unit ID Unit Process ID Throughput Operations
54/64
185724
Kubota Tractor
1
Kubota Tractor
Annual Throughput: 16.2 GALLONS (Diesel) (Input)
Start Time: 08:00 AM, Stop Time: 04:00 PM
Average Hours/Day: 1.0, Days/Week: 1.0, Weeks/Year: 10.0
Actual Days/Year: 10.0
Actual Hours/Year: 10.0
Monthly Operations: Jan: 7.1%, Feb: 6.0%, Mar: 9.7%, Apr: 7.5%, May: 10.5%, Jun: 8.2%, Jul: 9.5%, Aug:
10.7%, Sep: 11.2%, Oct: 6.2%, Nov: 7.1%, Dec: 6.3%
Emission Unit ID Unit Process ID Throughput Operations
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.013 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.000105299999999
Emission Comment: Non-road Tier 4
PM25-PRI - PM2.5 Primary (Filt + Cond)0.012 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.000097199999999
Emission Comment: Non-road Tier 4
SO2 - Sulf ur Dioxide 0.0002 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00000162
Emission Comment: SO2 calculated from fuel sulfur content
NOX - Nitrogen Oxides 0.2317 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.001876769999999
Emission Comment: Non-road Tier 4
VOC - Volatile Organic Compounds 0.0122 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00009882
Emission Comment: Non-road Tier 4
CO - Carbon Monoxide 0.2147 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00173907
Emission Comment: Non-road Tier 4
Emission Unit ID Unit Process ID Throughput Operations
185725
On-site Pickup
Trucks
1
On-site Pickup
Trucks
Annual Throughput: 733.0 GALLONS (Gasoline) (Input)
Start Time: 08:00 AM, Stop Time: 04:00 PM
Average Hours/Day: 3.0, Days/Week: 4.0, Weeks/Year: 50.0
Actual Days/Year: 200.0
Actual Hours/Year: 600.0
Monthly Operations: Jan: 9.1%, Feb: 7.4%, Mar: 8.7%, Apr: 8.9%, May: 8.6%, Jun: 8.4%, Jul: 6.8%, Aug:
12.3%, Sep: 6.9%, Oct: 6.6%, Nov: 9.3%, Dec: 6.9%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.0001 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00003665
Emission Comment: On-road State EFs - Passenger Truck, assumed 15mi/gal
PM25-PRI - PM2.5 Primary (Filt + Cond)0.0001 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00003665
Emission Comment: On-road State EFs - Passenger Truck, assumed 15mi/gal
SO2 - Sulf ur Dioxide 0.0001 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00003665
Emission Comment: SO2 calculated from fuel sulfur content
NOX - Nitrogen Oxides 0.0022 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.0008063
55/64
Emission Comment: On-road State EFs - Passenger Truck, assumed 15mi/gal
VOC - Volatile Organic Compounds 0.0019 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00069635
Emission Comment: On-road State EFs - Passenger Truck, assumed 15mi/gal
CO - Carbon Monoxide 0.0697 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.02554505
Emission Comment: On-road State EFs - Passenger Truck, assumed 15mi/gal
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
Emission Unit ID Unit Process ID Throughput Operations
185726
JLG Lif t
1
JLG Lif t
Annual Throughput: 72.0 GALLONS (Gasoline) (Input)
Start Time: 08:00 AM, Stop Time: 04:00 PM
Average Hours/Day: 2.0, Days/Week: 2.2, Weeks/Year: 20.0
Actual Days/Year: 43.0
Actual Hours/Year: 86.0
Monthly Operations: Jan: 9.1%, Feb: 7.4%, Mar: 8.7%, Apr: 8.9%, May: 8.6%, Jun: 8.4%, Jul: 6.8%, Aug:
12.3%, Sep: 6.9%, Oct: 6.6%, Nov: 9.3%, Dec: 6.9%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.003 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.000108
Emission Comment: Off-road Natl EFs - Aerial Lif t
PM25-PRI - PM2.5 Primary (Filt + Cond)0.0027 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.0000972
Emission Comment: Off-road Natl EFs - Aerial Lif t
SO2 - Sulf ur Dioxide 0.0001 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.0000036
Emission Comment: SO2 calculated from fuel sulfur content
NOX - Nitrogen Oxides 0.5535 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.019926
Emission Comment: Off-road Natl EFs - Aerial Lif t
VOC - Volatile Organic Compounds 0.3238 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.011656799999999
Emission Comment: Off-road Natl EFs - Aerial Lif t
CO - Carbon Monoxide 6.2344 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.2244384
Emission Comment: Off-road Natl EFs - Aerial Lif t
Emission Unit ID Unit Process ID Throughput Operations
185727
Pow er Wash
Trailers
1
Pow er Wash
Trailers (Unleaded)
Process w as not operating, or w as not required to report emissions, during the reporting period.
Emission Unit ID Unit Process ID Throughput Operations
185727
Pow er Wash
Trailers
2
Pow er Wash
Trailers (Diesel)
Process w as not operating, or w as not required to report emissions, during the reporting period.
Emission Unit ID Unit Process ID Throughput Operations
56/64
185727
Pow er Wash
Trailers
3
Pow er Wash
Trailers (Propane)
Annual Throughput: 122.0 GALLONS (Liquified Petroleum Gas (LPG)) (Input)
Start Time: 08:00 PM, Stop Time: 04:00 PM
Average Hours/Day: 5.0, Days/Week: 4.0, Weeks/Year: 25.0
Actual Days/Year: 100.0
Actual Hours/Year: 500.0
Monthly Operations: Jan: 8.5%, Feb: 7.7%, Mar: 8.5%, Apr: 8.2%, May: 8.5%, Jun: 8.2%, Jul: 8.5%, Aug:
8.5%, Sep: 8.2%, Oct: 8.5%, Nov: 8.2%, Dec: 8.5%
Emission Unit ID Unit Process ID Throughput Operations
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.0012989148468 GAL - GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000079233805654
Overall Control Efficiency: 0.0%
Emission Comment: Non-road SCC value 2267006030 (EPA Webf ire)
PM25-PRI - PM2.5 Primary (Filt + Cond)0.0012989148468 GAL - GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.000079233805654
Overall Control Efficiency: 0.0%
Emission Comment: Non-road SCC value 2267006030 (EPA Webf ire)
SO2 - Sulf ur Dioxide 0.00026257434935 GAL - GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.00001601703531
Overall Control Efficiency: 0.0%
Emission Comment: Non-road SCC value 2267006030 (EPA Webf ire)
NOX - Nitrogen Oxides 0.10653370482 GAL - GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.00649855599402
Overall Control Efficiency: 0.0%
Emission Comment: Non-road SCC value 2267006030 (EPA Webf ire)
VOC - Volatile Organic Compounds 0.029048506748 GAL - GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.001771958911628
Overall Control Efficiency: 0.0%
Emission Comment: Non-road SCC value 2267006030 (EPA Webf ire)
CO - Carbon Monoxide 0.57440496693 GAL - GALLONS 8_2 - EPA WebFIRE Emission Factor (pre-control)0.03503870298273
Overall Control Efficiency: 0.0%
Emission Comment: Non-road SCC value 2267006030 (EPA Webf ire)
Emission Unit ID Unit Process ID Throughput Operations
185728
Vermeer Vactor
Trailer
1
Vermeer Vactor
Trailer
Annual Throughput: 52.7 GALLONS (Distillate Oil (Diesel)) (Input)
Start Time: 08:00 AM, Stop Time: 04:00 PM
Average Hours/Day: 5.0, Days/Week: 2.0, Weeks/Year: 5.0
Actual Days/Year: 10.0
Actual Hours/Year: 50.0
Monthly Operations: Jan: 7.1%, Feb: 6.0%, Mar: 9.7%, Apr: 7.5%, May: 10.5%, Jun: 8.2%, Jul: 9.5%, Aug:
10.7%, Sep: 11.2%, Oct: 6.2%, Nov: 7.1%, Dec: 6.3%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.001 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00002635
57/64
Emission Comment: Non-road Tier 4
PM25-PRI - PM2.5 Primary (Filt + Cond)0.0009 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.000023715
Emission Comment: Non-road Tier 4
SO2 - Sulf ur Dioxide 0.0002 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00000527
Emission Comment: SO2 calculated from fuel sulfur content
NOX - Nitrogen Oxides 0.1452 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00382602
Emission Comment: Non-road Tier 4
VOC - Volatile Organic Compounds 0.0076 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00020026
Emission Comment: Non-road Tier 4
CO - Carbon Monoxide 0.1789 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.004714015
Emission Comment: Non-road Tier 4
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
Emission Unit ID Unit Process ID Throughput Operations
185729
Grove Crane Truck
1
Grove Crane Truck
Annual Throughput: 67.2 GALLONS (Distillate Oil (Diesel)) (Input)
Start Time: 08:00 AM, Stop Time: 04:00 PM
Average Hours/Day: 5.0, Days/Week: 2.0, Weeks/Year: 10.0
Actual Days/Year: 20.0
Actual Hours/Year: 100.0
Monthly Operations: Jan: 7.1%, Feb: 6.0%, Mar: 9.7%, Apr: 7.5%, May: 10.5%, Jun: 8.2%, Jul: 9.5%, Aug:
10.7%, Sep: 11.2%, Oct: 6.2%, Nov: 7.1%, Dec: 6.3%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.0007 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00002352
Emission Comment: Non-road Tier 4 Interim
PM25-PRI - PM2.5 Primary (Filt + Cond)0.0006 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.000020159999999
Emission Comment: Non-road Tier 4 Interim
SO2 - Sulf ur Dioxide 0.0002 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00000672
Emission Comment: SO2 calculated from fuel sulfur content
NOX - Nitrogen Oxides 0.1236 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00415296
Emission Comment: Non-road Tier 4 Interim
VOC - Volatile Organic Compounds 0.0065 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.0002184
Emission Comment: Non-road Tier 4 Interim
CO - Carbon Monoxide 0.1626 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00546336
Emission Comment: Non-road Tier 4 Interim
Emission Unit ID Unit Process ID Throughput Operations
58/64
185732
Godw in Trash
Pumps
1
Godw in Trash
Pumps
Annual Throughput: 106.0 GALLONS (Distillate Oil (Diesel)) (Input)
Start Time: 12:00 AM, Stop Time: 11:30 PM
Average Hours/Day: 10.0, Days/Week: 2.0, Weeks/Year: 2.0
Actual Days/Year: 4.0
Actual Hours/Year: 40.0
Monthly Operations: Jan: 7.1%, Feb: 6.0%, Mar: 9.7%, Apr: 7.5%, May: 10.5%, Jun: 8.2%, Jul: 9.5%, Aug:
10.7%, Sep: 11.2%, Oct: 6.2%, Nov: 7.1%, Dec: 6.3%
Emission Unit ID Unit Process ID Throughput Operations
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.0052 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.0002756
Emission Comment: Non-road Tier 4 Interim
PM25-PRI - PM2.5 Primary (Filt + Cond)0.0048 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.000254399999999
Emission Comment: Non-road Tier 4 Interim
SO2 - Sulf ur Dioxide 0.0002 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.0000106
Emission Comment: SO2 calculated from fuel sulfur content
NOX - Nitrogen Oxides 0.1224 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.006487199999999
Emission Comment: Non-road Tier 4 Interim
VOC - Volatile Organic Compounds 0.0092 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.0004876
Emission Comment: Non-road Tier 4 Interim
CO - Carbon Monoxide 0.1708 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.0090524
Emission Comment: Non-road Tier 4 Interim
Emission Unit ID Unit Process ID Throughput Operations
185733
Unleaded Fuel
Storage Tank
1
Unleaded Fuel
Storage Tank -
Working Loss
Annual Throughput: 4.542 1000 GALLONS (Gasoline) (Input)
Start Time: 08:00 AM, Stop Time: 04:00 PM
Average Hours/Day: 1.0, Days/Week: 1.0, Weeks/Year: 3.0
Actual Days/Year: 3.0
Actual Hours/Year: 3.0
Monthly Operations: Jan: 0.0%, Feb: 0.0%, Mar: 33.2%, Apr: 0.0%, May: 0.0%, Jun: 0.0%, Jul: 33.4%, Aug:
0.0%, Sep: 0.0%, Oct: 0.0%, Nov: 0.0%, Dec: 33.5%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
VOC - Volatile Organic Compounds 5.1997 E3GAL - 1000 GALLONS 2_1 - Engineering Judgement (post-control EF)0.0118085187
Emission Comment: used EPA Tanks 5.0 outputs to calculate EF
Emission Unit ID Unit Process ID Throughput Operations
59/64
185733
Unleaded Fuel
Storage Tank
2
Unleaded Fuel
Storage Tanks -
Standing Loss
Annual Throughput: 4.542 1000 GALLONS (Gasoline) (Input)
Start Time: 12:00 AM, Stop Time: 11:30 PM
Average Hours/Day: 24.0, Days/Week: 7.0, Weeks/Year: 52.0
Actual Days/Year: 365.0
Actual Hours/Year: 8,760.0
Monthly Operations: Jan: 8.5%, Feb: 7.7%, Mar: 8.5%, Apr: 8.2%, May: 8.5%, Jun: 8.2%, Jul: 8.5%, Aug:
8.5%, Sep: 8.2%, Oct: 8.5%, Nov: 8.2%, Dec: 8.5%
Emission Unit ID Unit Process ID Throughput Operations
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
VOC - Volatile Organic Compounds 28.453 E3GAL - 1000 GALLONS 2_1 - Engineering Judgement (post-control EF)0.064616762999999
Emission Comment: used EPA Tanks 5.0 outputs to calculate EF
Emission Unit ID Unit Process ID Throughput Operations
185954
Wastew ater
Treatment Process
1
Wastew ater
Treatment Process
Annual Throughput: 19,330.0 MILLION GALLONS (Wastew ater) (Output)
Start Time: 12:00 AM, Stop Time: 11:30 PM
Average Hours/Day: 24.0, Days/Week: 7.0, Weeks/Year: 52.0
Actual Days/Year: 365.0
Actual Hours/Year: 8,760.0
Monthly Operations: Jan: 9.4%, Feb: 7.5%, Mar: 9.7%, Apr: 10.0%, May: 8.9%, Jun: 8.3%, Jul: 7.7%, Aug:
7.7%, Sep: 7.3%, Oct: 7.9%, Nov: 7.5%, Dec: 7.9%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
VOC - Volatile Organic Compounds 0.98 E6GAL - MILLION GALLONS 2_2 - Engineering Judgement (pre-control EF)9.4717
Overall Control Efficiency: 0.0%
Emission Comment: calculated using TRI based unit process emissions (accounting for biof ilter control and floating cover digester fugitive emissions)
NH3 - Ammonia 0.169 E6GAL - MILLION GALLONS 2_2 - Engineering Judgement (pre-control EF)1.633385
Overall Control Efficiency: 0.0%
Emission Comment: EF taken from EPA EIIP Document on Estimating Ammonia emissions from Anthropogenic non-agricultural sources (draf t f inal 2004)
- Table II-5
Emission Unit ID Unit Process ID Throughput Operations
186373
Jenbacher IC
Engine 3
1
Jenbacher IC
Engine 3 Digester
Gas
Annual Throughput: 114.59 MILLION CUBIC FEET (Process Gas) (Input)
Start Time: 12:00 AM, Stop Time: 11:30 PM
Average Hours/Day: 22.1, Days/Week: 5.4, Weeks/Year: 45.0
Actual Days/Year: 250.0
Actual Hours/Year: 5,532.0
Monthly Operations: Jan: 9.9%, Feb: 10.9%, Mar: 6.2%, Apr: 4.0%, May: 4.3%, Jun: 11.8%, Jul: 10.3%, Aug:
3.4%, Sep: 3.8%, Oct: 13.7%, Nov: 13.4%, Dec: 8.4%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)6.43 E6FT3 - MILLION CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.36840685
Overall Control Efficiency: 0.0%
Emission Comment: PM value from Manufacturer guaranteed emissions limits per hp-hr - converted to limits per MMSCF based on blended gas makeup
60/64
PM10-FIL - PM10 Filterable 0.05 E6FT3 - MILLION CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.00286475
Overall Control Efficiency: 0.0%
Emission Comment: calculated from PM10 Pri and PM Cond
PM25-PRI - PM2.5 Primary (Filt + Cond)6.43 E6FT3 - MILLION CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.36840685
Overall Control Efficiency: 0.0%
Emission Comment: Assumed equal to PM 10 per AP-42 Table 3.2-2, Uncontrolled emission factors for 4-stroke lean-burn engines
PM25-FIL - PM2.5 Filterable 0.05 E6FT3 - MILLION CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.00286475
Overall Control Efficiency: 0.0%
Emission Comment: calculated from PM25 Pri and PM Cond
PM-CON - PM Condensible 6.38 E6FT3 - MILLION CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.3655421
Overall Control Efficiency: 0.0%
Emission Comment: ratio of primary based on AP-42 Uncontrolled emission f actors f or 4-stroke lean-burn engines
SO2 - Sulf ur Dioxide 13.04 E6FT3 - MILLION CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.7471268
Overall Control Efficiency: 0.0%
Emission Comment: calculated from blended gas sulf ur content
NOX - Nitrogen Oxides 87.83 E6FT3 - MILLION CUBIC FEET 4_2 - Stack Test (pre-control EF)5.03221985
Stack Test Date: 03/28/2023
Overall Control Efficiency: 0.0%
VOC - Volatile Organic Compounds 27.85 E6FT3 - MILLION CUBIC FEET 4_2 - Stack Test (pre-control EF)1.59566575
Stack Test Date: 03/28/2023
Overall Control Efficiency: 0.0%
CO - Carbon Monoxide 428.42 E6FT3 - MILLION CUBIC FEET 4_2 - Stack Test (pre-control EF)24.5463239
Stack Test Date: 03/28/2023
Overall Control Efficiency: 0.0%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
Emission Unit ID Unit Process ID Throughput Operations
186377
Yamaha ATV
1
Yamaha ATV
Annual Throughput: 3.4 GALLONS (Gasoline) (Input)
Start Time: 08:00 AM, Stop Time: 05:00 PM
Average Hours/Day: 1.0, Days/Week: 1.0, Weeks/Year: 10.0
Actual Days/Year: 10.0
Actual Hours/Year: 10.0
Monthly Operations: Jan: 9.1%, Feb: 7.4%, Mar: 8.7%, Apr: 8.9%, May: 8.6%, Jun: 8.4%, Jul: 6.8%, Aug:
12.3%, Sep: 6.9%, Oct: 6.6%, Nov: 9.3%, Dec: 6.9%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.0027 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00000459
Emission Comment: Off-road Natl EFs - ATV
61/64
PM25-PRI - PM2.5 Primary (Filt + Cond)0.0024 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.000004079999999
Emission Comment: Off-road Natl EFs - ATV
SO2 - Sulf ur Dioxide 0.0001 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00000017
Emission Comment: SO2 calculated from fuel sulfur content
NOX - Nitrogen Oxides 0.3717 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00063189
Emission Comment: Engine tag has EF for HC/NOX
VOC - Volatile Organic Compounds 0.0196 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.000033319999999
Emission Comment: Engine tag has EF for HC/NOX
CO - Carbon Monoxide 11.6808 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.01985736
Emission Comment: Engine tag has EF for CO
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
Emission Unit ID Unit Process ID Throughput Operations
186664
Jenbacher IC
Engine 4
1
Jenbacher IC
Engine 4 Digester
Gas
Annual Throughput: 87.02 MILLION CUBIC FEET (Process Gas) (Input)
Start Time: 12:00 AM, Stop Time: 11:30 PM
Average Hours/Day: 21.1, Days/Week: 5.2, Weeks/Year: 37.0
Actual Days/Year: 193.0
Actual Hours/Year: 4,080.0
Monthly Operations: Jan: 1.9%, Feb: 14.2%, Mar: 12.2%, Apr: 15.4%, May: 7.1%, Jun: 7.8%, Jul: 7.5%, Aug:
11.7%, Sep: 8.1%, Oct: 0.0%, Nov: 4.6%, Dec: 9.5%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)6.43 E6FT3 - MILLION CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.2797693
Overall Control Efficiency: 0.0%
Emission Comment: PM value from Manufacturer guaranteed emissions limits per hp-hr - converted to limits per MMSCF based on blended gas makeup
PM10-FIL - PM10 Filterable 0.05 E6FT3 - MILLION CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.0021755
Overall Control Efficiency: 0.0%
Emission Comment: calculated from PM10 Pri and PM Cond
PM25-PRI - PM2.5 Primary (Filt + Cond)6.43 E6FT3 - MILLION CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.2797693
Overall Control Efficiency: 0.0%
Emission Comment: Assumed equal to PM 10 per AP-42 Table 3.2-2, Uncontrolled emission factors for 4-stroke lean-burn engines
PM25-FIL - PM2.5 Filterable 0.05 E6FT3 - MILLION CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.0021755
Overall Control Efficiency: 0.0%
Emission Comment: calculated from PM25 Pri and PM Cond
PM-CON - PM Condensible 6.38 E6FT3 - MILLION CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.2775938
Overall Control Efficiency: 0.0%
Emission Comment: ratio of primary based on AP-42 Uncontrolled emission f actors f or 4-stroke lean-burn engines
SO2 - Sulf ur Dioxide 13.04 E6FT3 - MILLION CUBIC FEET 2_2 - Engineering Judgement (pre-control EF)0.5673704
62/64
Overall Control Efficiency: 0.0%
Emission Comment: calculated from blended gas sulf ur content
NOX - Nitrogen Oxides 83.54 E6FT3 - MILLION CUBIC FEET 4_2 - Stack Test (pre-control EF)3.6348254
Stack Test Date: 12/14/2023
Overall Control Efficiency: 0.0%
VOC - Volatile Organic Compounds 29.99 E6FT3 - MILLION CUBIC FEET 4_2 - Stack Test (pre-control EF)1.3048649
Stack Test Date: 12/14/2023
Overall Control Efficiency: 0.0%
CO - Carbon Monoxide 366.3 E6FT3 - MILLION CUBIC FEET 4_2 - Stack Test (pre-control EF)15.937713
Stack Test Date: 12/14/2023
Overall Control Efficiency: 0.0%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
Emission Unit ID Unit Process ID Throughput Operations
186665
On-site Diesel
Pickup Trucks
1
On-site Diesel
Pickup Trucks
Annual Throughput: 264.6 GALLONS (Diesel) (Input)
Start Time: 08:00 AM, Stop Time: 04:00 PM
Average Hours/Day: 2.0, Days/Week: 1.0, Weeks/Year: 20.0
Actual Days/Year: 20.0
Actual Hours/Year: 40.0
Monthly Operations: Jan: 7.1%, Feb: 6.0%, Mar: 9.7%, Apr: 7.5%, May: 10.5%, Jun: 8.2%, Jul: 9.5%, Aug:
10.7%, Sep: 11.2%, Oct: 6.2%, Nov: 7.1%, Dec: 6.3%
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
PM10-PRI - PM10 Primary (Filt + Cond)0.0001 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00001323
Emission Comment: On-road State EFs - Single Unit Short-haul Truck, assumed 10mi/gal
PM25-PRI - PM2.5 Primary (Filt + Cond)0.0001 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00001323
Emission Comment: On-road State EFs - Single Unit Short-haul Truck, assumed 10mi/gal
SO2 - Sulf ur Dioxide 0.0002 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00002646
Emission Comment: SO2 calculated from fuel sulfur content
NOX - Nitrogen Oxides 0.028 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.0037044
Emission Comment: On-road State EFs - Single Unit Short-haul Truck, assumed 10mi/gal
VOC - Volatile Organic Compounds 0.0021 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00027783
Emission Comment: On-road State EFs - Single Unit Short-haul Truck, assumed 10mi/gal
CO - Carbon Monoxide 0.0215 GAL - GALLONS 2_1 - Engineering Judgement (post-control EF)0.00284445
Emission Comment: On-road State EFs - Single Unit Short-haul Truck, assumed 10mi/gal,50/50 roadw ays
Emission Unit ID Unit Process ID Throughput Operations
63/64
187449
Green Waste Pile
1
Green Waste Pile
Annual Throughput: 8,822.0 TONS (Sludge) (Input)
Start Time: 12:00 AM, Stop Time: 11:30 PM
Average Hours/Day: 24.0, Days/Week: 7.0, Weeks/Year: 52.0
Actual Days/Year: 365.0
Actual Hours/Year: 8,760.0
Monthly Operations: Jan: 10.4%, Feb: 10.4%, Mar: 6.6%, Apr: 6.5%, May: 14.1%, Jun: 3.5%, Jul: 10.2%,
Aug: 10.4%, Sep: 7.0%, Oct: 10.5%, Nov: 3.5%, Dec: 7.0%
Emission Unit ID Unit Process ID Throughput Operations
Pollutant Emis. Factor (Lbs/UOM)Emis. Factor UOM Calculation Method Estimated Emis. (Tons)
VOC - Volatile Organic Compounds 0.3 TON - TONS 2_2 - Engineering Judgement (pre-control EF)1.3233
Overall Control Efficiency: 0.0%
Emission Comment: Table 1 of Compost Emission Factor Report, San Joaquin Valley APCD, Revised 3/21/2023 - normalized by compost throughput to
obtain EF
NH3 - Ammonia 0.03 TON - TONS 2_2 - Engineering Judgement (pre-control EF)0.132329999999999
Overall Control Efficiency: 0.0%
Emission Comment: Table 1 of Compost Emission Factor Report, San Joaquin Valley APCD, Revised 3/21/2023 - normalized by compost throughput to
obtain EF
64/64
Appendix F

Air pollution control equipment
1

Air Pollution Control Methods and
Treatment Systems
1. Ferric chloride dosage into raw influent to reduce sulfur content of
digester gas.
2. Treatment of Digester Gas to reduce H2S to < 10ppm. See Table 1 and
Figure 1 below.
3. Use of ultra-low sulfur diesel fuel in diesel-powered engines and
equipment.
4. Use of low-ash engine oil in engines and equipment.
5. Biofilter treatment of foul air from high H2S environments to reduce
odors and air pollution. See Table 2 and Figure 2 below.

2

Table 1. Digester Gas H2S Removal Vessel System Data
H2S REMOVAL TANK 1 H2S REMOVAL TANK 2
ASSET ID TK270510 TK270520
MANUFACTURER Unison Solutions
MODEL PGS-1500-272-H
VESSEL DIA 8 ft 8 ft
VESSEL VOLUME 603 CF 603 CF
MEDIA Iron hydroxide media
QTY OF MEDIA 22,000 lbs 22,000 lbs
STARTUP Jul 2021 Jul 2024
TREATMENT CAPACITY 1500 SCFM
REMOVAL EFFICIENCY Achieves <10 ppm H2S with digester gas up to 150
ppm (~95% removal)
OPERATION 1 Vessel Duty, 1 Standby, Option to run two
vessels in parrallel
DAILY VAR None
SEASONAL VAR None

Figure 1. Digester Gas H2S Removal Vessel System

3

Table 2. Odor Control Biofilter System Data
BIOFILTER 1 BIOFILTER 2 BIOFILTER 3
ASSET ID BIO120001 BIO120002 BIO120003
MEDIA BIOREM proprietary media
MEDIA VOLUME 6210 CF 6210 CF 6210 CF
MEDIA EBRT 45 s 45 s 45 s
STARTUP 2020 2020 2024
TREATMENT CAPACITY 25,000 CFM Total
REMOVAL EFFICIENCY 90% VOC, 90% Ammonia, 99.5% H2S
OPERATION Three biofilters in parallel
DAILY VAR None
SEASONAL VAR None

Figure 2. Odor Control Biofilter System
Appendix G

Compliance Monitoring Activities
Monitoring Activities and Devices
Activity Preformed by Testing
Method or
Monitoring
Device
Unit Parameters
Opacity Certified
observer
Method 9* · Boiler 1 & 2
· JMS Engines
· Standby Diesel
Generators
· Waste Gas Flares
1 & 2
· Waste Oil
Heaters
Plume
Opacity
Stack Testing Qualified third
party
Method 320 * · JMS Engines NOx, CO,
VOC, &
NMHC
Calculation of
12M Rolling NOx
Emissions
Chief Engineer KWH meter
(coupled with
stack test
results as
prescribed in
Title V
permit)
· JMS Engines NOx
Calculation of
12M Rolling
Operating Hours
Chief Engineer Non-
resettable
hour meter
· Standby Diesel
Generators
Hours
Calculation of
Calendar Year
Operating Hours
Chief Engineer Non-
resettable
hour meter
· Standby Diesel
Generators
Hours
*Examples attached.

Method 9 Opacity Reading
Cogen Jenbacher #1 (Furthest North), June 14, 2024
7e5df598-536a-4c33-8169-719a37046bfe
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Complete all fields below. Any of the
following that are operated within a
Calendar Quarter must be
evaluated/recorded at least once that
same quarter: Cogen Jenbacher #1
(Furthest North) Cogen Jenbacher #2
Cogen Jenbacher #3 Cogen
Jenbacher #4 (Furthest South) Cogen
Waukesha #5 (Furthest South) Boiler
#1 (KBC - South) Boiler #2 (Burnham
- North Standby Engine #6 Power
Gen (West) Standby Engine #7 Power
Gen (East) Standby Engine #9 RSS
(South) Standby Engine #10 Admin
Standby Engine #11 RSS (North)
Standby Engine #12 Headworks
(East) Standby Engine #13
Headworks (West) Waste Gas Flare
#1 (North) Waste Gas Flare #2 (South)
Items you'll need: Compass (or app)
Stopwatch (or app) Range finder
(with vertical adjustment) Optional:
sling psychrometer thermometer
Facility Information
Company Name Central Valley WRF
Street Address 800 W. Central Valley Rd.
City, State, Zip Salt Lake City, UT 84119
Key Contact Phone Bryan Mansell 801-870-4414
Source ID 10414
Facility Wastewater Treatment Facility
Equipment Information
Equipment Cogen Jenbacher #1 (Furthest North)
Operating Mode ~75% Capacity
Emission Control No
Emission Point
Type Exhaust Stack
Describe Emission Pt if needed
Height of Emission Pt above ground,
ft
Jenbacher_45ft
Observer should be at least 3
effective effective stack heights (3 x
stack height relative to observer
eyes). Observer must also be
approximately perpendicular to
plume.
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Ensure maximum contrast between
plume and background. White smoke
contrasts well with green tree. Black
smoke contrasts well with blue sky.
Buildings or other object may also be
suitable if colors contrast with plume.
Height of Emission Pt relative to
Observer Eyes, ft
5
Distance to Emission Pt from
Observer, ft
15
Emission Pt Slant Angle Calculated,
deg
18.43
Direction from Observer to Emission
Pt
NW
Degrees from Observer to Emission
Pt
8
Observation point must be point of
greatest opacity and not steam. If
steam present as attached plume,
observe after point of steam
dissipation. If steam present as
detached plume, observe prior to
steam formation or after point of
steam dissipation.
Emission Pt Changes during
Observations
None
Observation Pt 1 Stack width above
Emission Pt?
Yes
Observation Pt Changes during
Observations
None
Observation Conditions
Date June 14, 2024
Sky Conditions Clear
Precipitation (Y/N)No
Wind Direction SE
Wind Speed, mph 13 to 18
Ambient Temp, ˚F 86
Relative Humidity, %17
Wet Bulb Temp calc, F 59.08
Wet Bulb Temp, ˚F
Weather Data
Contrasting Background Blue sky
Background Color Sky blue
Observation Condition changes
during observations
None
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Plume Attributes
Plume Characteristic lacy
Plume Behavior lofting
Emission Color Black
Condensed Water Vapor Present?No
Observation Location in Plume 1 stack width above outlet
Plume Attribute changes during
observations
None
Layout Sketch
Sketch
Include sun, wind, N arrow, emission point/plume, observer. Ensure sun is behind you within
140 deg angle when facing the emission point.
Signed 6/14/2024, 11:22:28 PM UTC
Sketch requirements
Attachments
Comments
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Photos
Videos
Opacity Observations ->
Start Time 11:24
1Min00 0
1Min15 0
1Min30 0
1Min45 0
2Min00 0
2Min15 0
2Min30 0
2Min45 0
3Min00 0
3Min15 0
3Min30 0
3Min45 0
4Min00 0
4Min15 0
4Min30 0
4Min45 0
5Min00 0
5Min15 0
5Min30 0
5Min45 0
6Min00 0
6Min15 0
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6Min30 0
6Min45 0
Missed Reading comments
7Min00
Stop Time 11:30
Make sure to note any conditions that
have changed during the
observations in the notes above.
Observer's Name Dillon Anglin
Observer's Title CoGen
Signature
sign here
Signed 6/14/2024, 11:23:13 PM UTC
Record Review
Reviewer Comments none
Reviewer's Name Porscha Swain
Reviewer's Title Environmental Compliance Technician
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Reviewer's Signature
sign here
Signed 7/5/2024, 8:29:13 PM UTC
7e5df598-536a-4c33-8169-719a37046bfe
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TEST REPORT SUMMARY

CORPORATE OFFICE
255 Grant St. SE, Suite 600
Decatur, AL 35601
256.351.0121

www.alliancetechnicalgroup.com
Client Information / Test Location Source Information
Central Valley Water Reclamation Facility Engine/Unit ID: Jenbacher #2
Wastewater Treatment Plant
800 W Central Valley Road
Salt Lake City, UT 84119-3379
Engine Make/Model: GE Jenbacher Model JMS
612-F28F02 Generator
Engine
Engine Serial Number: 1322416
Engine Type: Compression Ignition
Engine Date of Manufacture: 01-01-2017
Engine Rating: 2,509 HP

Regulatory Applicability Project No.
40 CFR 60, Subpart JJJJ AST-2023-4301
DAQE-AN104140015-21

Run No. Run 1 Run 2 Run 3 Average
Date 12/15/23 12/15/23 12/15/23 --
Engine Load, % * 96 96 96 96
Nitrogen Oxides Data
Emission Rate, g/bHP-hr 0.41 0.41 0.38 0.40
Emission Limit, g/bHP-hr -- -- -- 0.55
Percent of Limit, % -- -- -- 72
Carbon Monoxide Data
Emission Rate, g/bHP-hr 1.94 1.88 1.86 1.89
Emission Limit, g/bHP-hr -- -- -- 2.5
Percent of Limit, % -- -- -- 76
Volatile Organic Compounds Data
Emission Factor, g/bHP-hr 0.16 0.15 0.16 0.16
Emission Limit, g/bHP-hr -- -- -- 1.0
Percent of Limit, % -- -- -- 16
Non-Methane Hydrocarbons Data
Emission Rate, g/bHP-hr 0.28 0.27 0.27 0.27
Emission Limit, g/bHP-hr -- -- -- 0.3
Percent of Limit, % -- -- -- 91
Methane Data
Emission Factor, g/bHP-hr 3.84 3.69 3.73 3.75
Formaldehyde Data
Emission Factor, g/bHP-hr 0.23 0.22 0.22 0.22
* Performance testing was conducted while the engine was operating at the highest achievable load at current site conditions.

TEST REPORT SUMMARY

CORPORATE OFFICE
255 Grant St. SE, Suite 600
Decatur, AL 35601
256.351.0121

www.alliancetechnicalgroup.com
Client Information / Test Location Source Information
Central Valley Water Reclamation Facility Engine/Unit ID: Jenbacher #4
Wastewater Treatment Plant
800 W Central Valley Road
Salt Lake City, UT 84119-3379
Engine Make/Model: GE Jenbacher Model JMS
612-F28F02 Generator
Engine
Engine Serial Number: 1322446
Engine Type: Compression Ignition
Engine Date of Manufacture: 01-01-2018
Engine Rating: 2,509 HP

Regulatory Applicability Project No.
40 CFR 60, Subpart JJJJ AST-2023-4301
DAQE-AN104140015-21
Run No. Run 1 Run 2 Run 3 Average
Date 12/14/23 12/14/23 12/14/23 --
Engine Load, % * 96 96 96 96
Nitrogen Oxides Data
Emission Rate, g/bHP-hr 0.44 0.42 0.33 0.39
Emission Limit, g/bHP-hr -- -- -- 0.55
Percent of Limit, % -- -- -- 72
Carbon Monoxide Data
Emission Rate, g/bHP-hr 1.57 1.72 1.84 1.71
Emission Limit, g/bHP-hr -- -- -- 2.0
Percent of Limit, % -- -- -- 86
Volatile Organic Compounds Data
Emission Factor, g/bHP-hr 0.13 0.13 0.15 0.14
Emission Limit, g/bHP-hr -- -- -- 1.0
Percent of Limit, % -- -- -- 14
Non-Methane Hydrocarbons Data
Emission Rate, g/bHP-hr 0.22 0.24 0.27 0.24
Emission Limit, g/bHP-hr -- -- -- 0.3
Percent of Limit, % -- -- -- 81
Methane Data
Emission Factor, g/bHP-hr 3.00 3.38 3.82 3.40
Formaldehyde Data
Emission Factor, g/bHP-hr 0.19 0.20 0.23 0.21
* Performance testing was conducted while the engine was operating at the highest achievable load at current site conditions.

Source Test

Central Valley Water Reclamation Facility
800 W Central Valley Road
Salt Lake City, UT 84119-3379

Sources Tested: Jenbacher Engine #2 &
Jenbacher Engine #4
Test Dates: December 14 & 15, 2023

Project No. AST-2023-4301

Prepared By
Alliance Technical Group, LLC
3683 W 2270 S, Suite E
West Valley City, UT 84120

.
Source Test Report
Source & Contact Information
AST-2023-4301 Central Valley – Salt Lake City, UT Page i

Regulatory Information

Permit Nos. Title V 3500191001 and DAQE-AN104140015-21
Regulatory Citation 40 CFR 60, Subpart JJJJ

Source Information

Source Name Source ID Target Parameters
GE Jenbacher Model JMS 612-
F28F02 Generator Engine Jenbacher #2 NOx, CO, VOC, NMHC
GE Jenbacher Model JMS 612-
F28F02 Generator Engine Jenbacher #4 NOx, CO, VOC, NMHC

Contact Information

Test Location Test Company
Central Valley Water Reclamation Facility
Wastewater Treatment Plant
800 W Central Valley Road
Salt Lake City, UT 84119-3379

Facility Contact
Zack Vanwormer
[e-mail]
[phone]
Ext. 128
Alliance Technical Group, LLC
3683 W 2270 S, Suite E
West Valley City, UT 84120

Project Manager
Charles Horton
[e-mail]
[phone]

Field Team Leader
Robert Burton
[e-mail]
[phone]

QA/QC Manager
Kathleen Shonk
[e-mail]
[phone]

Report Coordinator
Delaine Spangler
[e-mail]

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Source Test Report
Certification Statement
AST-2023-4301 Central Valley – Salt Lake City, UT Page ii

Alliance Technical Group, LLC (Alliance) has completed the source testing as described in this report. Results
apply only to the source(s) tested and operating condition(s) for the specific test date(s) and time(s) identified within
this report. All results are intended to be considered in their entirety, and Alliance is not responsible for use of less
than the complete test report without written consent. This report shall not be reproduced in full or in part without
written approval from the customer.

To the best of my knowledge and abilities, all information, facts and test data are correct. Data presented in this
report has been checked for completeness and is accurate, error-free and legible. Onsite testing was conducted in
accordance with approved internal Standard Operating Procedures. Any deviations or problems are detailed in the
relevant sections in the test report.

This report is only considered valid once an authorized representative of Alliance has signed in the space provided
below; any other version is considered draft. This document was prepared in portable document format (.pdf) and
contains pages as identified in the bottom footer of this document.

Charles Horton, QSTI
Project Manager
Alliance Technical Group, LLC
Date

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01/04/2024

Source Test Report
Table of Contents

AST-2023-4301 Central Valley – Salt Lake City, UT Page iii

TABLE OF CONTENTS

1.0 Introduction .................................................................................................................................................. 1-1
1.1 Source and Control System Descriptions ................................................................................................. 1-1
1.2 Project Team ............................................................................................................................................ 1-1
1.3 Site Specific Test Plan/Test Protocol & Notification ............................................................................... 1-1
2.0 Testing Methodology .................................................................................................................................... 2-1
2.1 U.S. EPA Reference Test Methods 1 and 2 – Volumetric Flow Rate ...................................................... 2-1
2.2 U.S. EPA Reference Test Method 3A – Oxygen/Carbon Dioxide ........................................................... 2-1
2.3 U.S. EPA Reference Test Method 320 – BWS, NOx, CO, VOC, and NMHC ........................................ 2-1
2.4 U.S. EPA Reference Test Method 205 – Gas Dilution System Certification ........................................... 2-2
2.5 Quality Assurance/Quality Control – U.S. EPA Reference Test Method 3A .......................................... 2-2
2.6 Quality Assurance/Quality Control – U.S. EPA Reference Method 320 ................................................. 2-3

LIST OF TABLES

Table 1-1: Project Team ........................................................................................................................................... 1-1
Table 2-1: Source Testing Methodology .................................................................................................................. 2-1

APPENDICES
Appendix A Sample Calculations
Appendix B Field Data
Appendix C Quality Assurance/Quality Control Data
Appendix D Engine Operating Data
Appendix E Site Specific Test Plan
4 of 87

Introduction

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Introduction

AST-2023-4301 Central Valley – Salt Lake City, UT Page 1-1

1.0 Introduction
Alliance Technical Group, LLC (Alliance) was retained by Central Valley Wastewater Reclamation Facility
(Central Valley) to conduct compliance testing at the Wastewater Treatment Plant in Salt Lake City, Utah. Portions
of the facility are subject to provisions of the 40 CFR 60, Subpart JJJJ and the Utah Department of Environmental
Quality, Division of Air Quality (UDAQ) Title V Permit No. 3500191001 and Approval Order (AO) DAQE-
AN104140015-21. Testing was conducted to determine the emission rates of nitrogen oxides (NOx), carbon
monoxide (CO), volatile organic compounds (VOC), and non-methane hydrocarbons (NMHC) from the exhausts of
two (2) GE Jenbacher Model JSM 612-F28F02 engines designated as Jenbacher #2 and Jenbacher #4. The VOC
emissions do not include formaldehyde.
1.1 Source and Control System Descriptions
Central Valley operates two (2) GE Jenbacher Model JMS 612-F28F02 generator engines. Each engine rates at
2,509 horsepower (hp). The engines can be fired on natural gas or digester gas. Testing for Jenbacher #2 and
Jenbacher #4 were conducted while the engines are fired on a mixed gas of blended digester gas and natural gas.
1.2 Project Team
Personnel involved in this project are identified in the following table.

Table 1-1: Project Team

Central Valley Personnel Zack Vanwormer
Regulatory Personnel UDAQ
Alliance Personnel Robert Burton
Dillon Brown
1.3 Site Specific Test Plan/Test Protocol & Notification
Testing was conducted in accordance with the Site Specific Test Plan (SSTP) submitted to UDAQ by Central
Valley.
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Testing Methodology

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Source Test Report
Testing Methodology

AST-2023-4301 Central Valley – Salt Lake City, UT Page 2-1

2.0 Testing Methodology
The emission testing program was conducted in accordance with the test methods listed in Table 2-1. Method
descriptions are provided below while quality assurance/quality control data is provided in Appendix C.

Table 2-1: Source Testing Methodology

Parameter U.S. EPA Reference
Test Methods Notes/Remarks
Volumetric Flow Rate 1 & 2 Full Velocity Traverses
Oxygen / Carbon Dioxide 3A Instrumental Analysis
Moisture Content / Nitrogen Oxides / Carbon
Monoxide / Volatile Organic Compounds /
Non-Methane Hydrocarbons
320 FTIR – Continuous Sampling
Gas Dilution System Certification 205 --
2.1 U.S. EPA Reference Test Methods 1 and 2 – Volumetric Flow Rate
The sampling location and number of traverse (sampling) points were selected in accordance with U.S. EPA
Reference Test Method 1. To determine the minimum number of traverse points, the upstream and downstream
distances were equated into equivalent diameters and compared to Figure 1-2 in U.S. EPA Reference Test Method 1.

Full velocity traverses were conducted in accordance with U.S. EPA Reference Test Method 2 to determine the
average stack gas velocity pressure, static pressure, and temperature. The velocity and static pressure measurement
system consisted of a pitot tube and inclined manometer. The stack gas temperature was measured with a K-type
thermocouple and pyrometer.

Stack gas velocity pressure and temperature readings were recorded during each test run. The data collected was
utilized to calculate the volumetric flow rate in accordance with U.S. EPA Reference Test Method 2.
2.2 U.S. EPA Reference Test Method 3A – Oxygen/Carbon Dioxide
The oxygen (O2) and carbon dioxide (CO2) testing was conducted in accordance with U.S. EPA Reference Test
Method 3A. Data was collected online and reported in one-minute averages. The sampling system consisted of a
stainless-steel probe, Teflon sample line(s), gas conditioning system, and the identified gas analyzer. The gas
conditioning system was a non-contact condenser used to remove moisture from the stack gas. If an unheated
Teflon sample line was used, then a portable non-contact condenser was placed in the system directly after the
probe. Otherwise, a heated Teflon sample line was used. The quality control measures are described in Section 2.5.
2.3 U.S. EPA Reference Test Method 320 – BWS, NOx, CO, VOC, and NMHC
The concentrations of moisture content (BWS), nitrogen oxides (NOx), carbon monoxide (CO), volatile organic
compounds (VOC) and non-methane hydrocarbons (NMHC) were determined in accordance with U.S. EPA Reference
Test Method 320. Each source gas stream was extracted at a constant rate through a heated probe, heated filter and
heated sample line and analyzed with a MKS MultiGas 2030 FTIR operated by a portable computer. The computer has
FTIR spectra of calibration gases stored on the hard drive. These single component calibration spectra are used to
analyze the measured sample spectra. The measured gas components were selected from the spectra library and
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Testing Methodology

AST-2023-4301 Central Valley – Salt Lake City, UT Page 2-2

incorporated into the analytical method. The signal amplitude, linearity, and signal to noise ratio were measured and
recorded to document analyzer performance. A leak check was performed on the sample cell. The instrument path length
was verified using ethylene as the Calibration Transfer Standard. Dynamic spiking was performed using a certified
standard of the target compound or appropriate surrogate in nitrogen with sulfur hexafluoride blended as a tracer to
calculate the dilution factor. All test spectra, interferograms, and analytical method information are recorded and stored
with the calculated analytical results. The quality control measures are described in Section 2.6.
2.4 U.S. EPA Reference Test Method 205 – Gas Dilution System Certification
A calibration gas dilution system field check was conducted in accordance with U.S. EPA Reference Method 205.
Multiple dilution rates and total gas flow rates were utilized to force the dilution system to perform two dilutions on
each mass flow controller. The diluted calibration gases were sent directly to the analyzer, and the analyzer response
recorded in an electronic field data sheet. The analyzer response agreed within 2% of the actual diluted gas
concentration. A second Protocol 1 calibration gas, with a cylinder concentration within 10% of one of the gas
divider settings described above, was introduced directly to the analyzer, and the analyzer response recorded in an
electronic field data sheet. The cylinder concentration and the analyzer response agreed within 2%. These steps
were repeated three (3) times.
2.5 Quality Assurance/Quality Control – U.S. EPA Reference Test Method 3A
Cylinder calibration gases met EPA Protocol 1 (+/- 2%) standards. Copies of all calibration gas certificates are
included in the Quality Assurance/Quality Control Appendix of the report.

Low Level gas was introduced directly to the analyzer. After adjusting the analyzer to the Low Level gas
concentration and once the analyzer reading is stable, the analyzer value was recorded. This process was repeated
for the High Level gas. For the Calibration Error Test, Low, Mid, and High Level calibration gases were
sequentially introduced directly to the analyzer. The Calibration Error for each gas was within 2.0 percent of the
Calibration Span or 0.5% absolute difference.

High or Mid Level gas (whichever was closer to the stack gas concentration) was introduced at the probe and the
time required for the analyzer reading to reach 95 percent or 0.5% (whichever was less restrictive) of the gas
concentration was recorded. The analyzer reading was observed until it reached a stable value, and this value was
recorded. Next, Low Level gas was introduced at the probe and the time required for the analyzer reading to
decrease to a value within 5.0 percent or 0.5% (whichever was less restrictive) was recorded. If the Low Level gas
was zero gas, the acceptable response was 5.0 percent of the upscale gas concentration or 0.5% (whichever was less
restrictive). The analyzer reading was observed until it reached a stable value and this value was recorded. The
measurement system response time and initial system bias were determined from these data. The System Bias for
each gas were within 5.0 percent of the Calibration Span or 0.5% absolute difference.

High or Mid Level gas (whichever was closer to the stack gas concentration) were introduced at the probe. After the
analyzer response was stable, the value was recorded. Next, Low Level gas was introduced at the probe, and the
analyzer value was recorded once it reached a stable response. The System Bias for each gas was within 5.0 percent
of the Calibration Span or 0.5% absolute difference or the data was invalidated and the Calibration Error Test and
System Bias were repeated.

9 of 87

Source Test Report
Testing Methodology

AST-2023-4301 Central Valley – Salt Lake City, UT Page 2-3

The Drift between pre- and post-run System Bias were within 3 percent of the Calibration Span or 0.5% absolute
difference or the Calibration Error Test and System Bias was repeated.

To determine the number of sampling points, a gas stratification check was conducted prior to initiating testing. The
pollutant concentrations were measured at twelve traverse points (as described in Method 1) or three points (16.7,
50.0 and 83.3 percent of the measurement line). Each traverse point was sampled for a minimum of twice the system
response time.

If the pollutant concentration at each traverse point did not differ more than 5% or 0.5 0.3% (whichever was less
restrictive) of the average pollutant concentration, then single point sampling was conducted during the test runs. If
the pollutant concentration did not meet these specifications but differed less than 10% or 0.5% from the average
concentration, then three (3) point sampling was conducted (stacks less than 7.8 feet in diameter - 16.7, 50.0 and
83.3 percent of the measurement line; stacks greater than 7.8 feet in diameter – 0.4, 1.0, and 2.0 meters from the
stack wall). If the pollutant concentration differed by more than 10% or 0.5% from the average concentration, then
sampling was conducted at a minimum of twelve (12) traverse points. Copies of stratification check data are
included in the Quality Assurance/Quality Control Appendix of the report.

A Data Acquisition System with battery backup were used to record the instrument response in one (1) minute
averages. The data was continuously stored as a *.CSV file in Excel format on the hard drive of a computer. At the
completion of testing, the data was also saved to the Alliance server. All data was reviewed by the Field Team
Leader before leaving the facility. Once arriving at Alliance’s office, all written and electronic data was
relinquished to the report coordinator and then a final review was performed by the Project Manager.
2.6 Quality Assurance/Quality Control – U.S. EPA Reference Method 320
EPA Protocol 1 Calibration Gases – Cylinder calibration gases used met EPA Protocol 1 (+/- 2%) standards. Copies
of all calibration gas certificates can be found in the Quality Assurance/Quality Control Appendix.

After providing ample time for the FTIR to reach the desired temperature and to stabilize, zero gas (nitrogen) was
introduced directly to the instrument sample port. While flowing nitrogen the signal amplitude was recorded, a
background spectra was taken, a linearity check was performed and recorded, the peak to peak noise and the root
mean square in the spectral region of interest was measured and a screenshot was recorded.

Following the zero gas checks, room air was pulled through the sample chamber and the line width and resolution
was verified to be at 1879 cm-1, the peak position was entered and the FWHH was recorded (screenshot). Following
these checks, another background spectra was recorded and the calibration transfer standard (CTS) was introduced
directly to the instrument sample port. The CTS instrument recovery was recorded and the instrument mechanical
response time was measured.

Next, stack gas was introduced to the FTIR through the sampling system and several scans were taken until a stable
reading was achieved. The native concentration of our target spiking analyte was recorded. Spike gas was
introduced to the sampling system at a constant flow rate ≤ 10% of the total sample flow rate and a corresponding
dilution ratio was calculated along with a system response time. Matrix spike recovery spectra were recorded and
were within the ± 30% of the calculated value of the spike concentration that the method requires.

10 of 87

Source Test Report
Testing Methodology

AST-2023-4301 Central Valley – Salt Lake City, UT Page 2-4

The matrix spike recovery was conducted once at the beginning of the testing and the CTS recovery procedures
were repeated following each test run. The corresponding values were recorded.
11 of 87
Appendix A
12 of 87
Example Calculations
Location
Source
Project No.
Run No.
Parameter(s)
Absolute Stack Gas Pressure (Ps), in. Hg
where,
Pb 25.88 = barometric pressure, in. Hg
Pg 1.00 = static pressure, in. H2O
Ps 25.95 = in. Hg
Moisture Fraction (BWSsat), dimensionless (theoretical at saturated conditions)
where,
Ts 339.4 = stack temperature, °F
Ps 26.0 = absolute stack gas pressure, in. Hg
BWSsat 1.000 = dimensionless
Molecular Weight (DRY) (Md), lb/lb-mole
where,
CO2 6.6 = carbon dioxide concentration, %
O2 11.6 = oxygen concentration, %
Md 29.53 = lb/lb mol
Molecular Weight (WET) (Ms), lb/lb-mole
where,
Md 29.53 = molecular weight (DRY), lb/lb mol
BWS 0.101 = moisture fraction, dimensionless
Ms 28.36 = lb/lb mol
Average Velocity (Vs), ft/sec
where,
Cp 0.84 = pitot tube coefficient
Δ P1/2 1.030 = average pre/post test velocity head of stack gas, (in. H2O)1/2
Ts 799.1 = average pre/post test absolute stack temperature, °R
Ps 25.95 = absolute stack gas pressure, in. Hg
Ms 28.36 = molecular weight of stack gas, lb/lb mol
Vs 77.1 = ft/sec
Average Stack Gas Flow at Stack Conditions (Qa), acfm
where,
Vs 77.1 = stack gas velocity, ft/sec
As 2.18 = cross-sectional area of stack, ft
2
Qa 10,090 = acfm
Average Stack Gas Flow at Standard Conditions (Qs), dscfm
Ps
Ts
where,
Qa 10,090 = average stack gas flow at stack conditions, acfm
BWS 0.101 = moisture fraction, dimensionless
Ps 25.95 = absolute stack gas pressure, in. Hg
Ts 799.1 = average pre/post test absolute stack temperature, °R
Qs 5,196 = dscfm
Central Valley Water Reclamation (CVWR)
Jenbacher #2
AST-2023-4301
1
VFR
Qsd = 17.636 x Qa x (1 - BWS) x
Ms ൌ Md ሺ1 െ BWSሻ ൅ 18.015 ሺBWSሻ
Md ൌ ሺ0.44 ൈ % COଶ ሻ ൅ ሺ0.32 ൈ % O2ሻ ൅ ሺ0.28 ሺ100 െ % COଶ െ % O2ሻሻ
BWSsat ൌ 10଺.ଷ଻ି ଶ,଼ଶ଻
୘ୱାଷ଺ହ
Ps
Ps ൌ Pb ൅ Pg
13 6
Vs ൌ 85.49 ൈ Cp ൈ ሺΔ P ଵ/ଶ ሻ avg ൈ Ts
Ps x Ms
Qa ൌ 60 ൈ Vs ൈ As
13 of 87
Location:
Source:
Project No.:
Run No. /Method
VOC - Outlet Concentration (C VOCc15), ppmvd @ 15% O₂
20.9 - 15
20.9 - O₂
where,
CVOC 20.2 = VOC - Outlet Concentration, ppmvd
CO₂11.2 = oxygen concentration, %
CVOCc15 12.3 = ppmvd @15% O₂
VOC - Outlet Emission Rate (ERVOC), lb/hr
where,
CVOC 20.2 = VOC - Outlet Concentration, ppmvd
MW 44.1 = VOC molecular weight, g/g-mole
Qs 4,923 = stack gas volumetric flow rate at standard conditions, dscfm
ERVOC 0.68 = lb/hr
VOC - Outlet Emission Rate (ERVOCTPY), ton/yr
ERVOC x 8,760
2,000
where,
ERVOC 0.68 = VOC - Outlet Emission Rate, lb/hr
ERVOCTPY 2.99 = ton/yr
VOC - Outlet Emission Factor (EFVOC), g/hp-hr
ERVOC x 454
EBW
where,
ERVOC 0.68 = VOC - Outlet Emission Rate, lb/hr
EBW 2,414 = engine brake work, HP
EFVOC 0.128 = g/hp-hr
ERVOCTPY =
EFVOC =
ERVOC =CVOC x MW x Qs x 60 x 28.32
24.04 x 1.0E06 x 454
CVOCc15 = CVOC x
Central Valley Water Reclamation (CVWR)
Jenbacher #4
AST-2023-4301
Run 1 / Method 320

𝑚𝑖𝑛
ℎ𝑟
𝐿
𝑓𝑡ଷ
𝐿
𝑔െ𝑚𝑜𝑙𝑒
𝑔
𝑙𝑏
𝑙𝑏
𝑡𝑜𝑛
ℎ𝑟
𝑦𝑟
𝑔
𝑙𝑏
14 of 87
Location:
Source:
Project No.:
Run No. /Method
NOx - Outlet Concentration (C NOxc15), ppmvd @ 15% O₂
20.9 - 15
20.9 - O₂
where,
CNOx 65.9 = NOx - Outlet Concentration, ppmvd
CO₂11.2 = oxygen concentration, %
CNOxc15 40.1 = ppmvd @15% O₂
NOx - Outlet Emission Rate (ERNOx), lb/hr
where,
CNOx 65.9 = NOx - Outlet Concentration, ppmvd
MW 46.0055 = NOx molecular weight, g/g-mole
Qs 4,923 = stack gas volumetric flow rate at standard conditions, dscfm
ERNOx 2.33 = lb/hr
NOx - Outlet Emission Rate (ERNOxTPY), ton/yr
ERNOx x 8,760
2,000
where,
ERNOx 2.33 = NOx - Outlet Emission Rate, lb/hr
ERNOxTPY 10.19 = ton/yr
NOx - Outlet Emission Factor (EF NOx), g/hp-hr
ERNOx x 453.592
EBW
where,
ERNOx 2.33 = NOx - Outlet Emission Rate, lb/hr
EBW 2,414 = engine brake work, HP
EFNOx 0.437 = g/hp-hr
ERNOxTPY =
EFNOx =
ERNOx =CNOx x MW x Qs x 60 x 28.32
24.04 x 1.0E06 x 453.592
CNOxc15 = CNOx x
Central Valley Water Reclamation (CVWR)
Jenbacher #4
AST-2023-4301
Run 1 / Method 320

𝑚𝑖𝑛
ℎ𝑟
𝐿
𝑓𝑡ଷ
𝐿
𝑔െ𝑚𝑜𝑙𝑒
𝑔
𝑙𝑏
𝑙𝑏
𝑡𝑜𝑛
ℎ𝑟
𝑦𝑟
𝑔
𝑙𝑏
15 of 87
Location:
Source:
Project No.:
Run No. /Method
CO - Outlet Concentration (C COc15), ppmvd @ 15% O₂
20.9 - 15
20.9 - O₂
where,
CCO 389.3 = CO - Outlet Concentration, ppmvd
CO₂11.2 = oxygen concentration, %
CCOc15 236.9 = ppmvd @15% O₂
CO - Outlet Emission Rate (ERCO), lb/hr
where,
CCO 389.3 = CO - Outlet Concentration, ppmvd
MW 28.01 = CO molecular weight, g/g-mole
Qs 4,923 = stack gas volumetric flow rate at standard conditions, dscfm
ERCO 8.37 = lb/hr
CO - Outlet Emission Rate (ERCOTPY), ton/yr
ERCO x 8,760
2,000
where,
ERCO 8.37 = CO - Outlet Emission Rate, lb/hr
ERCOTPY 36.64 = ton/yr
CO - Outlet Emission Factor (EFCO), g/hp-hr
ERCO x 453.592
EBW
where,
ERCO 8.37 = CO - Outlet Emission Rate, lb/hr
EBW 2,414 = engine brake work, HP
EFCO 1.572 = g/hp-hr
ERCOTPY =
EFCO =
ERCO =CCO x MW x Qs x 60 x 28.32
24.04 x 1.0E06 x 453.592
CCOc15 = CCO x
Central Valley Water Reclamation (CVWR)
Jenbacher #4
AST-2023-4301
Run 1 / Method 320

𝑚𝑖𝑛
ℎ𝑟
𝐿
𝑓𝑡ଷ
𝐿
𝑔െ𝑚𝑜𝑙𝑒
𝑔
𝑙𝑏
𝑙𝑏
𝑡𝑜𝑛
ℎ𝑟
𝑦𝑟
𝑔
𝑙𝑏
16 of 87
r
r
O₂ - Outlet Concentration (C O₂), % dry
C
M

A ( C M - C 0 )
where,
Cobs 11.2
Co 0.0
CMA 12.0
CM 12.0
CO₂11.2
= average analyzer value during test, % dry
= average of pretest & posttest zero responses, % dry
= actual concentration of calibration gas, % dry
= average of pretest & posttest calibration responses, % dry
= O₂ Concentration, % dry
CO₂ = ( Cobs - C0 ) x
CO₂ - Outlet Concentration (C CO₂), % dry
C M A ( CM - C 0 )
where,
Cobs 6.5
Co 0.0
CMA 12.0
CM 12.0
CCO₂6.5
= average analyzer value during test, % dry
= average of pretest & posttest zero responses, % dry
= actual concentration of calibration gas, % dry
= average of pretest & posttest calibration responses, % dry
= CO₂ Concentration, % dry
CCO₂ = ( Cobs - C0 ) x
Location:
Source:
Project No.:
Run No. /Method
Central Valley Water Reclamation (CVWR)
Jenbacher #4
AST-2023-4301
Run 1 / Method 3A
17 of 87
Location
Source(s)
Project No.
Date(s)
Where,
CTSavg 102.27 = average of all CTS calibration gas readings, ppm
CTScyl 101 = CTS bottle certified gas value, ppm
CTSR 101.3% = CTS recovery value, %
Spike Dilution Factor (DF), %
Where,
SF6dir 4.57 = average of direct tracer gas value readings
SF6nat 0.01 = average of native tracer gas value readings
SF6spike 0.523333 = average of dynamic spike tracer gas value readings
DF 11.23% = spike dilution factor, %
Calculated Spike (Spikecalc), ppm
Where,
DF. 11.23% = spike dilution factor, %
Analytedir 93.00 = average of direct analyte gas values, ppm
Analyte nat 0.50 = average of native analyte gas values, ppm
Spikecalc 10.89 = calculated spike, ppm value, ppm
Spike Recovery Value (SpikeR), %
Where,
Spikecalc 10.89 = calculated spike, ppm value, ppm
Analytespike 8.60 = average of spiked analyte gas values, ppm
SpikeR 79.00% = spike recovery value, %
Central Valley Water Reclamation (CVWR)
Jenbacher #2 and #4
AST-2023-4301
8/14/2023
CTS Recovery Value (CTSR), %
𝐶𝑇𝑆௔௩௚
𝐶𝑇𝑆௖௬௟
ൈ 100
𝑆𝐹6௦௣௜௞௘ െ𝑆𝐹6௡௔௧
𝑆𝐹6ௗ௜௥
ൈ 100
𝐷𝐹 ൈ 𝐴𝑛𝑎𝑙𝑦𝑡𝑒𝑑𝑖𝑟൅ሺ𝐴𝑛𝑎𝑙𝑦𝑡𝑒௡௔௧ ൈ 1 െ𝐷𝐹 ሻ
𝐴𝑛𝑎𝑙𝑦𝑡𝑒௦௣௜௞௘
𝑆𝑝𝑖𝑘𝑒௖௔௟௖
ൈ 100
18 of 87
Appendix B
19 of 87
Jenbacher Engine #2
20 of 87
Emissions Calculations
Location
Source
Project No.
Run Number Run 1 Run 2 Run 3 Average
Date 12/15/23 12/15/23 12/15/23 --
Start Time 9:24 10:39 12:33 --
Stop Time 10:24 11:39 13:33 --
Engine Manufacturer
Engine Model
Engine Serial Number
Engine Type
Engine Date of Manufacturer DOM
Engine Hour Meter Reading EMR
Engine Exhaust Temperature, °F 983 984 983 983
Generator Output, Hz Gen OP 60 60 60 60
Engine Speed, RPM ES 1,500 1,500 1,500 1,500
Engine Brake Work, HP EBW 2,415 2,415 2,415 2,415
Maximum Brake Work, HP MaxEBW 2,509 2,509 2,509 2,509
Engine Load, % EL 96 96 96 96
Ambient Temperature TAmb 45 45 45 45
Relative Humidity, % RH
30 30 30 30
Barometric Pressure, in. Hg Pb
25.75 25.75 25.75 25.75
Moisture Fraction, dimensionless BWS 0.101 0.101 0.098 0.100
Volumetric Flow Rate (M1-4), dscfm Qs 5,196 5,081 5,093 5,123
O₂ Concentration, % dry CO₂11.58 11.44 11.43 11.48
CO₂ Concentration, % dry CCO₂6.64 6.68 6.64 6.65
Methane - Outlet Concentration, ppmvd CCH₄1572.17 1548.44 1561.44 1560.68
Methane - Outlet Concentration, ppmvw CCH₄w 1413.11 1392.06 1408.74 1404.64
Methane - Outlet Concentration, ppmvd @ 15 % O₂CCH₄c15 995.66 965.28 972.51 977.82
Methane - Outlet Emission Rate, lb/hr ERCH₄20.42 19.66 19.88 19.99
Methane - Outlet Emission Rate, ton/yr ERCH₄TPY 89.43 86.13 87.06 87.54
Methane - Outlet Emission Factor, g/HP-hr EFCH₄3.84 3.69 3.73 3.75
Ethane - Outlet Concentration, ppmvd CC₂H₆26.96 26.23 26.74 26.64
Ethane - Outlet Concentration, ppmvd (as C3H8)*CC₂H₆17.79 17.31 17.65 17.58
Ethane - Outlet Concentration, ppmvw CC₂H₆w 24.23 23.58 24.12 23.98
Ethane - Outlet Concentration, ppmvd @ 15 % O₂CC₂H₆c15 17.07 16.35 16.65 16.69
Ethane - Outlet Emission Rate, lb/hr ERC₂H₆0.66 0.62 0.64 0.64
Ethane - Outlet Emission Rate, ton/yr ERC₂H₆TPY 2.87 2.74 2.79 2.80
Ethane - Outlet Emission Factor, g/HP-hr EFC₂H₆0.12 0.12 0.12 0.12
Formaldehyde - Outlet Concentration, ppmvd CCHOH 49.66 49.03 48.30 48.99
Formaldehyde - Outlet Concentration, ppmvw CCHOHw 44.63 44.08 43.57 44.09
Formaldehyde - Outlet Concentration, ppmvd @ 15 % O₂CCHOHc15 31.45 30.56 30.08 30.70
Formaldehyde - Outlet Emission Rate, lb/hr ERCHOH 1.21 1.17 1.15 1.17
Formaldehyde - Outlet Emission Rate, ton/yr ERCHOHTPY 5.29 5.11 5.04 5.15
Formaldehyde - Outlet Emission Factor, g/HP-hr EFCHOH 0.23 0.22 0.22 0.22
CO - Outlet Concentration, ppmvd CCO 455.13 450.74 446.44 450.77
CO - Outlet Concentration, ppmvd @ 15 % O₂CCOc15 288.23 280.99 278.06 282.43
CO - Outlet Emission Rate, lb/hr ERCO 10.32 10.00 9.92 10.08
CO - Outlet Emission Rate, ton/yr ERCOTPY 45.21 43.78 43.47 44.15
CO - Outlet Emission Factor, g/HP-hr EFCO 1.94 1.88 1.86 1.89
NOx - Outlet Concentration, ppmvd CNOx 58.10 59.20 54.88 57.39
NOx - Outlet Concentration, ppmvd @ 15 % O₂CNOxc15 36.79 36.91 34.18 35.96
NOx - Outlet Emission Rate, lb/hr ERNOx 2.16 2.16 2.00 2.11
NOx - Outlet Emission Rate, ton/yr ERNOxTPY 9.48 9.45 8.78 9.23
NOx - Outlet Emission Factor, g/HP-hr EFNOx 0.41 0.41 0.38 0.40
VOC - Outlet Concentration, ppmvd CVOC 23.75 23.42 24.01 23.73
VOC - Outlet Concentration, ppmvd @ 15 % O₂CVOCc15 15.04 14.60 14.95 14.86
VOC - Outlet Emission Rate, lb/hr ERVOC 0.85 0.82 0.84 0.84
VOC - Outlet Emission Rate, ton/yr ERVOCTPY 3.71 3.58 3.68 3.66
VOC - Outlet Emission Factor, g/HP-hr EFVOC 0.16 0.15 0.16 0.16
NMHC - Outlet Concentration, ppmvd CNMHC (as C3H8)41.54 40.73 41.65 41.31
NMHC - Outlet Concentration, ppmvw CNMHC (as C3H8)w 37.34 36.62 37.58 37.18
NMHC - Outlet Concentration, ppmvd @ 15 % O₂CNMHC (as C3H8)c15 26.31 25.39 25.94 25.88
NMHC - Outlet Emission Rate, lb/hr ERNMHC (as C3H8)1.48 1.42 1.46 1.45
NMHC - Outlet Emission Rate, ton/yr ERNMHC (as C3H8)TPY 6.50 6.23 6.39 6.37
NMHC - Outlet Emission Factor, g/HP-hr EFNMHC (as C3H8)0.28 0.27 0.27 0.27
Engine Data
18,480
Input Data - Outlet
Calculated Data - Outlet
FTIR Calculated Data
Central Valley Water Reclamation (CVWR)
Jenbacher #2
AST-2023-4301
GE
JMS 612-F28F02
1322416
Compression Ignition
2017-01-01
21 of 87
Run 1 - RM Data
Location:
Source:
Project No.:
Date:
Time O₂ - Outlet CO₂ - Outlet
Unit % dry % dry
Status Valid Valid
Uncorrected Run Average (Cobs)11.44 6.49
Cal Gas Concentration (CMA)12.00 12.00
Pretest System Zero Response -0.01 0.02
Posttest System Zero Response 0.08 -0.02
Average Zero Response (Co)0.04 0.00
Pretest System Cal Response 11.83 11.79
Posttest System Cal Response 11.88 11.68
Average Cal Response (CM)11.85 11.74
Corrected Run Average (Corr)11.58 6.64
9:24 11.41 6.51
9:25 11.41 6.51
9:26 11.42 6.50
9:27 11.41 6.51
9:28 11.43 6.50
9:29 11.42 6.50
9:30 11.42 6.50
9:31 11.41 6.50
9:32 11.42 6.49
9:33 11.42 6.49
9:34 11.43 6.49
9:35 11.43 6.50
9:36 11.43 6.50
9:37 11.44 6.49
9:38 11.44 6.49
9:39 11.45 6.48
9:40 11.45 6.49
9:41 11.46 6.48
9:42 11.46 6.48
9:43 11.48 6.47
9:44 11.47 6.47
9:45 11.46 6.48
9:46 11.46 6.48
9:47 11.46 6.48
9:48 11.47 6.47
9:49 11.46 6.48
9:50 11.46 6.49
9:51 11.45 6.48
9:52 11.45 6.49
9:53 11.45 6.49
9:54 11.44 6.49
9:55 11.45 6.49
9:56 11.44 6.48
9:57 11.44 6.49
9:58 11.44 6.49
9:59 11.44 6.49
10:00 11.43 6.49
10:01 11.44 6.48
10:02 11.45 6.48
10:03 11.45 6.49
10:04 11.45 6.49
10:05 11.44 6.50
10:06 11.44 6.49
10:07 11.42 6.50
10:08 11.44 6.49
10:09 11.45 6.48
10:10 11.44 6.49
10:11 11.44 6.49
10:12 11.44 6.50
10:13 11.46 6.48
10:14 11.45 6.49
10:15 11.44 6.50
10:16 11.45 6.50
10:17 11.45 6.50
10:18 11.45 6.51
10:19 11.45 6.51
10:20 11.46 6.50
10:21 11.48 6.49
10:22 11.46 6.49
10:23 11.47 6.49
Central Valley Water Reclamation (CVWR)
Jenbacher #2
AST-2023-4301
12/15/23
22 of 87
Run 1 - FTIR Data
Location:
Source:
Project No.:
Date:
Time Temperature Pressure Methane - Outlet Ethane - Outlet Formaldehyde - Outlet CO - Outlet NOx - Outlet VOC - Outlet BWS - Outlet
Unit ° C atm ppmvw ppmvw ppmvw ppmvd ppmvd ppmvd % (wet)
MDL ----0.04 0.08 0.08 0.13 0.74 0.28 --
Status Valid Valid Valid Valid Valid Valid Valid Valid Valid
9:24 191.0 0.850 1,399.5 23.7 45.0 452.2 58.6 24.1 10.1
9:25 191.0 0.850 1,412.1 24.3 43.4 451.6 58.9 22.9 9.9
9:26 191.0 0.860 1,426.8 24.6 43.8 455.4 57.7 21.9 9.8
9:27 191.0 0.850 1,406.3 24.5 46.9 455.8 59.0 23.8 10.6
9:28 191.0 0.860 1,419.7 24.6 44.6 455.8 58.1 23.4 10.1
9:29 191.0 0.850 1,415.4 24.5 42.6 451.0 58.9 24.1 9.7
9:30 191.0 0.850 1,406.8 24.0 44.3 452.2 58.3 23.9 10.1
9:31 191.0 0.850 1,385.7 23.8 45.4 449.8 58.9 23.3 10.3
9:32 191.0 0.860 1,402.3 23.9 45.1 452.9 58.2 23.2 10.1
9:33 191.0 0.850 1,412.3 24.7 44.5 454.2 58.4 24.0 10.1
9:34 191.0 0.850 1,408.6 24.3 46.1 455.1 58.2 23.9 10.5
9:35 191.0 0.850 1,440.1 24.7 43.7 459.4 58.2 24.6 9.8
9:36 190.9 0.850 1,421.3 24.5 43.6 455.8 57.8 23.8 9.9
9:37 190.9 0.850 1,442.5 25.2 44.0 460.5 57.0 23.2 10.0
9:38 190.9 0.850 1,422.9 24.6 46.6 462.4 57.1 24.0 10.6
9:39 190.9 0.850 1,474.4 25.7 45.7 469.4 55.6 24.8 10.1
9:40 190.9 0.850 1,469.6 25.4 45.7 466.3 56.8 23.8 10.0
9:41 191.0 0.850 1,457.0 25.6 44.9 465.0 56.4 23.4 9.9
9:42 191.0 0.850 1,450.7 25.4 46.3 465.8 56.4 24.8 10.3
9:43 191.0 0.850 1,499.4 26.2 46.1 476.1 55.1 24.1 10.1
9:44 191.0 0.850 1,477.8 26.1 46.3 472.0 55.4 24.3 10.2
9:45 191.0 0.850 1,435.4 25.0 46.3 463.1 56.7 24.9 10.2
9:46 190.9 0.850 1,460.9 25.9 45.5 467.9 56.4 25.4 10.1
9:47 191.0 0.850 1,474.2 26.0 45.0 467.4 56.0 25.1 9.9
9:48 191.0 0.860 1,484.1 26.5 45.0 469.1 55.6 24.8 9.9
9:49 191.0 0.850 1,441.2 25.3 46.3 464.3 56.7 25.6 10.4
9:50 191.0 0.850 1,423.6 25.0 45.1 456.8 57.4 23.9 10.1
9:51 191.0 0.850 1,433.2 25.1 46.0 461.8 57.4 23.8 10.4
9:52 191.0 0.850 1,420.5 24.7 44.2 457.4 57.6 24.4 9.9
9:53 191.0 0.850 1,421.4 24.8 44.7 458.7 57.6 24.6 10.0
9:54 190.9 0.850 1,419.2 24.6 45.4 456.8 57.8 24.1 10.2
9:55 191.0 0.850 1,415.7 24.9 43.9 455.2 57.6 23.6 9.9
9:56 191.0 0.850 1,390.4 24.5 44.0 452.0 58.0 23.5 10.1
9:57 190.9 0.850 1,399.4 24.3 44.0 454.0 58.1 24.8 10.0
9:58 191.0 0.850 1,379.8 24.1 44.0 449.0 58.9 24.7 10.1
9:59 191.0 0.850 1,396.6 24.1 44.1 453.7 58.1 24.5 10.1
10:00 190.9 0.850 1,360.6 23.0 43.1 443.5 59.7 22.8 10.0
10:01 191.0 0.860 1,367.7 23.6 43.5 443.8 58.3 23.0 10.2
10:02 191.0 0.850 1,413.6 24.4 44.1 453.5 58.5 23.6 10.1
10:03 191.0 0.850 1,389.0 23.8 44.7 450.1 59.2 23.3 10.3
10:04 191.0 0.850 1,370.1 22.9 45.3 448.2 59.4 22.9 10.5
10:05 191.0 0.850 1,364.7 22.8 43.9 445.6 59.5 23.4 10.2
10:06 191.0 0.850 1,369.6 23.3 43.2 444.0 59.5 23.2 10.1
10:07 191.0 0.850 1,349.2 22.6 43.6 442.6 59.9 23.2 10.2
10:08 191.0 0.860 1,384.4 23.0 44.2 447.6 59.2 22.5 10.2
10:09 191.0 0.850 1,420.4 24.0 44.9 457.3 58.5 23.4 10.2
10:10 191.0 0.850 1,385.8 23.6 44.1 448.5 59.7 23.0 10.1
10:11 191.0 0.850 1,405.0 23.5 44.3 451.0 59.4 23.9 10.1
10:12 191.0 0.850 1,382.9 23.0 43.7 447.8 60.1 22.4 10.1
10:13 191.0 0.850 1,398.0 23.3 44.5 451.0 58.9 24.0 10.2
10:14 191.0 0.850 1,405.9 23.0 44.8 453.0 59.2 23.0 10.2
10:15 191.0 0.850 1,380.5 22.8 44.1 444.0 59.6 25.2 10.1
10:16 191.0 0.850 1,373.2 22.8 43.1 444.3 59.5 23.5 10.0
10:17 191.0 0.850 1,377.6 22.8 43.9 448.9 58.7 23.8 10.1
10:18 191.0 0.850 1,386.9 22.9 45.7 449.9 59.0 23.9 10.4
10:19 191.0 0.850 1,390.9 23.0 44.3 448.7 58.8 22.5 10.1
10:20 191.0 0.850 1,392.8 23.3 44.3 449.7 58.6 23.2 10.2
10:21 191.0 0.850 1,415.9 23.8 44.0 455.1 58.2 23.6 10.0
10:22 191.0 0.850 1,427.9 24.4 44.3 457.8 58.0 22.0 10.1
10:23 191.0 0.860 1,426.9 23.8 44.5 456.2 57.6 23.2 10.1
Parameter Temperature Pressure Methane - Outlet Ethane - Outlet Formaldehyde - Outlet CO - Outlet NOx - Outlet VOC - Outlet BWS - Outlet
Run Average 191.0 0.851 1413.1 24.2 44.6 455.1 58.1 23.8 10.1
Central Valley Water Reclamation (CVWR)
Jenbacher #2
AST-2023-4301
12/15/23
23 of 87
Run 2 - RM Data
Location:
Source:
Project No.:
Date:
Time O₂ - Outlet CO₂ - Outlet
Unit % dry % dry
Status Valid Valid
Uncorrected Run Average (Cobs)11.29 6.51
Cal Gas Concentration (CMA)12.00 12.00
Pretest System Zero Response 0.08 -0.02
Posttest System Zero Response 0.01 0.03
Average Zero Response (Co)0.04 0.01
Pretest System Cal Response 11.88 11.68
Posttest System Cal Response 11.81 11.71
Average Cal Response (CM)11.85 11.69
Corrected Run Average (Corr)11.44 6.68
10:39 11.36 6.48
10:40 11.35 6.49
10:41 11.34 6.50
10:42 11.34 6.50
10:43 11.34 6.50
10:44 11.34 6.49
10:45 11.34 6.49
10:46 11.33 6.50
10:47 11.34 6.49
10:48 11.34 6.50
10:49 11.35 6.48
10:50 11.35 6.50
10:51 11.35 6.49
10:52 11.36 6.50
10:53 11.35 6.51
10:54 11.34 6.51
10:55 11.35 6.51
10:56 11.34 6.50
10:57 11.34 6.51
10:58 11.34 6.51
10:59 11.34 6.51
11:00 11.32 6.51
11:01 11.32 6.51
11:02 11.32 6.50
11:03 11.31 6.50
11:04 11.31 6.50
11:05 11.32 6.50
11:06 11.32 6.49
11:07 11.32 6.49
11:08 11.30 6.50
11:09 11.31 6.51
11:10 11.29 6.52
11:11 11.28 6.53
11:12 11.28 6.52
11:13 11.26 6.52
11:14 11.26 6.53
11:15 11.25 6.54
11:16 11.25 6.54
11:17 11.25 6.53
11:18 11.24 6.53
11:19 11.24 6.54
11:20 11.24 6.52
11:21 11.23 6.54
11:22 11.23 6.54
11:23 11.23 6.53
11:24 11.22 6.53
11:25 11.22 6.53
11:26 11.21 6.53
11:27 11.22 6.51
11:28 11.21 6.52
11:29 11.21 6.51
11:30 11.20 6.52
11:31 11.22 6.52
11:32 11.22 6.51
11:33 11.23 6.51
11:34 11.25 6.51
11:35 11.26 6.50
11:36 11.27 6.48
11:37 11.28 6.48
11:38 11.30 6.47
Central Valley Water Reclamation (CVWR)
Jenbacher #2
AST-2023-4301
12/15/23
24 of 87
Run 2 - FTIR Data
Location:
Source:
Project No.:
Date:
Time Temperature Pressure Methane - Outlet Ethane - Outlet Formaldehyde - Outlet CO - Outlet NOx - Outlet VOC - Outlet BWS - Outlet
Unit ° C atm ppmvw ppmvw ppmvw ppmvd ppmvd ppmvd % (wet)
MDL ----0.04 0.08 0.08 0.13 0.74 0.28 --
Status Valid Valid Valid Valid Valid Valid Valid Valid Valid
10:39 191.0 0.850 1,461.3 25.2 42.3 463.1 56.9 22.9 9.5
10:40 190.9 0.850 1,461.7 25.3 42.1 460.9 57.4 23.0 9.4
10:41 191.0 0.850 1,443.5 25.0 41.9 457.8 57.5 22.8 9.5
10:42 191.0 0.850 1,424.6 25.0 42.2 456.0 58.2 21.4 9.6
10:43 191.0 0.850 1,452.4 25.1 43.0 460.2 58.2 23.6 9.5
10:44 191.0 0.850 1,443.6 25.0 44.1 461.3 56.7 23.6 9.9
10:45 191.0 0.850 1,431.9 24.2 45.5 460.8 57.2 24.0 10.2
10:46 191.0 0.850 1,423.1 24.3 45.3 460.3 57.8 23.9 10.2
10:47 190.9 0.850 1,454.6 24.7 44.9 464.7 57.5 23.5 10.0
10:48 190.9 0.850 1,415.2 24.2 45.3 457.8 58.2 24.5 10.2
10:49 191.0 0.850 1,451.8 24.9 45.9 465.6 56.8 24.3 10.1
10:50 191.0 0.850 1,458.1 25.4 44.6 463.3 57.5 24.7 9.9
10:51 190.9 0.850 1,422.6 24.6 43.9 458.5 57.0 23.8 10.0
10:52 190.9 0.850 1,422.3 24.3 48.3 464.2 57.5 25.4 10.9
10:53 191.0 0.850 1,431.1 25.2 44.4 459.4 58.6 23.5 10.2
10:54 191.0 0.850 1,397.0 23.9 44.7 454.9 57.6 23.5 10.2
10:55 191.0 0.850 1,416.9 23.7 46.0 460.4 57.7 23.7 10.4
10:56 190.9 0.850 1,414.1 24.3 44.4 457.1 57.9 23.6 10.1
10:57 191.0 0.850 1,399.5 23.8 43.8 453.4 58.4 23.7 10.0
10:58 191.0 0.850 1,415.0 24.4 44.9 456.0 58.6 23.2 10.1
10:59 191.0 0.850 1,405.1 24.0 45.1 453.7 58.9 23.4 10.2
11:00 191.0 0.850 1,383.1 23.4 46.9 452.3 58.6 23.3 10.7
11:01 191.0 0.850 1,396.9 23.3 45.0 453.6 58.4 23.3 10.2
11:02 191.1 0.850 1,385.9 23.5 44.7 450.6 58.5 23.1 10.2
11:03 191.1 0.850 1,387.7 23.5 45.0 450.7 59.1 23.8 10.3
11:04 191.1 0.850 1,385.4 23.6 45.0 451.5 59.1 24.3 10.4
11:05 191.0 0.860 1,379.1 23.2 43.9 448.4 58.6 23.8 10.1
11:06 191.1 0.850 1,402.6 23.9 45.7 455.6 58.8 24.7 10.4
11:07 191.1 0.860 1,397.3 24.0 44.6 451.8 58.6 22.7 10.3
11:08 191.0 0.860 1,396.1 23.7 44.2 451.4 59.1 22.8 10.1
11:09 191.0 0.860 1,388.3 23.6 43.9 448.5 59.2 22.5 10.1
11:10 191.1 0.850 1,386.5 23.5 44.6 449.1 59.7 24.0 10.2
11:11 191.0 0.860 1,358.5 22.8 43.8 443.5 60.2 23.1 10.1
11:12 191.1 0.850 1,366.7 22.9 44.1 445.9 60.5 22.8 10.1
11:13 191.0 0.860 1,337.9 22.5 43.5 437.6 60.5 23.5 10.1
11:14 191.0 0.860 1,318.1 22.1 42.6 434.9 60.8 23.2 10.1
11:15 191.0 0.850 1,327.8 21.7 42.8 436.0 61.7 23.8 10.1
11:16 191.0 0.860 1,306.0 21.7 42.6 431.7 62.4 23.3 10.2
11:17 191.0 0.860 1,352.3 22.6 43.1 438.5 61.3 22.2 10.1
11:18 191.0 0.860 1,355.8 22.5 43.1 440.5 61.7 23.1 10.1
11:19 191.0 0.860 1,325.1 22.1 43.3 434.3 62.0 22.9 10.2
11:20 191.0 0.860 1,337.4 22.1 43.3 439.4 61.6 21.7 10.1
11:21 191.0 0.860 1,314.3 22.1 42.8 433.2 62.1 22.5 10.1
11:22 191.0 0.850 1,342.4 22.5 43.2 438.1 61.6 22.8 10.1
11:23 191.0 0.860 1,355.8 23.1 43.5 439.9 61.8 23.3 10.2
11:24 191.0 0.860 1,353.9 22.8 43.2 441.7 61.8 23.9 10.1
11:25 191.0 0.860 1,371.5 22.9 44.0 444.0 61.2 23.1 10.2
11:26 191.0 0.860 1,333.4 22.0 42.8 435.0 61.7 23.1 10.1
11:27 191.0 0.860 1,360.8 22.5 43.0 442.0 61.3 22.8 10.1
11:28 191.0 0.860 1,321.6 22.3 42.9 434.0 62.6 22.4 10.2
11:29 191.0 0.860 1,347.2 22.4 42.9 440.2 61.7 23.3 10.1
11:30 191.0 0.860 1,346.1 22.4 42.8 439.6 62.2 23.1 10.1
11:31 191.0 0.860 1,349.0 22.6 43.5 441.3 60.9 22.5 10.2
11:32 191.1 0.860 1,372.7 23.2 43.4 446.0 60.2 23.2 10.1
11:33 191.1 0.860 1,389.9 23.3 43.5 449.7 59.2 24.1 10.0
11:34 191.0 0.860 1,408.5 23.8 44.5 454.0 58.3 24.0 10.1
11:35 191.1 0.860 1,412.8 23.8 44.3 457.4 58.0 23.1 10.1
11:36 191.0 0.860 1,450.6 24.5 44.7 463.6 56.1 25.0 10.0
11:37 191.0 0.860 1,463.8 24.8 45.4 469.3 55.6 24.3 10.1
11:38 191.1 0.860 1,509.8 26.2 46.1 480.7 53.8 25.3 10.1
Parameter Temperature Pressure Methane - Outlet Ethane - Outlet Formaldehyde - Outlet CO - Outlet NOx - Outlet VOC - Outlet BWS - Outlet
Run Average 191.0 0.855 1392.1 23.6 44.1 450.7 59.2 23.4 10.1
Central Valley Water Reclamation (CVWR)
Jenbacher #2
AST-2023-4301
12/15/23
25 of 87
Run 3 - RM Data
Location:
Source:
Project No.:
Date:
Time O₂ - Outlet CO₂ - Outlet
Unit % dry % dry
Status Valid Valid
Uncorrected Run Average (Cobs)11.24 6.49
Cal Gas Concentration (CMA)12.00 12.00
Pretest System Zero Response 0.01 0.03
Posttest System Zero Response 0.00 0.00
Average Zero Response (Co)0.00 0.02
Pretest System Cal Response 11.81 11.71
Posttest System Cal Response 11.80 11.70
Average Cal Response (CM)11.81 11.70
Corrected Run Average (Corr)11.43 6.64
12:33 11.20 6.51
12:34 11.21 6.50
12:35 11.20 6.50
12:36 11.20 6.50
12:37 11.19 6.50
12:38 11.18 6.51
12:39 11.19 6.50
12:40 11.19 6.50
12:41 11.19 6.50
12:42 11.19 6.50
12:43 11.19 6.50
12:44 11.19 6.51
12:45 11.19 6.51
12:46 11.20 6.51
12:47 11.20 6.50
12:48 11.19 6.50
12:49 11.21 6.49
12:50 11.22 6.50
12:51 11.23 6.48
12:52 11.22 6.49
12:53 11.23 6.51
12:54 11.23 6.50
12:55 11.23 6.49
12:56 11.24 6.47
12:57 11.24 6.48
12:58 11.25 6.48
12:59 11.24 6.47
13:00 11.25 6.47
13:01 11.25 6.48
13:02 11.25 6.50
13:03 11.26 6.48
13:04 11.28 6.47
13:05 11.29 6.47
13:06 11.29 6.47
13:07 11.29 6.46
13:08 11.28 6.48
13:09 11.28 6.49
13:10 11.29 6.48
13:11 11.28 6.49
13:12 11.30 6.47
13:13 11.29 6.47
13:14 11.29 6.47
13:15 11.28 6.47
13:16 11.26 6.47
13:17 11.27 6.47
13:18 11.27 6.48
13:19 11.25 6.48
13:20 11.26 6.47
13:21 11.25 6.47
13:22 11.26 6.48
13:23 11.26 6.48
13:24 11.25 6.48
13:25 11.25 6.47
13:26 11.25 6.48
13:27 11.25 6.48
13:28 11.24 6.49
13:29 11.24 6.50
13:30 11.22 6.50
13:31 11.22 6.49
13:32 11.43 6.42
Central Valley Water Reclamation (CVWR)
Jenbacher #2
AST-2023-4301
12/15/23
26 of 87
Run 3 - FTIR Data
Location:
Source:
Project No.:
Date:
Time Temperature Pressure Methane - Outlet Ethane - Outlet Formaldehyde - Outlet CO - Outlet NOx - Outlet VOC - Outlet BWS - Outlet
Unit ° C atm ppmvw ppmvw ppmvw ppmvd ppmvd ppmvd % (wet)
MDL ----0.04 0.08 0.08 0.13 0.74 0.28 --
Status Valid Valid Valid Valid Valid Valid Valid Valid Valid
12:35 191.0 0.860 1,384.9 23.6 43.8 444.8 60.2 24.0 10.1
12:36 191.0 0.860 1,394.5 23.4 44.1 447.5 60.2 23.5 10.2
12:37 191.0 0.850 1,390.6 23.6 45.6 447.2 60.5 25.2 10.5
12:38 191.0 0.860 1,392.0 23.5 44.1 447.8 60.5 24.5 10.2
12:39 191.0 0.860 1,395.3 23.1 43.3 446.1 60.2 23.7 10.0
12:40 191.0 0.860 1,399.4 23.9 44.3 447.1 59.9 24.4 10.3
12:41 191.1 0.860 1,388.1 23.1 44.1 443.4 60.7 22.6 10.1
12:42 191.0 0.860 1,393.0 23.6 43.9 445.7 60.6 23.0 10.1
12:43 191.1 0.860 1,385.4 23.1 44.3 444.7 60.7 23.2 10.3
12:44 191.1 0.860 1,402.1 23.9 43.0 446.9 60.2 23.1 9.9
12:45 191.0 0.850 1,396.9 23.4 44.4 448.1 60.7 23.1 10.2
12:46 191.1 0.850 1,389.2 23.4 45.1 446.9 60.6 23.2 10.4
12:47 191.1 0.860 1,388.5 23.5 43.4 443.5 60.4 23.3 10.0
12:48 191.0 0.860 1,387.6 23.4 43.9 446.1 60.2 23.2 10.0
12:49 191.0 0.860 1,413.0 23.9 44.4 452.7 59.0 23.6 10.2
12:50 191.0 0.860 1,433.8 24.5 44.0 454.3 58.6 23.6 10.0
12:51 191.0 0.860 1,438.1 24.5 43.6 457.7 57.9 23.8 9.9
12:52 191.0 0.860 1,437.9 24.5 45.2 460.1 57.6 23.9 10.3
12:53 191.1 0.860 1,442.3 25.0 45.1 457.6 57.2 23.7 10.1
12:54 191.1 0.860 1,443.8 24.6 44.4 458.4 57.2 23.7 10.1
12:55 191.0 0.860 1,438.4 24.3 45.1 459.1 56.9 24.7 10.2
12:56 191.0 0.860 1,481.0 25.5 44.6 467.9 55.8 24.3 10.0
12:57 191.0 0.860 1,491.0 25.2 45.0 469.3 56.1 24.8 10.0
12:58 191.0 0.860 1,479.1 25.8 45.7 467.2 56.3 24.1 10.1
12:59 191.1 0.860 1,466.5 25.0 44.9 463.4 56.5 24.3 9.9
13:00 191.0 0.860 1,481.8 25.3 44.4 468.1 56.0 23.9 9.9
13:01 191.0 0.860 1,473.9 25.4 45.3 465.5 56.1 23.8 10.2
13:02 191.0 0.860 1,478.0 25.4 44.5 465.1 56.0 24.3 9.9
13:03 191.0 0.860 1,496.5 25.7 46.1 474.8 55.1 24.2 10.3
13:04 191.1 0.860 1,521.1 26.3 46.1 476.2 54.6 23.8 10.0
13:05 191.1 0.860 1,519.7 26.2 46.4 476.2 54.4 24.7 10.0
13:06 191.1 0.860 1,517.0 26.6 45.8 476.8 54.0 24.5 10.0
13:07 191.0 0.860 1,502.2 25.8 45.0 472.3 54.1 24.6 9.9
13:08 191.0 0.860 1,478.6 25.0 44.2 468.0 54.4 24.6 9.9
13:09 191.0 0.860 1,505.2 26.4 44.4 473.7 54.2 23.6 9.8
13:10 191.0 0.860 1,521.8 26.2 46.3 479.2 53.1 24.5 10.2
13:11 191.0 0.860 1,495.5 26.2 44.8 472.6 54.4 23.1 9.9
13:12 191.0 0.860 1,529.1 26.8 45.9 480.9 53.7 24.4 10.0
13:13 191.0 0.860 1,533.4 26.4 46.5 480.3 54.2 24.5 10.1
13:14 191.1 0.860 1,539.1 26.4 46.5 480.0 53.9 24.1 10.0
13:15 191.0 0.860 1,543.6 27.0 45.9 479.5 53.8 23.7 9.8
13:16 191.0 0.850 1,490.2 25.5 46.1 471.7 55.1 25.0 10.2
13:17 191.0 0.860 1,475.2 25.5 45.9 470.0 54.4 24.6 10.0
13:18 191.0 0.860 1,490.8 25.7 45.5 471.5 54.8 23.0 10.0
13:19 191.0 0.860 1,496.7 25.7 44.4 471.0 54.8 23.9 9.9
13:20 191.0 0.860 1,497.9 25.7 44.8 471.0 54.7 24.1 10.0
13:21 191.0 0.860 1,480.1 25.7 45.0 470.0 55.4 23.1 10.0
13:22 191.0 0.860 1,484.7 26.3 46.5 472.1 55.5 23.0 10.2
13:23 191.1 0.860 1,470.2 25.7 46.0 466.4 55.2 23.0 10.1
13:24 191.1 0.860 1,490.6 25.6 44.6 468.9 55.2 24.0 9.9
13:25 191.1 0.860 1,484.9 25.7 44.9 468.1 55.2 23.4 10.0
13:26 191.0 0.860 1,504.5 25.7 44.9 471.9 55.4 24.1 10.0
13:27 191.0 0.860 1,473.5 25.1 47.0 468.3 55.7 24.5 10.3
13:28 191.0 0.860 1,467.4 25.5 45.0 462.0 57.4 24.5 10.0
13:29 191.0 0.860 1,443.7 24.6 44.9 458.4 57.6 24.4 10.2
13:30 191.0 0.860 1,438.6 24.5 44.4 458.5 57.8 23.3 10.1
13:31 191.0 0.860 1,440.8 24.6 44.8 455.7 58.2 22.5 10.0
13:32 191.1 0.860 1,301.6 22.4 41.6 404.2 53.1 20.9 9.7
13:33 191.1 0.860 1.6 0.1 9.2 3.1 0.7 3.2 2.9
13:34 191.1 0.860 2.9 0.1 1.9 1.1 0.7 55.1 0.6
Parameter Temperature Pressure Methane - Outlet Ethane - Outlet Formaldehyde - Outlet CO - Outlet NOx - Outlet VOC - Outlet BWS - Outlet
Run Average 191.0 0.859 1408.7 24.1 43.6 446.4 54.9 24.0 9.8
Central Valley Water Reclamation (CVWR)
Jenbacher #2
AST-2023-4301
12/15/23
27 of 87
Method 1 Data
Location
Source
Project No.
Date
Vertical
Circular
26.00 in
6.00 in
20.00 in
2.18 ft2
2
1
1.1 ft
0.7 (must be > 0.5)
4.1 ft
2.5 (must be > 2)
16
16
Measurer (Initial and Date):DBR
Reviewer (Initial and Date):RBB
2345 6 789101112
1 14.6 -- 6.7 -- 4.4 -- 3.2 -- 2.6 -- 2.1 1 3.2 0.64 6.64
2 85.4 -- 25.0 -- 14.6 -- 10.5 -- 8.2 -- 6.7 2 10.52.108.10
3 -- -- 75.0 -- 29.6 -- 19.4 -- 14.6 -- 11.8 3 19.43.889.88
4 -- -- 93.3 -- 70.4 -- 32.3 -- 22.6 -- 17.7 4 32.3 6.46 12.46
5 -- -- -- -- 85.4 -- 67.7 -- 34.2 -- 25.0 5 67.7 13.54 19.54
6 -- -- -- -- 95.6 -- 80.6 -- 65.8 -- 35.6 6 80.6 16.12 22.12
7 -- -- -- -- -- -- 89.5 -- 77.4 -- 64.4 7 89.5 17.90 23.90
8 -- -- -- -- -- -- 96.8 -- 85.4 -- 75.0 8 96.8 19.36 25.36
9 -- -- -- -- -- -- -- -- 91.8 -- 82.3 9 -- -- --
10 -- -- -- -- -- -- -- -- 97.4 -- 88.2 10 -- -- --
11 -- -- -- -- -- -- -- -- -- -- 93.3 11 -- -- --
12 -- -- -- -- -- -- -- -- -- -- 97.9 12 -- -- --
*Percent of stack diameter from inside wall to traverse point.
A = 1.1 ft.
B = 4.1 ft.
Depth of Duct = 20 in.
Number of traverse points on a diameter
Stack Diagram
Cross Sectional Area
LOCATION OF TRAVERSE POINTS
Traverse
Point
% of
Diameter
Distance
from inside
wall
Distance
from
outside of
port
Number of Readings per Point:
Distance A:
Distance A Duct Diameters:
Distance B:
Distance B Duct Diameters:
Minimum Number of Traverse Points:
Actual Number of Traverse Points:
CIRCULAR DUCT
Cross Sectional Area of Duct:
Central Valley Water Reclamation (CVWR)
Jenbacher #2
AST-2023-4301
12/15/23
Stack Parameters
Duct Orientation:
Duct Design:
Distance from Far Wall to Outside of Port:
Nipple Length:
Depth of Duct:
No. of Test Ports:
Upstream
Disturbance
Downstream
Disturbance
B
A
28 of 87
Cyclonic Flow Check
Location
Source
Project No.
Date
Sample Point Angle (ΔP=0)
1 5
2 4
3 2
4 2
5 0
6 1
7 3
8 5
9 8
10 6
11 2
12 3
13 1
14 8
15 8
16 12
Average 4.4
Central Valley Water Reclamation (CVWR)
Jenbacher #2
AST-2023-4301
12/15/23
29 of 87
Field Data
Method 2 Data
Location
Source
Project No.
Δ P
(in. WC)
Ts
(°F)
Δ P
(in. WC)
Ts
(°F)
Δ P
(in. WC)
Ts
(°F)
0.95 335 0.90 337 0.88 337
1.10 338 1.00 338 0.95 338
1.20 339 1.00 340 1.00 340
1.30 339 1.10 340 1.10 340
1.30 340 1.10 341 1.10 341
1.30 340 1.00 341 1.20 341
1.10 341 1.00 341 1.10 341
1.00 341 0.84 342 1.00 342
0.88 336 0.79 335 0.96 335
0.92 338 0.85 340 0.99 340
0.95 339 1.00 341 1.10 341
1.00 340 1.20 341 1.00 341
1.10 341 1.30 342 1.10 342
1.00 342 1.20 342 1.10 342
1.00 342 1.10 343 0.82 343
0.95 342 0.95 343 0.88 343
Average
Square Root of ΔP, (in. WC)1/2 (ΔP)1/2 1.015
Average ΔP, in. WC (ΔP)1.03
Pitot Tube Coefficient (Cp)0.840
Barometric Pressure, in. Hg (Pb)25.88
Static Pressure, in. WC (Pg)1.07
Stack Pressure, in. Hg (Ps)25.96
Average Temperature, °F (Ts)340.1
Average Temperature, °R (Ts)799.7
Measured Moisture Fraction (BWSmsd)0.100
Moisture Fraction @ Saturation (BWSsat)1.000
Moisture Fraction (BWS)0.100
O2 Concentration, % (O2)11.5
CO2 Concentration, % (CO2)6.7
Molecular Weight, lb/lb-mole (dry) (Md)29.52
Molecular Weight, lb/lb-mole (wet) (Ms)28.37
Velocity, ft/sec (Vs)76.0
VFR at stack conditions, acfm (Qa)9,945
VFR at standard conditions, scfh (Qsw)341,558
VFR at standard conditions, scfm (Qsw)5,693
VFR at standard conditions, dscfm (Qsd)5,123
1.0001.0001.000
0.0980.1010.101
5,196 5,081 5,093
5,779 5,652 5,646
346,769 339,129 338,777
10,090 9,877 9,867
77.1 75.5 75.4
28.36 28.36 28.39
29.53 29.53 29.52
11.58 11.44 11.43
6.64 6.68 6.64
0.101 0.101 0.098
799.1 800.1 800.1
339.4 340.4 340.4
25.95 25.96 25.96
1.00 1.10 1.10
25.88 25.88 25.88
0.840 0.840 0.840
1.07 1.02 1.02
1.030 1.008 1.007
3
4
5
6
7
5
6
7
8
1
2
Traverse Point
1
2
3
4
Leak Check Pass Pass Pass
Stop Time 10:02 12:12 13:26
Start Time 9:50 11:07 13:20
8
Central Valley Water Reclamation (CVWR)
Jenbacher #2
AST-2023-4301
Run No. 1 2 3
Status VALID VALID VALID
Date 12/15/23 12/15/23 12/15/23
30 of 87
Jenbacher Engine #4
31 of 87
Emissions Calculations
Location
Source
Project No.
Run Number Run 1 Run 2 Run 3 Average
Date 12/14/23 12/14/23 12/14/23 --
Start Time 11:03 12:25 14:00 --
Stop Time 12:03 13:25 15:00 --
Engine Manufacturer
Engine Model
Engine Serial Number
Engine Type
Engine Date of Manufacturer DOM
Engine Hour Meter Reading EMR
Engine Exhaust Temperature, °F 980 975 965 973
Generator Output, Hz Gen OP 60 60 60 60
Engine Speed, RPM ES 1,500 1,500 1,500 1,500
Engine Brake Work, HP EBW 2,414 2,416 2,415 2,415
Maximum Brake Work, HP MaxEBW 2,509 2,509 2,509 2,509
Engine Load, % EL 96 96 96 96
Ambient Temperature TAmb 50 55 60 55
Relative Humidity, % RH
35 35 40 37
Barometric Pressure, in. Hg Pb
25.92 25.92 25.92 25.92
Moisture Fraction, dimensionless BWS 0.105 0.101 0.104 0.103
Volumetric Flow Rate (M1-4), dscfm Qs 4,923 5,024 4,964 4,969
O₂ Concentration, % dry CO₂11.20 11.25 11.20 11.22
CO₂ Concentration, % dry CCO₂6.50 6.62 6.49 6.54
Methane - Outlet Concentration, ppmvd CCH₄1299.22 1433.87 1641.07 1458.05
Methane - Outlet Concentration, ppmvw CCH₄w 1162.49 1289.11 1470.78 1307.46
Methane - Outlet Concentration, ppmvd @ 15 % O₂CCH₄c15 790.55 876.43 998.25 888.41
Methane - Outlet Emission Rate, lb/hr ERCH₄15.99 18.01 20.36 18.12
Methane - Outlet Emission Rate, ton/yr ERCH₄TPY 70.02 78.86 89.18 79.36
Methane - Outlet Emission Factor, g/HP-hr EFCH₄3.00 3.38 3.82 3.40
Ethane - Outlet Concentration, ppmvd CC₂H₆22.69 24.80 28.26 25.25
Ethane - Outlet Concentration, ppmvd (as C3H8)*CC₂H₆14.97 16.37 18.65 16.67
Ethane - Outlet Concentration, ppmvw CC₂H₆w 20.30 22.30 25.33 22.64
Ethane - Outlet Concentration, ppmvd @ 15 % O₂CC₂H₆c15 13.80 15.16 17.19 15.39
Ethane - Outlet Emission Rate, lb/hr ERC₂H₆0.52 0.58 0.66 0.59
Ethane - Outlet Emission Rate, ton/yr ERC₂H₆TPY 2.29 2.56 2.88 2.58
Ethane - Outlet Emission Factor, g/HP-hr EFC₂H₆0.10 0.11 0.12 0.11
Formaldehyde - Outlet Concentration, ppmvd CCHOH 44.67 44.57 51.71 46.98
Formaldehyde - Outlet Concentration, ppmvw CCHOHw 39.97 40.07 46.34 42.13
Formaldehyde - Outlet Concentration, ppmvd @ 15 % O₂CCHOHc15 27.18 27.24 31.45 28.63
Formaldehyde - Outlet Emission Rate, lb/hr ERCHOH 1.03 1.05 1.20 1.09
Formaldehyde - Outlet Emission Rate, ton/yr ERCHOHTPY 4.51 4.59 5.26 4.79
Formaldehyde - Outlet Emission Factor, g/HP-hr EFCHOH 0.19 0.20 0.23 0.21
CO - Outlet Concentration, ppmvd CCO 389.29 416.64 453.09 419.67
CO - Outlet Concentration, ppmvd @ 15 % O₂CCOc15 236.88 254.66 275.61 255.72
CO - Outlet Emission Rate, lb/hr ERCO 8.37 9.14 9.82 9.11
CO - Outlet Emission Rate, ton/yr ERCOTPY 36.64 40.02 43.00 39.88
CO - Outlet Emission Factor, g/HP-hr EFCO 1.57 1.72 1.84 1.71
NOx - Outlet Concentration, ppmvd CNOx 65.90 61.56 49.45 58.97
NOx - Outlet Concentration, ppmvd @ 15 % O₂CNOxc15 40.10 37.63 30.08 35.94
NOx - Outlet Emission Rate, lb/hr ERNOx 2.33 2.22 1.76 2.10
NOx - Outlet Emission Rate, ton/yr ERNOxTPY 10.19 9.71 7.71 9.20
NOx - Outlet Emission Factor, g/HP-hr EFNOx 0.44 0.42 0.33 0.39
VOC - Outlet Concentration, ppmvd CVOC 20.20 20.64 22.73 21.19
VOC - Outlet Concentration, ppmvd @ 15 % O₂CVOCc15 12.29 12.62 13.82 12.91
VOC - Outlet Emission Rate, lb/hr ERVOC 0.68 0.71 0.78 0.72
VOC - Outlet Emission Rate, ton/yr ERVOCTPY 2.99 3.12 3.40 3.17
VOC - Outlet Emission Factor, g/HP-hr EFVOC 0.13 0.13 0.15 0.14
NMHC - Outlet Concentration, ppmvd CNMHC (as C3H8)35.17 37.01 41.38 37.86
NMHC - Outlet Concentration, ppmvd @ 15 % O₂CNMHC (as C3H8)c15 21.40 22.62 25.17 23.07
NMHC - Outlet Emission Rate, lb/hr ERNMHC (as C3H8)1.19 1.28 1.41 1.29
NMHC - Outlet Emission Rate, ton/yr ERNMHC (as C3H8)TPY 5.21 5.60 6.18 5.66
NMHC - Outlet Emission Factor, g/HP-hr EFNMHC (as C3H8)0.22 0.24 0.27 0.24
Central Valley Water Reclamation (CVWR)
Jenbacher #4
AST-2023-4301
GE
JMS 612-F28F02
1322446
Compression Ignition
2018-01-01
Engine Data
7,931
Input Data - Outlet
Calculated Data - Outlet
FTIR Calculated Data
32 of 87
Run 1 - RM Data
Location:
Source:
Project No.:
Date:
Time O₂ - Outlet CO₂ - Outlet
Unit % dry % dry
Status Valid Valid
Uncorrected Run Average (Cobs)11.20 6.52
Cal Gas Concentration (CMA)12.00 11.96
Pretest System Zero Response 0.00 0.00
Posttest System Zero Response 0.00 0.00
Average Zero Response (Co)0.00 0.00
Pretest System Cal Response 12.00 12.00
Posttest System Cal Response 12.00 12.00
Average Cal Response (CM)12.00 12.00
Corrected Run Average (Corr)11.20 6.50
11:03 11.12 6.52
11:04 11.12 6.51
11:05 11.12 6.51
11:06 11.12 6.51
11:07 11.12 6.52
11:08 11.12 6.52
11:09 11.13 6.52
11:10 11.13 6.52
11:11 11.13 6.52
11:12 11.13 6.52
11:13 11.13 6.53
11:14 11.14 6.53
11:15 11.16 6.52
11:16 11.15 6.52
11:17 11.15 6.52
11:18 11.15 6.52
11:19 11.14 6.53
11:20 11.15 6.53
11:21 11.16 6.53
11:22 11.15 6.54
11:23 11.16 6.53
11:24 11.16 6.54
11:25 11.16 6.55
11:26 11.17 6.54
11:27 11.16 6.54
11:28 11.17 6.54
11:29 11.17 6.53
11:30 11.18 6.53
11:31 11.18 6.54
11:32 11.18 6.54
11:33 11.18 6.53
11:34 11.20 6.53
11:35 11.20 6.52
11:36 11.19 6.52
11:37 11.21 6.52
11:38 11.20 6.54
11:39 11.21 6.53
11:40 11.22 6.52
11:41 11.21 6.53
11:42 11.22 6.53
11:43 11.21 6.53
11:44 11.22 6.54
11:45 11.21 6.55
11:46 11.20 6.55
11:47 11.20 6.55
11:48 11.21 6.55
11:49 11.22 6.53
11:50 11.26 6.51
11:51 11.27 6.50
11:52 11.30 6.48
11:53 11.32 6.47
11:54 11.32 6.47
11:55 11.33 6.47
11:56 11.35 6.47
11:57 11.35 6.47
11:58 11.35 6.47
11:59 11.36 6.46
12:00 11.36 6.47
12:01 11.37 6.46
12:02 11.36 6.47
Central Valley Water Reclamation (CVWR)
Jenbacher #4
AST-2023-4301
12/14/23
33 of 87
Run 1 - FTIR Data
Location:
Source:
Project No.:
Date:
Time Temperature Pressure Methane - Outlet Ethane - Outlet Formaldehyde - Outlet CO - Outlet NOx - Outlet VOC - Outlet BWS - Outlet
Unit ° C atm ppmvw ppmvw ppmvw ppmvd ppmvd ppmvd % (wet)
MDL -- -- 0.04 0.08 0.08 0.13 0.74 0.28 --
Status Valid Valid Valid Valid Valid Valid Valid Valid Valid
11:03 191.4 0.839 1,164.3 21.6 40.3 393.6 63.7 21.2 10.7
11:04 191.4 0.838 1,173.2 21.3 41.7 396.8 63.3 21.1 10.9
11:05 191.4 0.840 1,174.5 21.2 41.0 394.1 64.0 20.2 10.7
11:06 191.4 0.840 1,176.9 21.3 38.7 392.3 64.8 20.7 10.1
11:07 191.4 0.840 1,184.3 21.6 38.3 393.9 64.7 21.3 10.0
11:08 191.4 0.836 1,173.4 21.1 38.3 391.5 64.9 20.8 10.2
11:09 191.4 0.837 1,164.0 21.0 40.4 392.0 64.7 19.8 10.6
11:10 191.4 0.838 1,144.9 20.3 43.1 387.9 65.8 20.7 11.1
11:11 191.4 0.837 1,147.8 20.7 42.1 389.1 65.8 19.8 11.0
11:12 191.4 0.839 1,162.3 20.7 41.2 391.8 65.5 19.4 10.8
11:13 191.4 0.840 1,167.1 20.8 41.1 392.9 65.0 21.9 10.8
11:14 191.4 0.838 1,155.4 20.6 40.8 389.1 66.2 20.6 10.7
11:15 191.4 0.836 1,166.0 20.7 39.9 391.0 65.6 19.8 10.6
11:16 191.4 0.837 1,169.4 21.0 40.0 391.7 65.4 19.9 10.7
11:17 191.4 0.838 1,160.0 20.7 39.8 388.3 65.7 19.9 10.6
11:18 191.4 0.837 1,165.7 20.8 39.7 391.7 66.1 20.1 10.6
11:19 191.4 0.838 1,143.0 20.5 39.6 385.7 67.0 19.7 10.7
11:20 191.4 0.837 1,136.2 20.1 40.5 384.2 67.2 19.9 10.7
11:21 191.4 0.837 1,142.6 20.0 40.5 384.0 67.0 19.7 10.6
11:22 191.4 0.835 1,144.1 19.8 40.2 385.9 67.4 21.0 10.5
11:23 191.4 0.836 1,151.5 20.5 41.5 387.0 67.1 20.9 10.5
11:24 191.4 0.837 1,153.7 20.2 40.1 386.1 66.6 19.3 10.3
11:25 191.4 0.836 1,151.2 20.5 39.5 384.1 67.6 19.7 10.1
11:26 191.4 0.837 1,159.6 20.6 38.4 387.1 67.1 19.2 10.1
11:27 191.4 0.838 1,148.3 20.2 37.7 384.2 67.2 20.0 10.2
11:28 191.4 0.836 1,130.6 19.5 37.6 379.8 68.4 18.3 10.2
11:29 191.4 0.837 1,147.1 19.9 37.7 383.4 67.9 21.3 10.3
11:30 191.4 0.835 1,140.2 20.0 40.1 384.3 67.6 19.5 10.8
11:31 191.4 0.838 1,119.0 19.1 39.3 379.3 67.9 19.9 10.7
11:32 191.4 0.835 1,130.1 19.3 39.5 382.9 67.8 20.2 10.7
11:33 191.4 0.837 1,123.1 19.3 44.9 382.0 68.3 20.0 11.3
11:34 191.4 0.837 1,148.9 19.8 40.5 387.7 67.3 18.5 10.7
11:35 191.4 0.837 1,145.9 19.7 39.7 386.8 66.4 21.1 10.6
11:36 191.4 0.837 1,122.9 19.2 39.3 379.5 68.5 19.4 10.7
11:37 191.4 0.837 1,153.9 19.5 38.9 385.5 67.1 20.8 10.5
11:38 191.4 0.837 1,131.1 18.6 38.8 381.4 67.6 20.1 10.4
11:39 191.4 0.836 1,145.0 19.6 40.2 385.4 67.6 21.2 10.4
11:40 191.4 0.836 1,157.1 19.7 40.0 387.9 66.8 18.7 10.3
11:41 191.4 0.835 1,131.1 19.3 38.8 380.7 68.0 19.7 10.4
11:42 191.4 0.836 1,137.9 19.6 38.8 385.6 67.3 18.8 10.7
11:43 191.4 0.834 1,114.7 18.8 39.4 382.6 68.4 18.6 10.8
11:44 191.4 0.835 1,127.0 18.5 39.8 383.2 68.0 21.2 10.9
11:45 191.4 0.836 1,113.3 18.8 40.4 380.0 68.2 19.5 10.9
11:46 191.4 0.836 1,106.2 18.4 40.9 377.8 68.6 20.0 11.1
11:47 191.4 0.834 1,103.3 19.7 46.0 378.4 71.3 18.9 11.6
11:48 191.4 0.835 1,122.5 19.1 40.4 378.3 69.9 19.3 10.5
11:49 191.4 0.835 1,124.7 19.8 39.5 380.5 69.3 19.9 10.4
11:50 191.4 0.835 1,155.1 19.6 39.6 390.3 66.3 19.8 10.5
11:51 191.4 0.835 1,178.8 20.6 38.4 390.9 66.7 20.7 10.1
11:52 191.4 0.835 1,205.0 21.0 39.2 400.4 63.2 20.9 10.4
11:53 191.3 0.835 1,216.8 21.3 39.1 394.4 62.8 19.7 10.2
11:54 191.4 0.834 1,230.2 20.7 38.6 403.9 62.9 21.2 10.0
11:55 191.4 0.836 1,213.6 21.3 39.2 393.1 62.6 21.0 10.2
11:56 191.4 0.834 1,238.2 21.7 40.1 409.3 61.2 20.8 10.4
11:57 191.4 0.834 1,234.0 21.3 41.3 399.5 62.0 21.2 10.6
11:58 191.4 0.835 1,222.1 21.3 39.4 406.9 61.2 21.3 10.4
11:59 191.4 0.835 1,237.6 21.2 40.3 400.4 61.9 21.2 10.4
12:00 191.3 0.834 1,236.2 21.5 39.7 398.4 61.1 20.4 10.2
12:01 191.3 0.835 1,235.0 21.6 39.4 406.4 61.7 21.0 10.0
12:02 191.3 0.835 1,224.5 21.0 39.7 396.2 61.8 20.6 10.1
12:03 191.3 0.834 1,230.4 21.1 39.0 407.8 60.9 20.7 9.9
Parameter Temperature Pressure Methane - Outlet Ethane - Outlet Formaldehyde - Outlet CO - Outlet NOx - Outlet VOC - Outlet BWS - Outlet
Run Average 191.4 0.836 1162.5 20.3 40.0 389.3 65.9 20.2 10.5
Central Valley Water Reclamation (CVWR)
Jenbacher #4
AST-2023-4301
12/14/23
34 of 87
Run 2 - RM Data
Location:
Source:
Project No.:
Date:
Time O₂ - Outlet CO₂ - Outlet
Unit % dry % dry
Status Valid Valid
Uncorrected Run Average (Cobs)11.18 6.59
Cal Gas Concentration (CMA)12.00 11.96
Pretest System Zero Response 0.08 0.08
Posttest System Zero Response 0.00 0.00
Average Zero Response (Co)0.04 0.04
Pretest System Cal Response 11.86 11.72
Posttest System Cal Response 12.00 12.00
Average Cal Response (CM)11.93 11.86
Corrected Run Average (Corr)11.25 6.62
12:25 11.16 6.58
12:26 11.15 6.59
12:27 11.15 6.60
12:28 11.13 6.62
12:29 11.14 6.62
12:30 11.16 6.62
12:31 11.17 6.60
12:32 11.18 6.61
12:33 11.17 6.61
12:34 11.17 6.62
12:35 11.16 6.63
12:36 11.16 6.63
12:37 11.18 6.61
12:38 11.17 6.62
12:39 11.15 6.65
12:40 11.16 6.65
12:41 11.17 6.64
12:42 11.18 6.63
12:43 11.18 6.64
12:44 11.19 6.63
12:45 11.20 6.63
12:46 11.19 6.64
12:47 11.19 6.65
12:48 11.22 6.62
12:49 11.20 6.63
12:50 11.20 6.63
12:51 11.18 6.65
12:52 11.11 6.70
12:53 11.08 6.70
12:54 11.04 6.72
12:55 11.04 6.73
12:56 11.08 6.68
12:57 11.16 6.62
12:58 11.13 6.64
12:59 11.10 6.68
13:00 11.08 6.69
13:01 11.07 6.68
13:02 11.03 6.69
13:03 11.01 6.71
13:04 11.01 6.73
13:05 11.02 6.71
13:06 10.98 6.73
13:07 11.05 6.68
13:08 11.31 6.48
13:09 11.23 6.53
13:10 11.09 6.63
13:11 11.04 6.67
13:12 11.07 6.64
13:13 11.33 6.44
13:14 11.29 6.45
13:15 11.38 6.39
13:16 11.35 6.40
13:17 11.49 6.30
13:18 11.49 6.28
13:19 11.36 6.38
13:20 11.34 6.39
13:21 11.36 6.36
13:22 11.31 6.41
13:23 11.43 6.31
13:24 11.54 6.21
Central Valley Water Reclamation (CVWR)
Jenbacher #4
AST-2023-4301
12/14/23
35 of 87
Run 2 - FTIR Data
Location:
Source:
Project No.:
Date:
Time Temperature Pressure Methane - Outlet Ethane - Outlet Formaldehyde - Outlet CO - Outlet NOx - Outlet VOC - Outlet BWS - Outlet
Unit ° C atm ppmvw ppmvw ppmvw ppmvd ppmvd ppmvd % (wet)
MDL -- -- 0.04 0.08 0.08 0.13 0.74 0.28 --
Status Valid Valid Valid Valid Valid Valid Valid Valid Valid
12:25 191.3 0.830 1,230.7 21.9 33.6 390.2 63.3 18.3 8.8
12:26 191.3 0.831 1,226.1 21.5 31.9 394.2 64.2 18.1 8.3
12:27 191.4 0.831 1,216.5 21.5 32.4 385.6 64.8 18.8 8.7
12:28 191.3 0.832 1,206.7 21.3 32.0 391.9 66.0 18.1 8.5
12:29 191.3 0.830 1,205.9 20.9 32.3 391.1 65.6 19.1 8.7
12:30 191.3 0.832 1,194.3 20.8 36.6 395.0 64.4 19.7 9.6
12:31 191.3 0.833 1,218.6 20.9 34.2 395.8 64.4 18.7 8.8
12:32 191.3 0.832 1,236.6 21.7 33.2 390.8 63.8 18.0 8.9
12:33 191.2 0.833 1,224.2 21.3 33.1 395.9 64.1 18.7 8.8
12:34 191.1 0.834 1,236.2 21.5 32.9 389.2 63.9 19.5 8.7
12:35 191.1 0.833 1,211.4 20.9 31.7 392.9 65.7 17.9 8.5
12:36 191.2 0.833 1,208.6 20.7 31.6 391.9 65.9 18.0 8.5
12:37 191.1 0.830 1,210.5 20.4 37.8 402.6 64.5 19.5 10.2
12:38 191.1 0.831 1,167.9 20.2 43.7 396.5 66.2 19.8 11.6
12:39 191.1 0.832 1,153.7 19.6 40.6 391.6 67.0 20.4 10.6
12:40 191.1 0.830 1,169.7 19.7 36.7 388.1 66.9 18.6 9.4
12:41 191.1 0.830 1,157.6 19.5 37.7 388.5 66.7 18.9 10.0
12:42 191.2 0.829 1,178.3 20.1 38.0 394.0 66.2 18.6 10.0
12:43 191.1 0.829 1,175.0 20.5 38.2 391.7 66.6 20.1 10.1
12:44 191.1 0.830 1,191.4 20.2 40.7 399.8 64.9 20.9 10.6
12:45 191.1 0.828 1,199.0 20.5 38.5 398.0 65.2 19.1 10.1
12:46 191.1 0.829 1,197.3 20.7 40.1 399.3 65.1 19.6 10.4
12:47 191.1 0.830 1,180.2 20.3 40.2 396.4 66.0 19.5 10.6
12:48 191.1 0.829 1,211.1 20.8 39.5 403.6 63.6 20.4 10.3
12:49 191.1 0.831 1,188.6 20.3 40.6 398.0 65.1 20.5 10.3
12:50 191.0 0.832 1,169.5 19.8 40.8 393.4 65.5 19.8 10.4
12:51 191.1 0.834 1,169.4 20.0 38.6 390.7 66.6 19.3 10.1
12:52 191.2 0.833 1,122.3 18.3 38.1 377.8 71.0 20.7 10.1
12:53 191.4 0.832 1,085.9 17.7 38.4 369.6 74.7 19.5 10.3
12:54 191.4 0.834 1,048.1 17.0 37.5 360.6 77.5 18.7 10.2
12:55 191.4 0.834 1,056.8 17.2 38.1 362.7 77.1 19.3 10.4
12:56 191.3 0.835 1,094.1 17.9 40.2 374.8 72.4 18.9 10.5
12:57 191.4 0.836 1,178.9 20.0 39.0 394.6 64.5 19.2 10.3
12:58 191.4 0.836 1,148.5 19.7 42.7 389.6 67.1 19.4 11.3
12:59 191.5 0.838 1,137.3 18.7 39.9 383.7 67.9 20.5 10.6
13:00 191.4 0.839 1,129.7 18.3 39.6 381.7 69.0 19.9 10.4
13:01 191.1 0.838 1,116.8 18.2 39.9 380.2 70.0 18.4 10.7
13:02 191.2 0.839 1,085.6 17.6 39.2 370.7 73.0 18.6 10.6
13:03 191.4 0.840 1,086.8 17.7 40.0 373.6 72.8 19.4 10.9
13:04 191.4 0.838 1,091.2 17.8 40.2 374.4 72.1 18.3 10.9
13:05 191.5 0.839 1,094.8 17.7 42.6 382.8 69.8 21.1 12.0
13:06 191.5 0.841 1,072.2 17.6 41.3 371.6 73.8 19.5 11.4
13:07 191.5 0.840 1,141.9 19.7 41.6 389.8 68.7 18.6 11.2
13:08 191.5 0.841 1,459.3 25.5 44.3 458.4 49.1 24.1 10.9
13:09 191.5 0.840 1,369.4 24.0 43.7 430.0 55.2 22.3 10.6
13:10 191.5 0.842 1,217.6 20.3 41.6 395.4 62.7 20.2 10.5
13:11 191.4 0.841 1,195.8 20.2 40.6 400.0 66.0 19.7 10.5
13:13 191.4 0.841 1,524.8 27.4 43.7 471.6 47.6 24.1 10.6
13:14 191.4 0.841 1,554.9 27.7 45.1 473.4 47.3 23.0 10.3
13:15 191.4 0.843 1,550.4 28.0 44.5 473.5 48.5 24.0 10.3
13:16 191.4 0.841 1,610.0 29.0 45.9 487.8 45.6 24.0 10.2
13:17 191.4 0.842 1,805.3 33.4 46.8 533.9 39.8 26.8 10.2
13:18 191.4 0.845 1,821.1 33.9 47.3 536.8 38.5 26.8 10.0
13:19 191.4 0.842 1,690.0 30.7 47.6 505.0 43.1 24.5 10.0
13:20 191.4 0.842 1,599.6 28.0 46.4 484.7 45.4 24.4 10.0
13:21 191.4 0.843 1,700.5 30.7 47.2 513.5 41.3 24.9 10.3
13:22 191.4 0.844 1,565.5 27.1 46.7 477.0 46.2 23.4 10.2
13:23 191.3 0.843 1,758.3 32.1 47.4 523.3 40.6 24.7 10.1
13:24 191.3 0.842 1,952.8 35.7 49.8 581.2 36.3 27.1 10.1
13:25 191.3 0.842 1,945.7 35.8 50.3 577.8 36.7 26.8 10.0
Parameter Temperature Pressure Methane - Outlet Ethane - Outlet Formaldehyde - Outlet CO - Outlet NOx - Outlet VOC - Outlet BWS - Outlet
Run Average 191.3 0.836 1289.1 22.3 40.1 416.6 61.6 20.6 10.1
Central Valley Water Reclamation (CVWR)
Jenbacher #4
AST-2023-4301
12/14/23
36 of 87
Run 3 - RM Data
Location:
Source:
Project No.:
Date:
Time O₂ - Outlet CO₂ - Outlet
Unit % dry % dry
Status Valid Valid
Uncorrected Run Average (Cobs)11.01 6.43
Cal Gas Concentration (CMA)12.00 11.96
Pretest System Zero Response -0.10 0.03
Posttest System Zero Response 0.00 0.00
Average Zero Response (Co)-0.05 0.02
Pretest System Cal Response 11.59 11.66
Posttest System Cal Response 12.00 12.00
Average Cal Response (CM)11.80 11.83
Corrected Run Average (Corr)11.20 6.49
14:00 11.09 6.39
14:01 11.07 6.40
14:02 11.07 6.41
14:03 11.07 6.41
14:04 11.07 6.42
14:05 11.06 6.42
14:06 11.06 6.42
14:07 11.05 6.41
14:08 11.05 6.42
14:09 11.05 6.41
14:10 11.03 6.42
14:11 11.05 6.42
14:12 11.04 6.42
14:13 11.03 6.42
14:14 11.03 6.43
14:15 11.03 6.43
14:16 11.02 6.44
14:17 11.02 6.44
14:18 11.02 6.43
14:19 11.02 6.43
14:20 11.01 6.43
14:21 11.02 6.42
14:22 11.01 6.42
14:23 11.00 6.43
14:24 11.02 6.42
14:25 11.02 6.43
14:26 11.00 6.43
14:27 11.02 6.42
14:28 11.01 6.42
14:29 10.99 6.44
14:30 10.98 6.44
14:31 10.93 6.46
14:32 10.97 6.45
14:33 11.01 6.42
14:34 10.99 6.42
14:35 10.97 6.43
14:36 10.93 6.46
14:37 10.95 6.45
14:38 10.96 6.45
14:39 10.96 6.46
14:40 10.96 6.45
14:41 10.96 6.45
14:42 10.96 6.45
14:43 10.97 6.45
14:44 10.99 6.42
14:45 11.01 6.42
14:46 10.99 6.43
14:47 10.98 6.43
14:48 10.99 6.42
14:49 11.00 6.42
14:50 11.00 6.42
14:51 10.99 6.42
14:52 11.02 6.40
14:53 11.02 6.40
14:54 11.00 6.41
14:55 10.98 6.43
14:56 10.98 6.43
14:57 10.94 6.45
14:58 10.94 6.45
14:59 11.00 6.41
Central Valley Water Reclamation (CVWR)
Jenbacher #4
AST-2023-4301
12/14/23
37 of 87
Run 3 - FTIR Data
Location:
Source:
Project No.:
Date:
Time Temperature Pressure Methane - Outlet Ethane - Outlet Formaldehyde - Outlet CO - Outlet NOx - Outlet VOC - Outlet BWS - Outlet
Unit ° C atm ppmvw ppmvw ppmvw ppmvd ppmvd ppmvd % (wet)
MDL -- -- 0.04 0.08 0.08 0.13 0.74 0.28 --
Status Valid Valid Valid Valid Valid Valid Valid Valid Valid
14:00 191.2 0.844 1,520.4 26.3 48.0 464.7 47.8 22.6 10.3
14:01 191.3 0.842 1,507.9 25.8 47.1 461.3 48.6 23.2 10.2
14:02 191.4 0.842 1,517.8 26.5 46.7 462.0 48.3 22.8 10.1
14:03 191.3 0.843 1,511.6 26.2 47.9 462.8 48.2 23.6 10.4
14:04 191.3 0.843 1,518.7 25.9 48.5 464.1 48.0 23.1 10.4
14:05 191.3 0.841 1,494.0 25.3 45.9 457.9 49.0 22.7 10.2
14:06 191.3 0.842 1,473.8 25.8 52.2 467.2 48.9 23.9 12.0
14:07 191.3 0.841 1,487.1 26.2 50.9 463.6 49.7 23.6 11.2
14:08 191.3 0.842 1,486.0 25.7 52.0 461.2 48.2 24.6 10.9
14:09 191.3 0.841 1,495.8 25.9 50.0 463.6 48.5 23.0 10.7
14:10 191.3 0.842 1,475.0 25.4 48.3 455.3 49.6 23.7 10.6
14:11 191.3 0.842 1,506.9 26.0 45.7 459.7 48.6 21.8 10.1
14:12 191.2 0.843 1,491.1 25.9 47.7 457.4 48.5 22.2 10.2
14:13 191.2 0.841 1,499.4 25.7 45.8 458.8 48.7 22.3 10.1
14:14 191.3 0.843 1,474.8 25.2 45.3 452.2 49.4 22.4 10.1
14:15 191.2 0.841 1,485.5 25.5 46.6 456.5 49.0 23.1 10.3
14:16 191.2 0.845 1,453.2 24.9 46.3 449.6 49.6 20.9 10.4
14:17 191.2 0.843 1,456.0 24.4 48.5 455.1 49.3 23.3 11.1
14:18 191.2 0.843 1,477.6 25.7 50.4 461.4 48.8 22.1 11.0
14:19 191.3 0.842 1,468.1 25.1 47.8 453.3 49.3 23.5 10.5
14:20 191.3 0.843 1,475.3 25.5 45.7 453.2 49.4 22.3 10.2
14:21 191.4 0.841 1,478.4 25.3 45.4 453.3 49.5 22.2 10.1
14:22 191.3 0.844 1,475.4 25.5 44.7 452.4 49.6 22.5 10.1
14:23 191.3 0.840 1,458.9 24.5 48.3 451.9 49.9 23.4 10.8
14:24 191.2 0.842 1,481.0 25.6 47.2 455.6 49.2 22.7 10.5
14:25 191.3 0.842 1,493.5 25.3 47.0 459.1 49.0 23.7 10.5
14:26 191.4 0.842 1,471.7 24.9 47.8 454.0 49.4 23.2 10.6
14:27 191.3 0.843 1,494.7 25.7 47.3 458.9 48.0 23.7 10.6
14:28 191.3 0.843 1,486.8 25.3 46.7 455.9 48.9 23.1 10.4
14:29 191.3 0.842 1,464.3 25.1 45.7 450.7 49.8 22.8 10.2
14:30 191.3 0.843 1,457.6 25.1 44.3 447.2 50.3 21.3 10.1
14:31 191.3 0.841 1,391.9 23.5 46.0 433.2 52.6 22.4 10.5
14:32 191.3 0.842 1,426.7 24.6 45.4 441.7 50.6 22.5 10.4
14:33 191.3 0.842 1,485.4 25.5 44.9 457.1 48.1 22.8 10.3
14:34 191.3 0.841 1,469.0 25.6 46.4 452.1 49.4 23.6 10.4
14:35 191.3 0.841 1,450.6 25.2 43.4 445.8 50.5 22.0 9.9
14:36 191.3 0.843 1,408.9 23.9 42.4 433.1 52.3 21.2 9.9
14:37 191.3 0.843 1,414.9 24.4 46.1 440.0 51.6 23.1 10.5
14:38 191.3 0.844 1,432.9 24.6 45.2 443.4 50.7 21.7 10.4
14:39 191.3 0.842 1,412.8 24.2 45.3 440.4 51.2 22.6 10.4
14:40 191.3 0.842 1,427.3 24.9 44.1 442.0 50.6 21.5 10.2
14:41 191.3 0.843 1,419.5 24.8 42.4 438.9 51.1 21.7 9.9
14:42 191.3 0.843 1,449.0 24.7 45.4 447.5 50.5 22.8 10.3
14:43 191.3 0.845 1,441.5 25.0 42.4 442.6 50.3 22.7 9.9
14:44 191.4 0.843 1,468.9 25.2 45.7 450.9 49.1 22.5 10.4
14:45 191.4 0.843 1,500.2 26.8 44.2 458.9 48.3 23.1 10.2
14:46 191.3 0.843 1,469.3 25.9 44.2 451.8 49.3 22.2 10.2
14:47 191.3 0.843 1,448.4 25.3 46.8 447.4 50.2 23.0 10.5
14:48 191.3 0.843 1,471.5 25.6 45.7 453.2 49.1 23.5 10.3
14:49 191.3 0.842 1,485.1 26.0 44.6 456.5 48.9 21.7 10.2
14:50 191.3 0.844 1,489.2 26.0 43.8 455.9 48.5 22.9 10.1
14:51 191.3 0.845 1,476.4 25.5 46.8 454.5 49.0 23.8 10.5
14:52 191.3 0.843 1,515.4 26.7 44.8 460.5 48.2 22.6 10.1
14:53 191.3 0.843 1,527.7 26.4 44.1 463.1 47.7 24.0 10.0
14:54 191.3 0.844 1,491.9 26.0 48.3 458.4 48.6 23.7 10.6
14:55 191.3 0.844 1,464.0 24.5 47.4 450.7 49.6 22.8 10.3
14:56 191.3 0.844 1,465.4 24.7 46.6 452.5 49.5 22.8 10.4
14:57 191.3 0.843 1,413.9 24.1 45.6 441.7 51.3 22.0 10.4
14:58 191.3 0.843 1,415.1 24.1 44.6 439.4 51.4 21.9 10.3
14:59 191.2 0.842 1,495.1 25.3 44.5 457.6 48.7 22.4 10.1
15:00 191.3 0.843 1,451.7 24.7 48.0 448.0 50.6 21.8 10.5
Parameter Temperature Pressure Methane - Outlet Ethane - Outlet Formaldehyde - Outlet CO - Outlet NOx - Outlet VOC - Outlet BWS - Outlet
Run Average 191.3 0.843 1470.8 25.3 46.3 453.1 49.5 22.7 10.4
Central Valley Water Reclamation (CVWR)
Jenbacher #4
AST-2023-4301
12/14/23
38 of 87
Method 1 Data
Location
Source
Project No.
Date
Vertical
Circular
26.00 in
6.00 in
20.00 in
2.18 ft2
2
1
1.1 ft
0.7 (must be > 0.5)
4.1 ft
2.5 (must be > 2)
16
16
Measurer (Initial and Date):DBR
Reviewer (Initial and Date):RBB
2345 6 789101112
1 14.6 -- 6.7 -- 4.4 -- 3.2 -- 2.6 -- 2.1 1 3.2 0.64 6.64
2 85.4 -- 25.0 -- 14.6 -- 10.5 -- 8.2 -- 6.7 2 10.52.108.10
3 -- -- 75.0 -- 29.6 -- 19.4 -- 14.6 -- 11.8 3 19.43.889.88
4 -- -- 93.3 -- 70.4 -- 32.3 -- 22.6 -- 17.7 4 32.3 6.46 12.46
5 -- -- -- -- 85.4 -- 67.7 -- 34.2 -- 25.0 5 67.7 13.54 19.54
6 -- -- -- -- 95.6 -- 80.6 -- 65.8 -- 35.6 6 80.6 16.12 22.12
7 -- -- -- -- -- -- 89.5 -- 77.4 -- 64.4 7 89.5 17.90 23.90
8 -- -- -- -- -- -- 96.8 -- 85.4 -- 75.0 8 96.8 19.36 25.36
9 -- -- -- -- -- -- -- -- 91.8 -- 82.3 9 -- -- --
10 -- -- -- -- -- -- -- -- 97.4 -- 88.2 10 -- -- --
11 -- -- -- -- -- -- -- -- -- -- 93.3 11 -- -- --
12 -- -- -- -- -- -- -- -- -- -- 97.9 12 -- -- --
*Percent of stack diameter from inside wall to traverse point.
A = 1.1 ft.
B = 4.1 ft.
Depth of Duct = 20 in.
Number of traverse points on a diameter
Stack Diagram
Cross Sectional Area
LOCATION OF TRAVERSE POINTS
Traverse
Point
% of
Diameter
Distance
from inside
wall
Distance
from
outside of
port
Number of Readings per Point:
Distance A:
Distance A Duct Diameters:
Distance B:
Distance B Duct Diameters:
Minimum Number of Traverse Points:
Actual Number of Traverse Points:
CIRCULAR DUCT
Cross Sectional Area of Duct:
Central Valley Water Reclamation (CVWR)
Jenbacher #4
AST-2023-4301
12/14/23
Stack Parameters
Duct Orientation:
Duct Design:
Distance from Far Wall to Outside of Port:
Nipple Length:
Depth of Duct:
No. of Test Ports:
Upstream
Disturbance
Downstream
Disturbance
B
A
39 of 87
Cyclonic Flow Check
Location
Source
Project No.
Date
Sample Point Angle (ΔP=0)
1 12
2 15
3 7
4 3
5 3
6 0
7 0
8 10
9 5
10 6
11 9
12 4
13 5
14 5
15 10
16 12
Average 6.6
Central Valley Water Reclamation (CVWR)
Jenbacher #4
AST-2023-4301
12/14/23
40 of 87
Field Data
Method 2 Data
Location
Source
Project No.
Δ P
(in. WC)
Ts
(°F)
Δ P
(in. WC)
Ts
(°F)
Δ P
(in. WC)
Ts
(°F)
0.87 361 1.00 360 0.90 359
0.82 361 0.99 360 0.92 360
0.92 362 1.00 361 1.00 360
1.30 363 1.10 361 1.10 361
1.20 363 1.20 362 1.00 362
1.20 363 1.20 362 1.10 362
0.95 363 1.00 362 0.99 363
0.88 362 1.00 362 0.96 363
1.00 362 0.98 362 0.90 361
1.10 363 1.00 362 1.10 363
1.10 363 1.10 363 1.10 363
1.10 363 1.10 363 1.20 364
0.95 363 1.00 364 1.00 365
0.88 364 0.95 364 1.00 365
0.86 363 0.90 364 0.90 365
0.79 363 0.88 364 0.92 365
Average
Square Root of ΔP, (in. WC)1/2 (ΔP)1/2 1.003
Average ΔP, in. WC (ΔP)1.01
Pitot Tube Coefficient (Cp)0.840
Barometric Pressure, in. Hg (Pb)25.80
Static Pressure, in. WC (Pg)1.07
Stack Pressure, in. Hg (Ps)25.88
Average Temperature, °F (Ts)362.5
Average Temperature, °R (Ts)822.2
Measured Moisture Fraction (BWSmsd)0.103
Moisture Fraction @ Saturation (BWSsat)1.000
Moisture Fraction (BWS)0.103
O2 Concentration, % (O2)11.2
CO2 Concentration, % (CO2)6.5
Molecular Weight, lb/lb-mole (dry) (Md)29.49
Molecular Weight, lb/lb-mole (wet) (Ms)28.31
Velocity, ft/sec (Vs)76.3
VFR at stack conditions, acfm (Qa)9,985
VFR at standard conditions, scfh (Qsw)332,569
VFR at standard conditions, scfm (Qsw)5,543
VFR at standard conditions, dscfm (Qsd)4,970
1.0001.0001.000
0.1040.1010.105
4,923 5,024 4,964
5,501 5,588 5,540
330,037 335,285 332,387
9,912 10,065 9,979
75.7 76.9 76.2
28.28 28.35 28.29
29.49 29.51 29.49
11.21 11.25 11.20
6.50 6.62 6.49
0.105 0.101 0.104
822.3 822.1 822.2
362.6 362.4 362.6
25.87 25.88 25.88
1.00 1.10 1.10
25.80 25.80 25.80
0.840 0.840 0.840
1.00 1.03 1.01
0.995 1.011 1.002
3
4
5
6
7
5
6
7
8
1
2
Traverse Point
1
2
3
4
Leak Check Pass Pass Pass
Stop Time 11:40 13:11 14:26
Start Time 11:30 13:06 14:20
8
Central Valley Water Reclamation (CVWR)
Jenbacher #4
AST-2023-4301
Run No. 1 2 3
Status VALID VALID VALID
Date 12/14/23 12/14/23 12/14/23
41 of 87

Appendix C

42 of 87
QA Data
Location
Source
Project No.
O₂ - Outlet CO₂ - Outlet
Make Servomex Servomex
Model 1400 1400
S/N 1420C-2 1415C-6
Operating Range 0-25 0-25
Cylinder ID
Zero NA NA
Low NA NA
Mid CC764364 CC764364
High CC764364 CC764364
Cylinder Certifed Values
Zero NA NA
Low NA NA
Mid 23.98 23.9
High 23.98 23.9
Cylinder Expiration Date
Zero NA NA
Low NA NA
Mid 9/19/31 9/19/31
High 9/19/31 9/19/31
Type of Sample Line Heated Sample Line
Parameter
Central Valley Water Reclamation (CVWR)
Jenbacher #2
AST-2023-4301
43 of 87
Calibration Data
Location:
Source:
Project No.:
Date:
O₂ - Outlet CO₂ - Outlet
Expected Average Concentration 10.00 8.00
Span Between
Low 10.00 8.00
High 50.00 40.00
Desired Span 23.98 23.90
Low Range Gas
Low NA NA
High NA NA
Mid Range Gas
Low 9.59 9.56
High 14.39 14.34
High Range Gas
Low NA NA
High NA NA
Actual Concentration (% or ppm)
Zero 0.00 0.00
Low NA NA
Mid 12.00 12.00
High 23.98 23.90
Upscale Calibration Gas (CMA)Mid Mid
Instrument Response (% or ppm)
Zero 0.06 -0.04
Low NA NA
Mid 11.97 11.87
High 23.97 23.81
Performance (% of Span or Cal. Gas Conc.)
Zero 0.25 0.17
Low NA NA
Mid 0.13 0.54
High 0.04 0.38
Status
Zero PASS PASS
Low NA NA
Mid PASS PASS
High PASS PASS
Jenbacher #2
Central Valley Water Reclamation (CVWR)
Parameter
12/15/23
AST-2023-4301
44 of 87
Bias/Drift Determinations
Location:
Source:
Project No.:
O₂ - Outlet CO₂ - Outlet
Run 1 Date 12/15/23
Span Value 23.98 23.90
Initial Instrument Zero Cal Response 0.06 -0.04
Initial Instrument Upscale Cal Response 11.97 11.87
Pretest System Zero Response -0.01 0.02
Posttest System Zero Response 0.08 -0.02
Pretest System Upscale Response 11.83 11.79
Posttest System Upscale Response 11.88 11.68
Bias (%)
Pretest Zero -0.29 0.25
Posttest Zero 0.08 0.08
Pretest Span -0.58 -0.33
Posttest Span -0.39 -0.79
Drift (%)
Zero 0.38 -0.17
Mid 0.20 -0.46
Run 2 Date 12/15/23
Span Value 23.98 23.90
Instrument Zero Cal Response 0.06 -0.04
Instrument Upscale Cal Response 11.97 11.87
Pretest System Zero Response 0.08 -0.02
Posttest System Zero Response 0.01 0.03
Pretest System Upscale Response 11.88 11.68
Posttest System Upscale Response 11.81 11.71
Bias (%)
Pretest Zero 0.08 0.08
Posttest Zero -0.22 0.31
Pretest Span -0.39 -0.79
Posttest Span -0.65 -0.67
Drift (%)
Zero -0.30 0.23
Mid -0.27 0.12
Run 3 Date 12/15/23
Span Value 23.98 23.90
Instrument Zero Cal Response 0.06 -0.04
Instrument Upscale Cal Response 11.97 11.87
Pretest System Zero Response 0.01 0.03
Posttest System Zero Response 0.00 0.00
Pretest System Upscale Response 11.81 11.71
Posttest System Upscale Response 11.80 11.70
Bias (%)
Pretest Zero -0.22 0.31
Posttest Zero -0.25 0.16
Pretest Span -0.65 -0.67
Posttest Span -0.72 -0.71
Drift (%)
Zero -0.03 -0.15
Mid -0.07 -0.04
Parameter
Central Valley Water Reclamation (CVWR)
Jenbacher #2
AST-2023-4301
45 of 87
Location:
Source:
Project No.:
Date:
Time O2 CO2
(%) (%)
A-1 9:10 11.20 6.62
2 9:11 11.23 6.60
3 9:12 11.24 6.60
11.2 6.6
Single Point Single Point
Average
Criteria Met
Traverse Point
Central Valley Water Reclamation (CVWR)
Jenbacher #2
AST-2023-4301
12/15/2024
46 of 87
QA Data
Location
Source
Project No.
Parameter(s)
Date Pitot ID
Evidence of
damage?
Evidence of
mis-alignment?
Calibration or
Repair required?
12/14/23 703-2 no no no
Date Probe or
Thermocouple ID
Reference
Temp. (°F)
Indicated
Temp. (°F)Difference Criteria
12/14/23 703-2 48.0 48.0 0.0%
Date Barometric
Pressure
Evidence of
damage?
Reading
Verified
Calibration or
Repair required?
12/14/23 Weather Station NA NA NA
Central Valley Water Reclamation (CVWR)
Jenbacher #2
AST-2023-4301
VFR
± 1.5 % (absolute)
Weather Station Location
Salt Lake City, UT
47 of 87
Response Times
Location:
Source:
Project No.:
O₂ - Outlet CO₂ - Outlet
Zero 20 20
Low NA NA
Mid 20 20
Average 20.0 20.0
Central Valley Water Reclamation (CVWR)
Jenbacher #2
AST-2023-4301
Parameter
Response Times, seconds
48 of 87
QA Data
Location
Source
Project No.
O₂ - Outlet CO₂ - Outlet
Make Servomex Servomex
Model 1400 1400
S/N 1420C-2 1415C-6
Operating Range 0-25 0-25
Cylinder ID
Zero NA NA
Low NA NA
Mid CC764364 CC764364
High CC764364 CC764364
Cylinder Certifed Values
Zero NA NA
Low NA NA
Mid 23.98 23.9
High 23.98 23.9
Cylinder Expiration Date
Zero NA NA
Low NA NA
Mid 9/19/31 9/19/31
High 9/19/31 9/19/31
Type of Sample Line Heated Sample Line
Parameter
Central Valley Water Reclamation (CVWR)
Jenbacher #4
AST-2023-4301
49 of 87
Calibration Data
Location:
Source:
Project No.:
Date:
O₂ - Outlet CO₂ - Outlet
Expected Average Concentration 10.00 10.00
Span Between
Low 10.00 10.00
High 50.00 50.00
Desired Span 23.98 23.90
Low Range Gas
Low NA NA
High NA NA
Mid Range Gas
Low 9.59 9.56
High 14.39 14.34
High Range Gas
Low NA NA
High NA NA
Actual Concentration (% or ppm)
Zero 0.00 0.00
Low NA NA
Mid 12.00 11.96
High 23.98 23.90
Upscale Calibration Gas (CMA)Mid Mid
Instrument Response (% or ppm)
Zero 0.01 0.07
Low NA NA
Mid 11.86 11.96
High 23.77 23.78
Performance (% of Span or Cal. Gas Conc.)
Zero 0.04 0.29
Low NA NA
Mid 0.58 0.00
High 0.88 0.50
Status
Zero PASS PASS
Low NA NA
Mid PASS PASS
High PASS PASS
Jenbacher #4
Central Valley Water Reclamation (CVWR)
Parameter
12/14/23
AST-2023-4301
50 of 87
Bias/Drift Determinations
Location:
Source:
Project No.:
O₂ - Outlet CO₂ - Outlet
Run 1 Date 12/14/23
Span Value 23.98 23.90
Initial Instrument Zero Cal Response 0.01 0.07
Initial Instrument Upscale Cal Response 11.86 11.96
Pretest System Zero Response 0.00 0.00
Posttest System Zero Response 0.00 0.00
Pretest System Upscale Response 12.00 12.00
Posttest System Upscale Response 12.00 12.00
Bias (%)
Pretest Zero -0.04 -0.29
Posttest Zero -0.04 -0.29
Pretest Span 0.58 0.17
Posttest Span 0.58 0.17
Drift (%)
Zero 0.00 0.00
Mid 0.00 0.00
Run 2 Date 12/14/23
Span Value 23.98 23.90
Instrument Zero Cal Response 0.01 0.07
Instrument Upscale Cal Response 11.86 11.96
Pretest System Zero Response 0.08 0.08
Posttest System Zero Response 0.00 0.00
Pretest System Upscale Response 11.86 11.72
Posttest System Upscale Response 12.00 12.00
Bias (%)
Pretest Zero 0.29 0.04
Posttest Zero -0.04 -0.29
Pretest Span 0.00 -1.00
Posttest Span 0.58 0.17
Drift (%)
Zero -0.33 -0.33
Mid 0.58 1.17
Run 3 Date 12/14/23
Span Value 23.98 23.90
Instrument Zero Cal Response 0.01 0.07
Instrument Upscale Cal Response 11.86 11.96
Pretest System Zero Response -0.10 0.03
Posttest System Zero Response 0.00 0.00
Pretest System Upscale Response 11.59 11.66
Posttest System Upscale Response 12.00 12.00
Bias (%)
Pretest Zero -0.46 -0.17
Posttest Zero -0.04 -0.29
Pretest Span -1.13 -1.26
Posttest Span 0.58 0.17
Drift (%)
Zero 0.42 -0.13
Mid 1.71 1.42
Parameter
Central Valley Water Reclamation (CVWR)
Jenbacher #4
AST-2023-4301
51 of 87
Location:
Source:
Project No.:
Date:
Time O2 CO2
(%) (%)
A-1 10:50 11.66 6.35
2 10:51 11.65 6.35
3 10:52 11.66 6.35
11.7 6.4
Single Point Single Point
Average
Criteria Met
Traverse Point
Central Valley Water Reclamation (CVWR)
Jenbacher #4
AST-2023-4301
12/14/2024
52 of 87
QA Data
Location
Source
Project No.
Parameter(s)
Date Pitot ID
Evidence of
damage?
Evidence of
mis-alignment?
Calibration or
Repair required?
12/14/23 703-2 no no no
Date Probe or
Thermocouple ID
Reference
Temp. (°F)
Indicated
Temp. (°F)Difference Criteria
12/14/23 703-2 48.0 48.0 0.0%
Date Barometric
Pressure
Evidence of
damage?
Reading
Verified
Calibration or
Repair required?
12/14/23 Weather Station NA NA NA
Central Valley Water Reclamation (CVWR)
Jenbacher #4
AST-2023-4301
VFR
± 1.5 % (absolute)
Weather Station Location
Salt Lake City, UT
53 of 87
Response Times
Location:
Source:
Project No.:
O₂ - Outlet CO₂ - Outlet
Zero 25 25
Low NA NA
Mid 25 25
Average 25.0 25.0
Central Valley Water Reclamation (CVWR)
Jenbacher #4
AST-2023-4301
Parameter
Response Times, seconds
54 of 87
Balance
Red Ball Technical Gas Service
555 Craig Kennedy Way
Shreveport, LA 71107
800-551-8150
Accreditation #62754 PGVP Vendor ID # G12023
EPA PROTOCOL GAS CERTIFICATE OF ANALYSIS
Cylinder Number:CC764364 Certification Date:09/21/2023
Product ID Number:127907 Expiration Date:09/19/2031
Cylinder Pressure:1900 PSIG MFG Facility: - Shreveport - LA
COA #CC764364.20230830-0 Lot Number:CC764364.20230830
Customer PO. NO.:Tracking Number:108811898
Customer:Previous Certification Dates:
This calibration standard has been certified per the May 2012 EPA Traceability Protocol, Document EPA-600/R-12/531,
using procedure G2.
Do Not Use This Cylinder Below 100 psig (0.7 Megapascal).
Certified Concentration(s)
Component Concentration Uncertainty Analytical Principle Assayed On
Carbon Dioxide 23.9 %±0.2 %FTIR 09/21/2023
Oxygen 23.98 %±0.04 %MPA 09/14/2023
Nitrogen
Analytical Measurement Data Available Online.
Reference Standard(s)
Serial Number Lot Expiration Type Balance Component Concentration Uncertainty(%)NIST Reference
CC737012 CC737012.20230228 07/09/2031 GMIS N2 O2 20 %0.112 SRM 2659a
EB0022021 EB0022021.20180323 07/15/2026 GMIS N2 CO2 14.9 %0.777 101001
Analytical Instrumentation SMART-CERT
Component Principle Make MPC Date
O2 MPA Thermo 09/13/2023
CO2 FTIR MKS 09/21/2023
Serial
1162980025
017146467
This is to certify the gases referenced have been calibrated/tested, and verified to meet the defined specifications. This
calibration/test was performed using Gases or Scales that are traceable through National Institute of Standards and
Technology (NIST) to the International System of Units (SI). The basis of compliance stated is a comparison of the
measurement parameters to the specified or required calibration/testing process. The expanded uncertainties use a coverage
factor of k=2 to approximate the 95% confidence level of the measurement, unless otherwise noted. This calibration certificate
applies only to the item described and shall not be reproduced other than in full, without written approval from Red Ball
Technical Gas Services. If not included, the uncertainty of calibrations are available upon request and were taken into account
when determining pass or fail.
Timothy Davis
Analytical Chemist
Assay Laboratory: Red Ball TGS
Version 02-J, Revised on 2018-09-17
Model
410i
MKS 2031DJG2EKVS13T
55 of 87
56 of 87
4.57 PPM ± 2% NIST FTIR
This is to certify the gases referenced have been calibrated/tested, and verified to meet the defined specifications. This
calibration/test was performed using Gases or Scales that are traceable through National Institute of Standards and
Technology (NIST) to the International System of Units (SI). The basis of compliance stated is a comparison of the
measurement parameters to the specified or required calibration/testing process. The expanded uncertainties use a
coverage factor of k=2 to approximate the 95% confidence level of the measurement, unless otherwise noted. This
calibration certificate applies only to the item described and shall not be reproduced other than in full, without written approval
from Red Ball Technical Gas Services. If not included, the uncertainty of calibrations are available upon request and were
taken into account when determining pass or fail.
Anthony Cyr
Assistant Operations Manager
Assay Laboratory: Red Ball TGS
Version 02-G, Revised on 2017-07-02
MKS MKS 2031DJG2EKVS13T 017146467
MPC Date
SF6 FTIR MKS MKS 2031DJG2EKVS13T 017146467
C2H4O FTIR
Analytical Instrumentation SMART-CERT
Component Principle Make Model Serial
2 4011772
9.97 PPM 5 4011772
CC742079 CC742079 07/27/2023 PS N2 C2H4O 98.1 PPM
CC518670 CC518670 07/27/2023 PS N2 SF6
Reference Standard(s)
Serial Number Lot Expiration Type Balance Component Concentration Uncertainty(%)NIST Reference
Nitrogen
Analytical Measurement Data Available Online.
Balance
Acetaldehyde
Sulfur Hexafluoride
Certified Concentration(s)
Component Concentration Uncertainty Analytical Principle
93.0 PPM ± 2% NIST FTIR
Customer:Previous Certification Dates:
Do Not Use This Cylinder Below 100 psig (0.7 Megapascal).
This mixture is for laboratory use only, not for drug, household or other use.
This mixture is certified in Mole % to be within ±2% of the actual number reported with a confidence of 95%.
This mixture was manufactured by scale; weights traceable to N.I.S.T. Certificate #822/266926-02.
COA #EB0038762.20230306-0 Lot Number:EB0038762.20230306
Customer PO. NO.:Tracking Number:065156566
Product ID Number:125303 Expiration Date:03/14/2025
Cylinder Pressure:1900 PSIG MFG Facility: - Shreveport - LA
CERTIFIED GAS CERTIFICATE OF ANALYSIS
Cylinder Number:EB0038762 Certification Date:03/15/2023
Red Ball Technical Gas Service
555 Craig Kennedy Way
Shreveport, LA 71107
800-551-8150
Accreditation #62754 PGVP Vendor ID # G12023
57 of 87
This is to certify the gases referenced have been calibrated/tested, and verified to meet the defined specifications. This
calibration/test was performed using Gases or Scales that are traceable through National Institute of Standards and
Technology (NIST) to the International System of Units (SI). The basis of compliance stated is a comparison of the
measurement parameters to the specified or required calibration/testing process. The expanded uncertainties use a
coverage factor of k=2 to approximate the 95% confidence level of the measurement, unless otherwise noted. This
calibration certificate applies only to the item described and shall not be reproduced other than in full, without written approval
from Red Ball Technical Gas Services. If not included, the uncertainty of calibrations are available upon request and were
taken into account when determining pass or fail.
Aaron Varelas
Analytical Chemist
Assay Laboratory: Red Ball TGS
Version 02-G, Revised on 2017-07-02
MPC Date
C2H4 FTIR MKS MKS 2031DJG2EKVS13T 017146467
Analytical Instrumentation SMART-CERT
Component Principle Make Model Serial
102 PPM 2 4034426CC722751CC72275107/28/2024 PS N2 C2H4
Reference Standard(s)
Serial Number Lot Expiration Type Balance Component Concentration Uncertainty(%)NIST Reference
Nitrogen
Analytical Measurement Data Available Online.
Balance
Ethylene
Certified Concentration(s)
Component Concentration Uncertainty Analytical Principle
101 PPM ± 2% NIST FTIR
Customer:Previous Certification Dates:
Do Not Use This Cylinder Below 100 psig (0.7 Megapascal).
This mixture is for laboratory use only, not for drug, household or other use.
This mixture is certified in Mole % to be within ±2% of the actual number reported with a confidence of 95%.
This mixture was manufactured by scale; weights traceable to N.I.S.T. Certificate #822/266926-02.
COA #EB0073902.20230730-0 Lot Number:EB0073902.20230730
Customer PO. NO.:Tracking Number:084266022
Product ID Number:124838 Expiration Date:08/06/2025
Cylinder Pressure:1900 PSIG MFG Facility: - Shreveport - LA
CERTIFIED GAS CERTIFICATE OF ANALYSIS
Cylinder Number:EB0073902 Certification Date:08/07/2023
Red Ball Technical Gas Service
555 Craig Kennedy Way
Shreveport, LA 71107
800-551-8150
Accreditation #62754 PGVP Vendor ID # G12023
58 of 87
Location
Source(s)
Project No.
Health Check Parameter Single Beam (Pre-Test)
Instrument ID MKS 7 (Serial #01451609)
Date
Central Valley Water Reclamation (CVWR)
Jenbacher #2 and #4
AST-2023-4301
12/14/2023
59 of 87
Location
Source(s)
Project No.
Health Check Parameter Single Beam (Post-Test)
Instrument ID MKS 7 (Serial #01451609)
Date
Central Valley Water Reclamation (CVWR)
Jenbacher #2 and #4
AST-2023-4301
12/15/2023
60 of 87
Location
Source(s)
Project No.
Health Check Parameter Detector Linearity
Instrument ID MKS 7 (Serial #01451609)
Date
Central Valley Water Reclamation (CVWR)
Jenbacher #2 and #4
AST-2023-4301
12/14/2023
61 of 87
Location
Source(s)
Project No.
Health Check Parameter Peak Analysis
Instrument ID MKS 7 (Serial #01451609)
Date
Central Valley Water Reclamation (CVWR)
Jenbacher #2 and #4
AST-2023-4301
12/14/2023
62 of 87
Location
Source(s)
Project No.
Health Check Parameter Signal to Noise Ratio
Instrument ID MKS 7 (Serial #01451609)
Date
Central Valley Water Reclamation (CVWR)
Jenbacher #2 and #4
AST-2023-4301
12/14/2023
63 of 87
Location
Source(s)
Project No.
Health Check Parameter Analysis Validation Utility
Instrument ID MKS 7 (Serial #01451609)
Date
Analysis Validation Report
Sample Filename: C:\2023\23-4301 CVWR\ENGINE 4_0465.LAB
Filename for noise: C:\2023\23-4301 CVWR\ENGINE 4_0035.LAB
Interferences Filenames: C:\OLT\Analysis Validation Utility\Support spectra\1min 191C LN2\Interferents H2O 10pct C
Recipe path: C:\OLT\Recipes\NG Engines R3.MGRCP
Gas calibration Name Conc MDC3 MDC2 MDC1 MAU FMU*R OCU ~ DL
ACETALDEHYDE 5-110 PPM 3.12 13.46 0.5 2.64 3.13 15.97 15.97 0.76
SF6 191C(2) -0.46 0.1 0.02 0.01 0.01 0.13 0.13 0.17
NO (350,3000) 191C 10.51 17.97 0.1 0.99 1.35 24.53 24.53 0.87
NO2 (150) 191C (1OF2) 35.05 3.21 0.06 0.16 0.17 3.38 3.38 0.15
NO2 (2000) 191C (2OF2) 16.75 58.61 0.64 4.36 5.56 74.67 74.67 0.79
CH4 (250) 191C (1OF2) 933.47 310.15 0.04 1.32 3.5 723.47 723.47 0.14
CH4 (3000) 191C (2OF2) 1473.99 158.87 0.49 2.76 4.55 234.49 234.49 1.28
N2O FULL CAL 191C -5.27 29.5 0.28 10.25 15.7 45.2 45.2 1.23
NH3 (300) 191C (1OF2) -0.15 4.44 0.04 0.27 0.46 7.51 7.51 0.18
NH3 (3000) 191C (2OF2) 1.63 23.42 0.82 2.99 5.63 44.18 44.18 1.33
H2O% (20) 191C 10.22 1.24 -0.03 0.05 2.47 2.47 -
CO2% (20) 191C 5.99 1.55 -0.04 0.05 2.16 2.16 -
CO (500) 191C (1OF2) 421.82 91.51 0.13 0.64 1.39 179.4 179.4 0.2
CO% (1) 191C (2OF2) 0.04 0.02 0 0 0 0.04 0.04 0
ETHANE (500) 191C 25.06 11.94 0.08 1.01 1.12 13.28 13.28 0.22
ETHYLENE (100,3000) 191C 15.01 6.09 0.09 0.37 0.65 10.6 10.6 0.57
ACETYLENE (1000) 191C 2.52 25.73 0.12 2.99 4.01 34.5 34.5 0.33
PROPANE (200) 191C 6.04 6.1 0.23 0.55 0.59 6.57 6.57 0.33
PROPYLENE (200,1000) 191C 0.05 14.15 0.3 0.97 1.14 16.59 16.59 0.51
BUTANE (200) 191C 0.17 5.25 0.28 0.48 0.57 6.2 6.2 0.29
FORMALDEHYDE (AST 4-41) 46.01 6.63 0.08 1.51 1.89 8.09 8.09 0.19
Central Valley Water Reclamation (CVWR)
Jenbacher #2 and #4
AST-2023-4301
12/14/2023
64 of 87
Location
Source(s)
Project No.
Spectra (CTS) ENGINE 4_0040.LAB
Date 12/14/2023
Time
Central Valley Water Reclamation (CVWR)
Jenbacher #2 and #4
AST-2023-4301
8:41:29 AM
65 of 87
Location
Source(s)
Project No.
Spectra (Native) ENGINE 4_0463.LAB
Date 12/14/2023
Time
1
Central Valley Water Reclamation (CVWR)
Jenbacher #2 and #4
AST-2023-4301
2:54:12 PM
66 of 87
Location
Source(s)
Project No.
Spectra (Spike) ENGINE 4_0474.LAB
Date 12/14/2023
Time
1
Central Valley Water Reclamation (CVWR)
Jenbacher #2 and #4
AST-2023-4301
3:05:12 PM
67 of 87
Location:
Source:
Project No.:
Date
EPA
O2
Servomex
1400
1420C-2
23.98
Cylinder Number ID
Zero NA
Mid EB0072318
High CC764364
Cylinder Certified Values
Zero 0.0
Mid 10.95
High 23.98
Instrument Response (% or ppm)
Zero 0.01
Mid 10.91
High 23.97
Calibration Gas Selection (% of Span)
Mid 45.7
High 100.0
Calibration Error Performance (% of Span)
Zero 0.0
Mid -0.2
High 0.0
Linearity (% of Range)
-0.2
(%) lpm (%) (%) (%) (%) (%) (%) (%)( ± 2 %)
10L/5L 80.0 5.0 19.2 19.20 19.26 19.32 19.29 19.29 0.09 0.5%
10L/5L 50.0 5.0 12.0 12.00 12.09 12.09 12.08 12.09 0.09 0.7%
10L/1L 20.0 4.0 4.8 4.80 4.82 4.74 4.75 4.77 -0.03 -0.6%
10L/1L 10.0 4.0 2.4 2.40 2.39 2.39 2.39 2.39 -0.01 -0.4%
(%)( ± 2 %)( ± 2 %)( ± 2 %)
19.29 -0.2% 0.2% 0.0%
12.09 0.0% 0.0% -0.1%
4.77 1.0% -0.6% -0.4%
2.39 0.0% 0.0% 0.0%
Mid-Level Supply Gas Calibration Direct to Analyzer
Calibration Injection 1 Injection 2 Injection 3 Average
Gas Analyzer Analyzer Analyzer Analyzer
Concentration Concentration Concentration Concentration Concentration
(%) (%) (%) (%) (%) (%)( ± 2 %)
10.95 10.99 11.00 11.00 11.00 0.05 0.4%
Analyzer Make: Servomex
Central Valley Water Reclamation (CVWR)
Jenbacher #4
AST-2023-4301
12/14/23
Parameter
Make
Model
S/N
Span
Method Criteria
Analyzer Model: 1400
Analyzer SN: 1420C-2
Environics ID: 8029
Component/Balance Gas: O2/N2
Cylinder Gas ID (Dilution): CC764364
Cylinder Gas Concentration (Dilution), %: 23.98
*Not all AST Environics Units have 2-10L Mass Flow Controllers. For these units the 90% @ 7lpm and 80% @ 7lpm injections will not be conducted.
Cylinder Gas ID (Mid-Level): EB0072318
Cylinder Gas Concentration (Mid-Level), %: 10.95
Target Mass Flow
Contollers
Target
Dilution
Target Flow
Rate
Target
Concentration
Actual
Concentration
Injection 1
Analyzer
Concentration
Injection 2
Analyzer
Concentration
Injection 3
Analyzer
Concentration
Average
Analyzer
Concentration Difference Average Error
Average
Analyzer
Concentration
Injection 1
Error
Injection 2
Error
Injection 3
Error
Difference
Average
Error
68 of 87
Dilution System Make:
Dilution System Model:
Dilution System S/N:
Calibration Equipment Make:
Calibration Equipment Model:
Calibration Equipment S/N:
Flow Cell S/N:
Flow Cell S/N:
Calibration Gas:
Barometric Pressure, mmHg:
Ambient Temperature, °F:
Mass Flow Controller ID
Size, ccm:
Make:
Model:
S/N:
Set Flow True Flow Difference Set Flow True Flow Difference Set Flow True Flow Difference
cc/min cc/min cc/min cc/min cc/min cc/min
5%500 502 0.4%500 495 1.0%50 47 5.8%
10%1,000 1,015 1.5%1,000 1,014 1.4%100 98 2.4%
20%2,000 2,040 2.0%2,000 2,037 1.9%200 199 0.3%
30%3,000 3,060 2.0%3,000 3,057 1.9%300 301 0.4%
40%4,000 4,083 2.1%4,000 4,071 1.8%400 403 0.6%
50%5,000 5,093 1.9%5,000 5,082 1.6%500 504 0.7%
60%6,000 6,110 1.8%6,000 6,100 1.7%600 606 0.9%
70%7,000 7,124 1.8%7,000 7,130 1.9%700 709 1.2%
80%8,000 8,150 1.9%8,000 8,150 1.9%800 814 1.7%
90%9,000 9,172 1.9%9,000 9,176 2.0%900 919 2.2%
100%10,000 10,214 2.1%10,000 10,202 2.0%1,000 1,028 2.8%
Date
4040 4040
72
Environics
8029
#1
10,000
Environics
4040
Alicat Scientific
197206; 197208
197208
197206
Nitrogen
25.6
Calibration Performed By Ryan Lyons
4/26/23
455242003
Mass Flow Controller Calibration
Note: The mass flow controller's calibration values are used by the dilution system's operating software to improve accuracy. These calibrations are not
necessarily indicative of the systems overall performance. Performance is verified by conducting a Method 205 prior to each field use.
M-10SLPD/5MM-D/5M, M-1SLPM-D/5M
4040
10,000
# 2 # 3
Environics
455242004
1,000
Environics
455242002
69 of 87

Appendix D

70 of 87
Location Central Valley Water Reclamation (CVWR)
Source Jenbacher #2
Project No.AST-2023-4301
Run Number Run 1 Run 2 Run 3
Date 12/15/23 12/15/23 12/15/23
Start Time 9:24 10:39 12:33
Stop Time 10:24 11:39 13:33
Engine Exhaust Temperature, °F
Time, 0 min 984 982 984
Time, 15 min 982 984 984
Time, 30 min 982 984 981
Time, 45 min 984 986 981
Time, 60 min 982 984 984
Average 983 984 983
Generator Output, Hz (Gen OP)
Time, 0 min 60 60 60
Time, 15 min 60 60 60
Time, 30 min 60 60 60
Time, 45 min 60 60 60
Time, 60 min 60 60 60
Average 60 60 60
Engine Speed, RPM (ES)
Time, 0 min 1,500 1,500 1,500
Time, 15 min 1,500 1,500 1,500
Time, 30 min 1,500 1,500 1,500
Time, 45 min 1,500 1,500 1,500
Time, 60 min 1,500 1,500 1,500
Average 1,500 1,500 1,500
Engine Brake Work, HP (EBW)
Time, 0 min 2,415 2,415 2,415
Time, 15 min 2,415 2,415 2,415
Time, 30 min 2,415 2,415 2,415
Time, 45 min 2,415 2,415 2,415
Time, 60 min 2,415 2,415 2,415
Average 2,415 2,415 2,415
Fuel Rate, scfh (FR)
Time, 0 min 175 176 177
Time, 15 min 175 176 177
Time, 30 min 176 177 178
Time, 45 min 175 175 177
Time, 60 min 174 176 177
Average 175 176 177
Operational Data
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Location Central Valley Water Reclamation (CVWR)
Source Jenbacher #4
Project No.AST-2023-4301
Run Number Run 1 Run 2 Run 3
Date 12/14/23 12/14/23 12/14/23
Start Time 11:03 12:25 14:00
Stop Time 12:03 13:25 15:00
Engine Exhaust Temperature, °F
Time, 0 min 979 979 963
Time, 15 min 981 982 964
Time, 30 min 981 988 966
Time, 45 min 984 964 964
Time, 60 min 977 961 966
Average 980 975 965
Generator Output, Hz (Gen OP)
Time, 0 min 60 60 60
Time, 15 min 60 60 60
Time, 30 min 60 60 60
Time, 45 min 60 60 60
Time, 60 min 60 60 60
Average 60 60 60
Engine Speed, RPM (ES)
Time, 0 min 1,500 1,500 1,500
Time, 15 min 1,500 1,500 1,500
Time, 30 min 1,500 1,500 1,500
Time, 45 min 1,500 1,500 1,500
Time, 60 min 1,500 1,500 1,500
Average 1,500 1,500 1,500
Engine Brake Work, HP (EBW)
Time, 0 min 2,412 2,414 2,415
Time, 15 min 2,414 2,414 2,415
Time, 30 min 2,414 2,414 2,414
Time, 45 min 2,415 2,414 2,415
Time, 60 min 2,415 2,425 2,415
Average 2,414 2,416 2,415
Fuel Rate, scfh (FR)
Time, 0 min 177 177 185
Time, 15 min 175 177 187
Time, 30 min 176 175 184
Time, 45 min 177 181 185
Time, 60 min 177 180 186
Average 176 178 185
Operational Data
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Appendix E

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Site Specific Test Plan

Central Valley Water Reclamation Facility
800 W Central Valley Road
Salt Lake City, UT 84119-3379

Sources to be Tested: Jenbacher Engine #2 & Jenbacher
Engine #4
Proposed Test Date: December 14-15, 2023

Project No. AST-2023-4301

Prepared By
Alliance Technical Group, LLC
3683 W 2270 S, Suite E
West Valley City, UT 84120

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Test Program Summary

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Regulatory Information

Permit Nos. Title V 3500191001 and DAQE-AN104140015-21
Regulatory Citation 40 CFR 60, Subpart JJJJ

Source Information

Source Name Source ID Target Parameters
GE Jenbacher Model JMS 612-
F28F02 Generator Engine Jenbacher #2 NOx, CO, VOC, NMHC
GE Jenbacher Model JMS 612-
F28F02 Generator Engine Jenbacher #4 NOx, CO, VOC, NMHC

Contact Information

Test Location Test Company
Central Valley Water Reclamation Facility
Wastewater Treatment Plant
800 W Central Valley Road
Salt Lake City, UT 84119-3379

Facility Contact
Bryan Mansell
[e-mail]
[phone]

Alliance Technical Group, LLC
5757 Genoa Red Bluff Road
Pasadena, TX 77507

Project Manager
Charles Horton
[e-mail]
[phone]

Field Team Leader
Alen Jensen
[e-mail]
[phone]
(subject to change)

QA/QC Manager
Kathleen Shonk
[e-mail]
[phone]

Test Plan/Report Coordinator
Betzaida Aponte Hernández
[e-mail]
[phone]

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Site Specific Test Plan
Table of Contents
AST-2023-4301 Central Valley – Salt Lake City, UT Page ii
TABLE OF CONTENTS
1.0 Introduction .................................................................................................................................................. 1-1
1.1 Process/Control System Descriptions ...................................................................................................... 1-1
1.2 Project Team ............................................................................................................................................ 1-1
1.3 Safety Requirements ................................................................................................................................ 1-1
2.0 Summary of Test Program ............................................................................................................................ 2-1
2.1 General Description ................................................................................................................................. 2-1
2.2 Process/Control System Parameters to be Monitored and Recorded ....................................................... 2-1
2.3 Proposed Test Schedule ........................................................................................................................... 2-1
2.4 Emission Limits ....................................................................................................................................... 2-2
2.5 Test Report ............................................................................................................................................... 2-3
3.0 Testing Methodology .................................................................................................................................... 3-1
3.1 U.S. EPA Reference Test Methods 1 and 2 – Sampling/Traverse Points and Volumetric Flow Rate ..... 3-1
3.2 U.S. EPA Reference Test Method 3A – Oxygen/Carbon Dioxide ........................................................... 3-1
3.3 U.S. EPA Reference Test Method 320 – BWS, NOx, CO, VOC, and NMHC ........................................ 3-2
3.4 U.S. EPA Reference Test Method 205 – Gas Dilution System Certification ........................................... 3-2
3.5 Quality Assurance/Quality Control – U.S. EPA Reference Test Method 3A .......................................... 3-2
3.6 Quality Assurance/Quality Control – U.S. EPA Reference Method 320 ................................................. 3-3
4.0 Quality Assurance Program .......................................................................................................................... 4-1
4.1 Equipment ................................................................................................................................................ 4-1
4.2 Field Sampling ......................................................................................................................................... 4-2
LIST OF TABLES
Table 1-1: Project Team ........................................................................................................................................... 1-1
Table 2-1: Program Outline and Tentative Test Schedule ........................................................................................ 2-2
Table 2-2: Emission Limits ...................................................................................................................................... 2-2
Table 3-1: Source Testing Methodology .................................................................................................................. 3-1
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Introduction
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1.0 Introduction
Alliance Technical Group, LLC (Alliance) was retained by Central Valley Wastewater Reclamation Facility
(Central Valley) to conduct compliance testing at the Wastewater Treatment Plant in Salt Lake City, Utah. Portions
of the facility are subject to provisions of the 40 CFR 60, Subpart JJJJ and the Utah Department of Environmental
Quality, Division of Air Quality (UDAQ) Title V Permit No. 3500191001 and Approval Order (AO) DAQE-
AN104140015-21. Testing will be conducted to determine the emission rates of nitrogen oxides (NOx), carbon
monoxide (CO), volatile organic compounds (VOC), and non-methane hydrocarbons (NMHC) from the exhausts of
two (2) GE Jenbacher Model JSM 612-F28F02 engines designated as Jenbacher #2 and Jenbacher #4. The VOC
emissions will not include formaldehyde.
This site-specific test plan (SSTP) has been prepared to address the notification and testing requirements of the
UDAQ permit and the NSPS.
1.1 Process/Control System Descriptions
Central Valley operates two (2) GE Jenbacher Model JMS 612-F28F02 generator engines. Each engine rates at
2,509 horsepower (hp). The engines can be fired on natural gas or digester gas. Testing for Jenbacher #2 and
Jenbacher #4 will be conducted while the engines are fired on a mixed gas of blended digester gas and natural gas.
1.2 Project Team
Personnel planned to be involved in this project are identified in the following table.
Table 1-1: Project Team
Central Valley Personnel Bryan Mansell
Regulatory Agency UDAQ
Alliance Personnel Alen Jensen
other field personnel assigned at time of testing event
1.3 Safety Requirements
Testing personnel will undergo site-specific safety training for all applicable areas upon arrival at the site. Alliance
personnel will have current OSHA or MSHA safety training and be equipped with hard hats, safety glasses with side
shields, steel-toed safety shoes, hearing protection, fire resistant clothing, and fall protection (including shock
corded lanyards and full-body harnesses). Alliance personnel will conduct themselves in a manner consistent with
Client and Alliance’s safety policies.
A Job Safety Analysis (JSA) will be completed daily by the Alliance Field Team Leader.
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2.0 Summary of Test Program
To satisfy the requirements of the UDAQ permit and the NSPS, the facility will conduct a performance test program
to determine the compliance status of two (2) GE Jenbacher Model JSM 612-F28F02 engines designated as
Jenbacher #2 and Jenbacher #4.
2.1 General Description
All testing will be performed in accordance with specifications stipulated in U.S. EPA Reference Test Methods 1, 2,
3A and 320. Table 2-1 presents an outline and tentative schedule for the emissions testing program. The following
is a summary of the test objectives.

 Testing will be performed to demonstrate compliance with the UDAQ permit and 40 CFR 60, Subpart JJJJ.
 Emissions testing will be conducted on the exhaust of Jenbacher #2 and Jenbacher #4.
 Performance testing for Jenbacher #2 and Jenbacher #4 will be conducted while the engines are fired on
mixed digester gas and natural gas.
 Performance testing for Jenbacher #2 and Jenbacher #4 will be conducted at no less than 90% of the
production rate achieved to date.
 Each of the three (3) test runs will be 60 minutes in duration.
 The VOC measurements will not include formaldehyde.
 Concurrent oxygen (O2), carbon dioxide (CO2) and moisture content (BWS) will be collected during each
test run and combined with facility data to calculate emission rates in grams per break horsepower hour
(g/bhp-hr).
2.2 Process/Control System Parameters to be Monitored and Recorded
Plant personnel will collect operational and parametric data at least once every 15 minutes during the testing. The
following list identifies the measurements, observations and records that will be collected during the testing
program:

 Ambient Temperature (°F)
 Barometric Pressure (“HgA)
 Relative Humidity (%)
 Compressor Process Conditions
 Engine Operating Load
 Fuel Consumption
2.3 Proposed Test Schedule
Table 2-1 presents an outline and tentative schedule for the emissions testing program.

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Table 2-1: Program Outline and Tentative Test Schedule

Testing Location Parameter US EPA Method No. of Runs Run Duration Est. Onsite
Time
DAY 1 – December 13, 2023
Equipment Setup & Pretest QA/QC Checks 6 hr
DAY 2 – December 14, 2023
Jenbacher #2
VFR 1-2
3 60 min 10 hr
O2 / CO2 3A
BWS
320
NOx
CO
VOC 1
NMHC
DAY 3 – December 15, 2023
Jenbacher #4
VFR 1-2
3 60 min 10 hr
O2 / CO2 3A
BWS
320
NOx
CO
VOC 1
NMHC
1 VOC measurements will not include formaldehyde.
2.4 Emission Limits
Emission limits for each pollutant are below.

Table 2-2: Emission Limits

Source Pollutant Citation
Jenbacher #2
Jenbacher #4
NOx – 0.55 g/bhp-hr
Permit CO – 2.5 g/bhp-hr
VOC – 1.0 g/bhp-hr
NMHC – 0.3 g/bhp-hr

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2.5 Test Report
The final test report must be submitted within 60 days of the completion of the performance test and will include the
following information.
 Introduction – Brief discussion of project scope of work and activities.
 Results and Discussion – A summary of test results and process/control system operational data with
comparison to regulatory requirements or vendor guarantees along with a description of process conditions
and/or testing deviations that may have affected the testing results.
 Methodology – A description of the sampling and analytical methodologies.
 Sample Calculations – Example calculations for each target parameter.
 Field Data – Copies of actual handwritten or electronic field data sheets.
 Quality Control Data – Copies of all instrument calibration data and/or calibration gas certificates.
 Process Operating/Control System Data – Process operating and control system data (as provided by
Central Valley) to support the test results.

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3.0 Testing Methodology
This section provides a description of the sampling and analytical procedures for each test method that will be
employed during the test program. All equipment, procedures and quality assurance measures necessary for the
completion of the test program meet or exceed the specifications of each relevant test method. The emission testing
program will be conducted in accordance with the test methods listed in Table 3-1.

Table 3-1: Source Testing Methodology

Parameter U.S. EPA Reference
Test Methods Notes/Remarks
Volumetric Flow Rate 1 & 2 Full Velocity Traverses
Oxygen / Carbon Dioxide 3A Instrumental Analysis
Moisture Content / Nitrogen Oxides / Carbon
Monoxide / Volatile Organic Compounds /
Non-Methane Hydrocarbons
320 FTIR – Continuous Sampling
Gas Dilution System Certification 205 --

All stack diameters, depths, widths, upstream and downstream disturbance distances and nipple lengths will be
measured on site with a verification measurement provided by the Field Team Leader.

3.1 U.S. EPA Reference Test Methods 1 and 2 – Sampling/Traverse Points and Volumetric Flow Rate
The sampling location and number of traverse (sampling) points will be selected in accordance with U.S. EPA
Reference Test Method 1. To determine the minimum number of traverse points, the upstream and downstream
distances will be equated into equivalent diameters and compared to Figure 1-2 in U.S. EPA Reference Test Method
1.

Full velocity traverses will be conducted in accordance with U.S. EPA Reference Test Method 2 to determine the
average stack gas velocity pressure, static pressure and temperature. The velocity and static pressure measurement
system will consist of a pitot tube and inclined manometer. The stack gas temperature will be measured with a K-
type thermocouple and pyrometer.

Stack gas velocity pressure and temperature readings will be recorded during each test run. The data collected will
be utilized to calculate the volumetric flow rate in accordance with U.S. EPA Reference Test Method 2.
3.2 U.S. EPA Reference Test Method 3A – Oxygen/Carbon Dioxide
The oxygen (O2) and carbon dioxide (CO2) testing will be conducted in accordance with U.S. EPA Reference Test
Method 3A. Data will be collected online and reported in one-minute averages. The sampling system will consist
of a stainless-steel probe, Teflon sample line(s), gas conditioning system and the identified gas analyzer. The gas
conditioning system will be a non-contact condenser used to remove moisture from the stack gas. If an unheated
Teflon sample line is used, then a portable non-contact condenser will be placed in the system directly after the
probe. Otherwise, a heated Teflon sample line will be used. The quality control measures are described in Section
3.5.
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3.3 U.S. EPA Reference Test Method 320 – BWS, NOx, CO, VOC, and NMHC
The concentrations of moisture content (BWS), nitrogen oxides (NOx), carbon monoxide (CO), volatile organic
compounds (VOC) and non-methane hydrocarbons (NMHC) will be determined in accordance with U.S. EPA
Reference Test Method 320. Each source gas stream will be extracted at a constant rate through a heated probe,
heated filter and heated sample line and analyzed with a MKS MultiGas 2030 FTIR operated by a portable
computer. The computer has FTIR spectra of calibration gases stored on the hard drive. These single component
calibration spectra are used to analyze the measured sample spectra. The gas components to be measured will be
selected from the spectra library and incorporated into the analytical method. The signal amplitude, linearity, and
signal to noise ratio will be measured and recorded to document analyzer performance. A leak check will be
performed on the sample cell. The instrument path length will be verified using ethylene as the Calibration Transfer
Standard. Dynamic spiking will be performed using a certified standard of the target compound or appropriate
surrogate in nitrogen with sulfur hexafluoride blended as a tracer to calculate the dilution factor. All test spectra,
interferograms, and analytical method information are recorded and stored with the calculated analytical results. The
quality control measures are described in Section 3.6.
3.4 U.S. EPA Reference Test Method 205 – Gas Dilution System Certification
A calibration gas dilution system field check will be conducted in accordance with U.S. EPA Reference Method
205. Multiple dilution rates and total gas flow rates will be utilized to force the dilution system to perform two
dilutions on each mass flow controller. The diluted calibration gases will be sent directly to the analyzer, and the
analyzer response recorded in an electronic field data sheet. The analyzer response must agree within 2% of the
actual diluted gas concentration. A second Protocol 1 calibration gas, with a cylinder concentration within 10% of
one of the gas divider settings described above, will be introduced directly to the analyzer, and the analyzer response
recorded in an electronic field data sheet. The cylinder concentration and the analyzer response must agree within
2%. These steps will be repeated three (3) times.
3.5 Quality Assurance/Quality Control – U.S. EPA Reference Test Method 3A
Cylinder calibration gases will meet EPA Protocol 1 (+/- 2%) standards. Copies of all calibration gas certificates
will be included in the Quality Assurance/Quality Control Appendix of the report.

Low Level gas will be introduced directly to the analyzer. After adjusting the analyzer to the Low Level gas
concentration and once the analyzer reading is stable, the analyzer value will be recorded. This process will be
repeated for the High Level gas. For the Calibration Error Test, Low, Mid, and High Level calibration gases will be
sequentially introduced directly to the analyzer. The Calibration Error for each gas must be within 2.0 percent of the
Calibration Span or 0.5% absolute difference.

High or Mid Level gas (whichever is closer to the stack gas concentration) will be introduced at the probe and the
time required for the analyzer reading to reach 95 percent or 0.5% (whichever was less restrictive) of the gas
concentration will be recorded. The analyzer reading will be observed until it reaches a stable value, and this value
will be recorded. Next, Low Level gas will be introduced at the probe and the time required for the analyzer reading
to decrease to a value within 5.0 percent or 0.5% (whichever was less restrictive) will be recorded. If the Low Level
gas is zero gas, the acceptable response must be 5.0 percent of the upscale gas concentration or 0.5% (whichever
was less restrictive). The analyzer reading will be observed until it reaches a stable value and this value will be
recorded. The measurement system response time and initial system bias will be determined from these data. The
System Bias for each gas must be within 5.0 percent of the Calibration Span or 0.5% absolute difference.

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High or Mid Level gas (whichever is closer to the stack gas concentration) will be introduced at the probe. After the
analyzer response is stable, the value will be recorded. Next, Low Level gas will be introduced at the probe, and the
analyzer value will be recorded once it reaches a stable response. The System Bias for each gas must be within 5.0
percent of the Calibration Span or 0.5% absolute difference or the data is invalidated and the Calibration Error Test
and System Bias must be repeated.

The Drift between pre- and post-run System Bias must be within 3 percent of the Calibration Span or 0.5% absolute
difference or the Calibration Error Test and System Bias must be repeated.

To determine the number of sampling points, a gas stratification check will be conducted prior to initiating testing.
The pollutant concentrations will be measured at twelve traverse points (as described in Method 1) or three points
(16.7, 50.0 and 83.3 percent of the measurement line). Each traverse point will be sampled for a minimum of twice
the system response time.

If the pollutant concentration at each traverse point do not differ more than 5% or 0.5 0.3% (whichever is less
restrictive) of the average pollutant concentration, then single point sampling will be conducted during the test runs.
If the pollutant concentration does not meet these specifications but differs less than 10% or 0.5% from the average
concentration, then three (3) point sampling will be conducted (stacks less than 7.8 feet in diameter - 16.7, 50.0 and
83.3 percent of the measurement line; stacks greater than 7.8 feet in diameter – 0.4, 1.0, and 2.0 meters from the
stack wall). If the pollutant concentration differs by more than 10% or 0.5% from the average concentration, then
sampling will be conducted at a minimum of twelve (12) traverse points. Copies of stratification check data will be
included in the Quality Assurance/Quality Control Appendix of the report.

A Data Acquisition System with battery backup will be used to record the instrument response in one (1) minute
averages. The data will be continuously stored as a *.CSV file in Excel format on the hard drive of a computer. At
the completion of testing, the data will also be saved to the AST server. All data will be reviewed by the Field Team
Leader before leaving the facility. Once arriving at AST’s office, all written and electronic data will be relinquished
to the report coordinator and then a final review will be performed by the Project Manager.
3.6 Quality Assurance/Quality Control – U.S. EPA Reference Method 320
EPA Protocol 1 Calibration Gases – Cylinder calibration gases used will meet EPA Protocol 1 (+/- 2%) standards or
will be certified standards.

After providing ample time for the FTIR to reach the desired temperature and to stabilize, zero gas (nitrogen) will be
introduced directly to the instrument sample port. While flowing nitrogen the signal amplitude will be recorded, a
background spectra will be taken, a linearity check will be performed and recorded, the peak to peak noise and the
root mean square in the spectral region of interest will be measured and a screenshot will be recorded.

Following the zero gas checks, room air will be pulled through the sample chamber and the line width and resolution
will be verified to be at 1879 cm-1, the peak position will be entered and the FWHH will be recorded (screenshot).
Following these checks, another background spectra will be recorded and the calibration transfer standard (CTS)
will be introduced directly to the instrument sample port. The CTS instrument recovery will be recorded and the
instrument mechanical response time will be measured.

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Next, stack gas will be introduced to the FTIR through the sampling system and several scans will be taken until a
stable reading will be achieved. The native concentration of our surrogate or target spiking analyte will be recorded.
Spike gas will be introduced to the sampling system at a constant flow rate ≤ 10% of the total sample flow rate and a
corresponding dilution ratio will be calculated along with a system response time. Matrix spike recovery spectra
will be recorded and will be within the ± 30% of the calculated value of the spike concentration that the method
requires.

The matrix spike recovery will be conducted once at the beginning of the testing and the CTS recovery procedures
will be repeated following each test run. The corresponding values will be recorded.

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4.0 Quality Assurance Program
Alliance follows the procedures outlined in the Quality Assurance/Quality Control Management Plan to ensure the
continuous production of useful and valid data throughout the course of this test program. The QC checks and
procedures described in this section represent an integral part of the overall sampling and analytical scheme.
Adherence to prescribed procedures is quite often the most applicable QC check.
4.1 Equipment
Field test equipment is assigned a unique, permanent identification number. Prior to mobilizing for the test
program, equipment is inspected before being packed to detect equipment problems prior to arriving on site. This
minimizes lost time on the job site due to equipment failure. Occasional equipment failure in the field is
unavoidable despite the most rigorous inspection and maintenance procedures. Therefore, replacements for critical
equipment or components are brought to the job site. Equipment returning from the field is inspected before it is
returned to storage. During the course of these inspections, items are cleaned, repaired, reconditioned and
recalibrated where necessary.

Calibrations are conducted in a manner, and at a frequency, which meets or exceeds U.S. EPA specifications. The
calibration procedures outlined in the U.S. EPA Methods, and those recommended within the Quality Assurance
Handbook for Air Pollution Measurement Systems: Volume III (EPA-600/R-94/038c, September 1994) are utilized.
When these methods are inapplicable, methods such as those prescribed by the American Society for Testing and
Materials (ASTM) or other nationally recognized agency may be used. Data obtained during calibrations is checked
for completeness and accuracy. Copies of calibration forms are included in the report.

The following sections elaborate on the calibration procedures followed by Alliance for these items of equipment.

 Pitot Tubes and Manometers. Type-S pitot tubes that meet the geometric criteria required by U.S. EPA
Reference Test Method 2 are assigned a coefficient of 0.84 unless a specific coefficient has been
determined from a wind tunnel calibration. If a specific coefficient from a wind tunnel calibration has been
obtained that coefficient will be used in lieu of 0.84. Standard pitot tubes that meet the geometric criteria
required by U.S. EPA Reference Test Method 2 are assigned a coefficient of 0.99. Any pitot tubes not
meeting the appropriate geometric criteria are discarded and replaced. Manometers are verified to be level
and zeroed prior to each test run and do not require further calibration.
 Temperature Measuring Devices. All thermocouple sensors mounted in Dry Gas Meter Consoles are
calibrated semi-annually with a NIST-traceable thermocouple calibrator (temperature simulator) and
verified during field use using a second NIST-traceable meter. NIST-traceable thermocouple calibrators
are calibrated annually by an outside laboratory.
 Digital Calipers. Calipers are calibrated annually by Alliance by using gage blocks that are calibrated
annually by an outside laboratory.
 Barometer. The barometric pressure is obtained from a nationally recognized agency or a calibrated
barometer. Calibrated barometers are checked prior to each field trip against a mercury barometer. The
barometer is acceptable if the values agree within ± 2 percent absolute. Barometers not meeting this
requirement are adjusted or taken out of service.
 Other Equipment. A mass flow controller calibration is conducted on each Environics system annually
following the procedures in the Manufacturer’s Operation manual. A methane/ethane penetration factor
check is conducted on the total hydrocarbon analyzers equipped with non-methane cutters every six (6)
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months following the procedures in 40 CFR 60, Subpart JJJJ. Other equipment such as probes, umbilical
lines, cold boxes, etc. are routinely maintained and inspected to ensure that they are in good working order.
They are repaired or replaced as needed.
4.2 Field Sampling
Field sampling will be done in accordance with the Standard Operating Procedures (SOP) for the applicable test
method(s). General QC measures for the test program include:
 The sampling port will be sealed to prevent air from leaking from the port.
 All raw data will be maintained in organized manner.
 All raw data will be reviewed on a daily basis for completeness and acceptability.
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Last Page of Report

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Appendix H

Applicable Regulations
Applicable Requirements
SIP
CVWRF is located in Salt Lake County, Utah which is currently designated non-attainment for
PM2.5, SO2 and ozone; the area is also designated as a PM10 maintenance area. Specific non-
attainment status (marginal, moderate, serious, etc.) is designated by the degree to which an area
does not meet the national primary or secondary ambient air quality standard for a National
Ambient Air Quality Standard (NAAQS) pollutant. Salt Lake County was designated as marginal non-
attainment for ozone on June 4, 2018. Since the area was not able to attain the ozone standard
within the three-year period allowed by United States Environmental Protection Agency (USEPA),
the area was re-designated as moderate non-attainment for ozone on November 7, 2022. Ozone is
not emitted directly into the air, but is formed through the photochemical reaction of nitrogen ox-
ides (NOx) and volatile organic compounds (VOCs). NOx and VOCs are known as ozone precursor
gases, which are, for the most part, emitted directly into the atmosphere.
The Northern Wasatch Front Ozone Nonattainment Area (NAA) was required to attain the ozone
standard by August 3, 2024; however recent monitoring data indicates the Northern Wasatch Front
NAA did not attain the standard and will be reclassified to serious non-attainment of ozone in
February of 2025. The serious non-attainment classification will trigger requirements for major
stationary sources and new thresholds for major stationary sources (50 tons per year or more of
NOx or VOCs). The facility is estimated to have a potential to emit exceeding 50 tons per year of
NOx, which will trigger the new major source threshold under the Northern Wasatch Front NAA
reclassification. The Ozone Implementation Rule in 83 FR 62998 requires the State Implementation
Plan (SIP) to include RACT for all major stationary sources in nonattainment areas classified as
moderate or higher. A copy of the most recent RACT Analysis performed in November 2023 per the
request of Utah Division of Air Quality (DAQ) is attached.

Approval Orders
The only currently applicable Approval Order for CVWRF is AN104140015-21 (included herewith)
dated July 2, 2021, which is incorporated by reference into the current Title V permit. CVWRF is
awaiting a new Approval Order that includes the three new Blower Building Area
Standby/Emergency Diesel Generators for which an NOI was submitted in May 2023. Additional
information was also provided per request to Utah DAQ in July 2023.
Technical Memorandum

Limitations:
This document was prepared solely for Central Valley Water Reclamation Facility (CVWRF) in accordance with professional standards at the time the
services were performed. This document is not intended to be relied upon by any other party except for regulatory authorities contemplated by the
scope of work. We have relied on information or instructions provided by CVWRF and other parties and, unless otherwise expressly indicated, have
made no independent investigation as to the validity, completeness, or accuracy of such information.

451 A Street, Suite 1500
San Diego, CA 92101

T: 858.514.8822

Prepared for: Central Valley Water Reclamation Facility (CVWRF)
Project Title: RACT Analysis for the Control of NOx
Project No.: 159388
Technical Memorandum
Subject: RACT Analysis for Emission Units at CVWRF
Date: November 21, 2023
To: Bryan Mansell, Chief Engineer
From: Jason Wiser
Copy to: File

Prepared by:
Katie Dorety, Senior Associate Engineer

Reviewed by:
Jennifer Border, Principal Engineer

iii
1_RACT Analysis
Table of Contents
List of Tables ............................................................................................................................................... iv
Section 1: Background ................................................................................................................................ 4
1.1 Site History and Permitting Timeline .................................................................................................... 4
1.2 Attainment Status .................................................................................................................................. 4
1.3 Description of Emissions Units ............................................................................................................. 4
Section 2: RACT Analysis ............................................................................................................................. 6
2.1 JMS Digester Gas/Natural Gas Cogeneration Engines ....................................................................... 6
2.1.1 Reasonably Available Control Technologies ........................................................................ 6
2.1.2 Eliminate Technically Infeasible Control Technologies ....................................................... 7
2.1.3 Rank Remaining Control Technologies Based on Capture and Control Efficiencies ........ 7
2.1.4 Evaluate Remaining Control Technologies on Economic, Energy, and Environmental
Feasibility ............................................................................................................................... 7
2.1.5 Select RACT ........................................................................................................................ 10
2.2 Diesel Fired Emergency Generators .................................................................................................. 10
2.2.1 Reasonably Available Control Technologies ..................................................................... 10
2.2.2 Eliminate Technically Infeasible Control Technologies .................................................... 11
2.2.3 Rank Remaining Control Technologies Based on Capture and Control Efficiencies ..... 11
2.2.4 Evaluate Remaining Control Technologies on Economic, Energy, and Environmental
Feasibility ............................................................................................................................ 11
2.2.5 Select RACT ........................................................................................................................ 11
2.3 Waste Oil Heaters ............................................................................................................................... 11
2.3.1 Reasonably Available Control Technologies ..................................................................... 11
2.3.2 Eliminate Technically Infeasible Control Technologies .................................................... 11
2.3.3 Rank Remaining Control Technologies Based on Capture and Control Efficiencies ..... 11
2.3.4 Evaluate Remaining Control Technologies on Economic, Energy, and Environmental
Feasibility ............................................................................................................................ 12
2.3.5 Select RACT ........................................................................................................................ 12
2.4 Digester Gas Flares ............................................................................................................................ 12
2.4.1 Reasonably Available Control Technologies ..................................................................... 12
2.4.2 Eliminate Technically Infeasible Control Technologies .................................................... 12
2.4.3 Rank Remaining Control Technologies Based on Capture and Control Efficiencies ..... 12
2.4.4 Evaluate Remaining Control Technologies on Economic, Energy, and Environmental
Feasibility ............................................................................................................................ 12
2.4.5 Select RACT ........................................................................................................................ 12
2.5 Boilers ................................................................................................................................................. 13
2.5.1 Reasonably Available Control Technologies ..................................................................... 13
2.5.2 Eliminate Technically Infeasible Control Technologies .................................................... 13
2.5.3 Rank Remaining Control Technologies Based on Capture and Control Efficiencies ..... 13
Table of Contents

iv
1_RACT Analysis
2.5.4 Evaluate Remaining Control Technologies on Economic, Energy, and Environmental
Feasibility ............................................................................................................................ 13
2.5.5 Select RACT ........................................................................................................................ 14
Section 3: Conclusion ............................................................................................................................... 15
Attachment A: 2021 BACT - Cogen Engines ............................................................................................... A
Attachment B: 2023 BACT - Emergency Engines .........................................................................................
Attachment C: Flare Replacement Cost Estimate ........................................................................................
Attachment D: Boiler Retrofit Emissions Reduction ....................................................................................
Attachment E: Cost Escalation ......................................................................................................................

List of Tables
Table 1. Emission Sources .......................................................................................................................... 5
Table 2. Revised Estimated Costs for Engine Controls ............................................................................. 8
Table 3. Estimated Ongoing Cost of SCR Control ...................................................................................... 9
Table 4. RBLC BACT Methods of Control ................................................................................................. 11

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1_RACT Analysis
List of Abbreviations
BACT Best Available Control Technology
Btu British thermal unit
CH4 methane
CO carbon monoxide
CO2 carbon dioxide
Cogen Cogeneration
CVWRF Central Valley Water Reclamation Facility
DAQ Division of Air Quality
g/hp-hr grams per horsepower-hour
ICE internal combustion engine
LAER Lowest Achievable Emission Rate
MMBtu/hr million Btu per hour
NAA Nonattainment Area
NAAQS National Ambient Air Quality Standard
NOx nitrogen oxide
PM10 particulate matter 10 micrometers
PM2.5 particulate matter 2.5 micrometers
ppm parts per million
RACT Reasonably Available Control Technology
RBLC RACT/BACT/LAER Clearinghouse
SCAQMD South Coast Air Quality Management District
SCR selective catalytic reduction
SIP State Implementation Plan
SO2 Sulfur dioxide
USEPA United States Environmental Protection Agency
VOC volatile organic compound

Reasonably Available Control Technology Analysis for NOx

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1_RACT Analysis
Section 1: Background
The Central Valley Water Reclamation Facility (CVWRF) is located at 800 West Central Valley Road in Salt
Lake City, Salt Lake County, Utah. CVWRF treats wastewater using a combination of processes. Every day,
between 50 and 60 million gallons of wastewater are conveyed into the facility for treatment. Those millions
of gallons of water are processed, impurities are separated and treated, and harmful bacteria, protozoa, and
viruses are eliminated so that only clean water is returned to Mill Creek and the Jordan River.
1.1 Site History and Permitting Timeline
CVWRF is currently permitted under Title V Air Permit 3500191001, issued March 16, 2020, through the
State of Utah, Department of Environmental Quality, Division of Air Quality (DAQ). Emissions at the facility are
primarily associated with electric power generation from the operation of prime-use digester gas/natural
gas-fueled engine generators and standby emergency diesel engine generators.
Due to an anticipated change in attainment status, the facility is required to perform a Reasonably Available
Control Technology (RACT) Analysis.
1.2 Attainment Status
CVWRF is located in Salt Lake County, Utah which is currently designated non-attainment for PM2.5, SO 2 and
ozone; the area is also designated as a PM10 maintenance area. Specific non-attainment status (marginal,
moderate, serious, etc.) is designated by the degree to which an area does not meet the national primary or
secondary ambient air quality standard for a National Ambient Air Quality Standard (NAAQS) pollutant. Salt
Lake County was designated as marginal non-attainment for ozone on June 4, 2018. Since the area was not
able to attain the ozone standard within the three-year period allowed by United States Environmental Pro-
tection Agency (USEPA), the area was re-designated as moderate non-attainment for ozone on November 7,
2022.
Ozone is not emitted directly into the air, but is formed through the photochemical reaction of nitrogen ox-
ides (NOx) and volatile organic compounds (VOCs). NOx and VOCs are known as ozone precursor gases,
which are, for the most part, emitted directly into the atmosphere.
The Northern Wasatch Front Ozone Nonattainment Area (NAA) is required to attain the ozone standard by
August 3, 2024; however recent monitoring data indicates the Northern Wasatch Front NAA will not attain
the standard and will be reclassified to serious non-attainment of ozone in February of 2025. The serious
non-attainment classification will trigger requirements for major stationary sources and new thresholds for
major stationary sources (50 tons per year or more of NOx or VOCs). The facility is estimated to have a poten-
tial to emit exceeding 50 tons per year of NOx, triggering the new major source threshold under the Northern
Wasatch Front NAA reclassification. The Ozone Implementation Rule in 83 FR 62998 requires the State Im-
plementation Plan (SIP) to include RACT for all major stationary sources in nonattainment areas classified as
moderate or higher.
1.3 Description of Emissions Units
The following emissions units are covered by the Title V permit (3500191001) last revised on September 9,
2021 and are sources of NOx.

Reasonably Available Control Technology Analysis for NOx

5
1_RACT Analysis
Table 1. Emission Sources
Emission Source Description
Digester Gas/Natural Gas Generator Engines (4)
Cogeneration Engines #1, #2, #3, #4
Four (4) GE Jenbacher Model JMS 612-F28F02 generator engines
Rating: 2,509 hp (each)
Fuel Type: Digester Gas/Natural Gas*
*Digester gas is the primary fuel
Emergency Generator Engines (10)
#2 and #3 – Rating: 896 hp each
#4 – Rating: 349 hp
#5 and #6 – Rating: 800 hp each
#7 and #8 – Rating 1,341 hp each
#9, #10, and #11 – Rating: 2,884 bhp/2000kW each
Fuel Type: Diesel
Waste Oil Heaters (3) Rating: 0.28, 0.33, and 0.35 MMBtu/hr each
Fuel Type: Used Oil
Digester Gas Flares (2) Fuel Type: Digester Gas
Type: Candlestick
Boilers (2)
Boiler #1 Rating: 6.05 MMBtu/hr
Boiler #2 Rating: 6.28 MMBtu/hr
Fuel Type: Natural Gas
Reasonably Available Control Technology Analysis for NOx

6
1_RACT Analysis
Section 2: RACT Analysis
A RACT analysis requires implementation of the lowest emission limitation that an emission source is capa-
ble of meeting by the application of a control technology that is reasonably available, considering technologi-
cal and economic feasibility. A RACT analysis must include the latest information when evaluating control
technologies. Control technologies evaluated for a RACT analysis can range from work practices to add-on
controls. As part of the RACT analysis, current control technologies already in use for NOx sources can be
taken into consideration. To conduct a RACT analysis, a top-down analysis is used to rank all control technol-
ogies:
 Step 1: Identify all reasonably available control technologies
 Step 2: Eliminate technically infeasible control technologies
 Step 3: Rank remaining control technologies based on capture and control efficiencies
 Step 4: Evaluate remaining control technologies on economic, energy, and environmental feasibility
 Step 5: Select RACT
The following presents the detailed RACT analysis for the emission units identified in Section 1.3.
2.1 JMS Digester Gas/Natural Gas Cogeneration Engines
2.1.1 Reasonably Available Control Technologies
A BACT analysis was completed for the Cogeneration Engines dated February 11, 2021. This BACT analysis
is provided as Attachment A in full, and has been utilized in the RACT analysis.
Several existing sources of information were used to identify emission controls that had been used for simi-
lar projects. The Utah DEQ, Air Quality Division did not have a RACT determination for a comparable digester
gas engine. BC conducted a search of the following BACT databases:
 USEPA RACT/BACT/LAER Clearinghouse (RBLC) - Category 17.140 – Internal Combustion Engines (ICE)
– Large (>500 hp) – Landfill/Digester/Bio-Gas
 California Statewide BACT Clearinghouse –ICE: Landfill or Digested Gas Fired
The results of these searches are included in the BACT analysis included in Attachment A. Table B-1 of At-
tachment A contains the RACT Determinations for Engines that were found in the USEPA RACT/BACT/LAER
Clearinghouse for Category 17.140 firing on landfill/digester/bio-gas. The search yielded 20 potential pro-
jects for consideration. Table B-2 of Attachment A contains the results of a search of the California Statewide
BACT Clearinghouse. Three projects were found, although one is a repeat from the USEPA RBLC.
All of the projects from the EPA database used landfill gas as fuel. While landfill gas and digester gas, can
both be categorized as “biogas,” they are dissimilar in composition. Digester gas is generally higher in heat
content than landfill gas and is comprised primarily of methane (CH4) and carbon dioxide (CO2). Landfill gas,
on the other hand, typically contains less CH4 and includes a mixture of various organic chemicals. As a con-
sequence, combustion of digester gas and landfill gas will emit different pollutants at different levels. There-
fore, landfill gas projects are not considered comparable to the proposed project.
The California Air Resources Board Statewide search yielded two digester gas fired projects, both of which
have lower emissions limits for NOx than the cogeneration engines. The City of Santa Maria Wastewater
Treatment Plant has a much smaller engine and does not provide many details on emission control, there-
fore it was excluded from the BACT analysis.
Reasonably Available Control Technology Analysis for NOx

7
1_RACT Analysis
The project most similar in design, by engine size, is Orange County Sanitation District which uses an oxida-
tion catalyst and selective catalytic reduction (SCR) for emission controls. This document will go into further
detail about the infeasibility of installing SCR controls for the cogeneration engines. Orange County Sanita-
tion District is located in the South Coast Air Quality Management District (SCAQMD) noted for its extremely
poor air quality (serious non-attainment for PM2.5 and extreme nonattainment for ozone), with three times
the population of Salt Lake County. The emission controls required in SCAQMD are much stricter than in any
other part of the United States, making that project not comparable.
In addition to the 2021 BACT analysis, an updated search of the EPA database using the same Category
17.140 was conducted on September 26, 2023. No new digester gas fired sources nor new control technol-
ogies were identified in that search.
2.1.2 Eliminate Technically Infeasible Control Technologies
The control technologies identified above (oxidation catalyst and SCR) are considered technologically feasi-
ble for the cogeneration engines.
2.1.3 Rank Remaining Control Technologies Based on Capture and Control Efficiencies
An add-on SCR control device is expected to provide 90% control of NOx emissions. An oxidation catalyst will
not provide control of NOx emissions.
2.1.4 Evaluate Remaining Control Technologies on Economic, Energy, and Environmental
Feasibility
During a BACT analysis dated February 11, 2021, Mr. Jim Schettler, PE, Brown and Caldwell’s Vice President
of Mechanical Engineering, completed a conceptual cost analysis to retrofit engines 3 and 4 with oxidation
catalyst and an SCR system. This analysis is found in Attachment A (Attachment C of the 2021 BACT report).
To add these controls would require significant redesign including:
 Additional equipment cost for the control equipment.
 Redesign and reconfiguration of all exhaust piping for both engines.
 Additional sensors, wiring and controls.
 Additional equipment installation costs.
 Structural modifications to the engine building, including the 2nd and 3rd deck, roof, and building wall.
 Increased engineering costs.
As detailed in Attachment C, costs to retrofit the engines to add SCR as well as oxidation catalysts would to-
tal $656,000 per engine (or $2,624,000 total) in 2021. Since the addition of oxidation catalysts would not
improve NOx emissions, the costs above have been adjusted to account for installation of the SCR systems
only, bringing the cost down to $556,800 per engine (or roughly $2,227,208 for all 4 engines) in 2021 dol-
lars. [It was assumed that 1/3 of the costs for the “Oxidation catalyst + SCR system” and 1/3 of the costs for
the “Equipment installation” were attributable to installation of the oxidation catalysts.]

Reasonably Available Control Technology Analysis for NOx

8
1_RACT Analysis
Table 2. Revised Estimated Costs for Engine Controls
Equipment Item Size Cost, each $ Remarks
SCR system (1/3 reduction for omitting oxidation cat.) For each engine 93,333 vendors quotes
Urea solution atomizing air compressor For this size SCR 6,000 complete
Urea solution atomizing air piping 60' per engine 1,440 approx.
Urea solution storage tank, 600 gallons HDPE 4,500 vendors quotes
Urea solution storage tank, fill and vent piping 3" 3,450 HDPE
Urea solution fill pump as needed 7,500 gear pump
Replacing 20" SST piping with 24" SST 46' each engine 31,280 sch 10S
High temp exhaust piping insulation, 24" dia 2" thick, 50' 7,200 approx.
24" SST piping supports lump sum 3,754
Expansion joints for 24" SST pipe 3 per engine 13,500 SST bellows
Urea solution piping, 1/2" SST 65' per engine 1,560
Subtotal $ 173,517
SCR sensors & electric controls wiring and controls 13,881 8%
Electrical wiring, motor starters, conduit, and misc. 27,763 16%
Subtotal $ 215,161
Equipment installation, per "RS Means Guide" at 35% 75,306 estimating guide
Structural steel modifications to 2nd deck approx.. 65,000 retrofit
Structural steel modifications to 3rd deck approx.. 28,000 retrofit
Structural modifications to roof approx.. 23,400 retrofit
Structural mods to building wall for 24" EE dia approx.. 31,560 retrofit
Subtotal $ 438,427
Engineering costs at 12% 52,611 typical, retrofit
Contingency at 15% 65,764
Total for each engine-generator $ 556,802 Approximately

Using the current prime lending rate of 8.5% (Wall Street Journal prime rate, 10/17/2023) and an expected
life of 20 years, the following formula was utilized to provide an annualized value for the construction cost
for SCR on the engines.
𝐵=𝑃𝑉∙ቄ ௜
ଵି(ଵା௜)ష೙ቅ (Eq. 1)
Where:
B = annualized control cost
PV = present day value of the control technology
i = interest rate at which the source can borrow money (8.5%)
n = life of equipment (number of years)
Using Equation 1 results in a $235,351.24 annualized value for the construction cost to install SCR on all
four engines.
In addition to construction costs, SCR will require ongoing costs as detailed in Table 3 below.

Reasonably Available Control Technology Analysis for NOx

9
1_RACT Analysis
Table 3. Estimated Ongoing Cost of SCR Control

IC Engine SCR System Ongoing Costs of Operation
SCR System Costs for an 1812 kW INNIO Jenbacher JMS 616 Spark Gas IC Engine Generator
Jim Schettler, BC
SCR System Electrical Operating Cost 10/20/2023
Atomizing air compressor 5 HP load approximate
4.14 kWe load
electricity cost $2,957 per year
Urea solution booster pump 0.5 HP load approximate
0.44 kWe load smaller motors are less efficient
electricity cost $313 per year
SCR system instruments, controls, heaters 600 watts approximate, 6 instruments
0.60 kWe load
electricity cost $428 per year
Urea heating 200 watts during cold weather hours
0.20 kWe load
electricity cost $34 per year for 2,000 hr/yr operation
Freeze protection 200 watts during cold weather hours
0.20 kWe load
electricity cost $34 per year for hr/yr operation
Urea Instruments 200 watts approximate, 6 instruments
0.20 kWe load
electricity cost $143 per year
SCR System Electrical Operating Cost, total $3,910 per year approximate
Urea Cost Urea solution usage, per hour 5.2 gals per hour, per similar engine-generator
SCR system urea dosing 8,300 hours per year, per engine-generator
Urea solution yearly usage 42,835 gallons per year, per continuously operated engine-generator
Urea solution unit cost $2.40 per gallon, at 42.5 % urea solution
Urea solution annual cost $102,805 per year, each operating engine-generator
Engine Lubrication, Added Cost of Low Ash Lube Oil (required for SCR catalyst)
Added cost per gallon of low ash lube oil $5 estimate
Jenbacher JMS616 engine lube capacity 180 gallons
Engine oil changes per year 5 approximately every 1600 operating hours
Added low ash engine lube oil cost $4,500 per year, each operating engine-generator
SCR Catalyst Media Core Replacement
SCR catalyst core replacement frequency every 6 years approximate, per Bob Erdman, sales engineer
SCR catalyst core replacement cost, complete $32,000 per catalyst supplier for San Diego project
SCR catalyst core replacement cost, per year $5,333 per year annualized
SCR System Testing Cost
engine exhaust source test costs $3,750 per year by an independent testing firm (estimate per Best Environmental)
Total yearly operating cost $120,000 for each engine-generator
Assumptions:$0.008 calculated cost per kWhr, average
0.086$ per kWh - electricity cost
8,300 hr/yr engine operating time
2,000 hr/yr cold weather operating hours
Reasonably Available Control Technology Analysis for NOx

10
1_RACT Analysis
Equation 2 was then utilized to provide the annualized cost of control.
𝐴=𝐵+𝐶
𝐷 (Eq. 2)
Where:
A = annualized cost of control ($/ton of pollutant removed)
B = annualized control cost (construction cost, per Equation 1 above)
C = annual ongoing cost of control ($/year)
D = Reduction in emissions (tons/year)

Assuming the SCR systems will reduce NOx emissions by 90% yields a reduction of 31.12 tons of NOx. The
cost-effectiveness of the SCR systems then equates to $22,985 per ton of NOx removed. Table 2-13 (Cost
and Cost Effectiveness Summary for NOx Control Techniques Applied to Lean-Burn SI Engines) in EPA’s Alter-
native Control Techniques Document (EPA-453/R-93-032) published in July 1993 provides an estimated
cost-effectiveness threshold for the 2,509 HP engines of $890/ton NOx removed (in 1991 dollars). When
these costs are escalated to current (year 2023) costs, the cost-effectiveness threshold is estimated to be
roughly $2,500/ton NOx removed (based on Engineering News Record cost data). When comparing the esti-
mated cost of control to the cost-effectiveness guidelines, the addition of SCR control is not considered cost-
effective for the engines.
This discussion does not account for direct and indirect environmental costs associated with storage and
handling of the urea necessary for the system. Therefore, for these reasons, we find additional emissions
controls to be infeasible for the cogeneration engines.
2.1.5 Select RACT
Per the analysis in Section 2.1.4, no RACT has been identified that is economically feasible for the existing
cogeneration engines.
2.2 Diesel Fired Emergency Generators
2.2.1 Reasonably Available Control Technologies
A BACT analysis was completed for the Diesel Fired Emergency Generators dated June 26, 2023. This BACT
analysis is provided as Attachment B in full, and has been utilized in the RACT analysis.
Several existing sources of information were used to identify emission controls that have been used for simi-
lar projects. The Utah DEQ, Air Quality Division did not have any NOx RACT determination for a comparable
internal combustion engine. In response to the area around the facility having been recently designated non-
attainment for ozone, the Utah DEQ website contains area source rules which apply to several specific
source categories; none of the rules apply directly or indirectly to internal combustion engines.
BC conducted an initial search of the following BACT database:
 USEPA RBLC – Category 17.110 – Internal Combustion Engines – Large (>500 hp) – Fuel Oil (kerosene,
aviation, and diesel) with a keyword search for “emergency”
The results from the RBLC initially provided over 6,000 potential determinations. However, the results were
further refined through filtering the information as follows:
 Engines fired on fuel other than diesel were removed
 Engines driving fire pumps were removed
Reasonably Available Control Technology Analysis for NOx

11
1_RACT Analysis
 Smaller engines (roughly under 1,000 hp) were removed
 Pollutants were limited to NOx only
The refined RBLC results provided 18 BACT determinations. The remaining control technologies for NOx cited
are listed in Table 4 below.

Table 4. RBLC BACT Methods of Control
Pollutant Methods of Control
NOx Emission Limit: 3.95 g/HP-hr – 4.46 g/HP-hra
a. The RBLC entry did not specify the method of control. BC requested verification from the
agency which submitted the determination for the NOx emission limit (PA 0291) and
received a response from the Pennsylvania Department of Environmental Protection stating
that the source had never been constructed. Therefore, this emissions limit was not
demonstrated as achieved in practice and was not brought forward for consideration as
RACT.

As noted in the footnote for the NOx emission standard in Table 4 above, according to an email from the
Pennsylvania Department of Environmental Protection, the facility subject to the NOx emission limit was
never constructed and the limit was not achieved in practice. Therefore, this RACT determination was not
brought forward.
2.2.2 Eliminate Technically Infeasible Control Technologies
Not applicable as no control technologies are identified.
2.2.3 Rank Remaining Control Technologies Based on Capture and Control Efficiencies
Not applicable as no control technologies are identified.
2.2.4 Evaluate Remaining Control Technologies on Economic, Energy, and Environmental
Feasibility
Not applicable as no control technologies are identified.
2.2.5 Select RACT
Per the analysis in Section 2.2.1, no RACT has been identified for the existing emergency generator engines.
2.3 Waste Oil Heaters
2.3.1 Reasonably Available Control Technologies
Existing sources of information were used to identify emission controls that have been used for similar pro-
jects. BC conducted an initial search of the following BACT database:
 USEPA RBLC – All Process Types, Process Name Contains: “waste oil”
The results from the RBLC provided zero potential determinations.
2.3.2 Eliminate Technically Infeasible Control Technologies
Not applicable as no control technologies are identified.
2.3.3 Rank Remaining Control Technologies Based on Capture and Control Efficiencies
Not applicable as no control technologies are identified.
Reasonably Available Control Technology Analysis for NOx

12
1_RACT Analysis
2.3.4 Evaluate Remaining Control Technologies on Economic, Energy, and Environmental
Feasibility
Not applicable as no control technologies are identified.
2.3.5 Select RACT
Per the analysis in Section 2.3.1, no RACT has been identified for the existing waste oil heaters.
2.4 Digester Gas Flares
2.4.1 Reasonably Available Control Technologies
Existing sources of information were used to identify emission controls that have been used for similar pro-
jects.
BC conducted an initial search of the following BACT database:
 USEPA RBLC – Category 19.320– Digester and Landfill Gas Flares – Pollutant Name: NOx
The results from the RBLC initially provided 5 potential determinations. The method of control for the 5 de-
terminations considered were listed as “good combustion practices” and installation of a gas collection sys-
tem with a flare. However, two of the processes noted that control was achieved using an enclosed flare.
Since enclosed flares are commonly used for combustion of excess digester gas at wastewater treatment
plants and the facility currently uses an open flare, this RACT review considered the use of an enclosed flare
for providing NOx control.
2.4.2 Eliminate Technically Infeasible Control Technologies
Use of an enclosed flare is considered technologically feasible for combustion of excess digester gas at the
plant.
2.4.3 Rank Remaining Control Technologies Based on Capture and Control Efficiencies
Use of enclosed flares is the only control technology being considered. Based on a literature review of NOx
emission factors for open flares and enclosed flares, it is expected that use of an enclosed flare would pro-
vide approximately a 12% reduction in NOx emissions (0.06 lb NOx/mmbtu for an enclosed flare versus
0.068 lb NOx/mmbtu for an open flare). This would result in a 0.06 ton per year NOx reduction at the facility.
2.4.4 Evaluate Remaining Control Technologies on Economic, Energy, and Environmental
Feasibility
Using Equations 1 and 2 (described in Section 2.1.4), together with a recent cost proposal received by BC for
a project in Washington State as well as data provided by BC’s subject matter experts for ongoing costs for
an enclosed flare, the cost of control is estimated to be roughly $ 568,000 per ton of NOx removed. (See At-
tachment D for information on the flare cost breakdown.)
BC did not find a cost-effectiveness threshold specific to NOx emissions from flares, but the cost-effective-
ness threshold for NOx is $ 17,500 per ton of NOx reduction in the Bay Area Air Quality Management District
(BAAQMD) in California. Using this threshold for comparison purposes finds that the cost of replacing the ex-
isting flare with an enclosed flare is not economically feasible.
2.4.5 Select RACT
Per the analysis in Section 2.4.4, no RACT has been identified that is economically feasible for the existing
digester gas flares.
Reasonably Available Control Technology Analysis for NOx

13
1_RACT Analysis
2.5 Boilers
2.5.1 Reasonably Available Control Technologies
Existing sources of information were used to identify emission controls that have been used for similar pro-
jects.
BC conducted an initial search of the following BACT database:
 USEPA RBLC – Category 13.310 – Commercial/Institutional-Size Boilers/Furnaces (<100 million BTH/H)
– Gaseous Fuel & Gaseous Fuel Mixtures – Natural Gas; Pollutant Name: NOx
The results from the RBLC initially provided 189 potential determinations. However, the results were further
refined to 18 entries through filtering the information as follows:
 Larger boilers (greater than 10 MMBtu/hr) were removed
 Boilers without a throughput listed (0 MMBtu/hr) were removed
 Boilers without a control method description were removed
The remaining entries identified the following as possible control technologies for NOx for natural gas-fired
boilers of similar design and size:
 Low NOx burners
 Good combustion practices
 Use of pipeline quality natural gas
Control technologies, good combustion practices, and use of pipeline quality natural gas are already imple-
mented and thus will not be considered any further in this evaluation. This document will go into further de-
tail about the infeasibility of installing the low NOx burners for the boilers.
2.5.2 Eliminate Technically Infeasible Control Technologies
All control technologies are technically feasible.
2.5.3 Rank Remaining Control Technologies Based on Capture and Control Efficiencies
The only control technology under evaluation is the use of low NOx burners. Low NOx burners capable of
achieving 30 ppm NOx in the exhaust are estimated to provide approximately 68% NOx reduction.
2.5.4 Evaluate Remaining Control Technologies on Economic, Energy, and Environmental
Feasibility
Mr. Jim Schettler, PE, Brown and Caldwell’s Vice President of Mechanical Engineering, completed a concep-
tual cost analysis to retrofit boilers 1 and 2 with low NOx burners. This analysis is found in Attachment C. To
replace the existing burners with 30 ppm NOx Weishaupt burner using flue gas recirculation as the low NOx
technique, the combined cost including burner, installation, and start-up services would cost $80,000 each
or $160,000 total. As shown in Attachment D, the cost of controls is calculated to be $45,184 per ton NOx
removed for Boiler #1 and $43,529 per ton NOx removed for Boiler #2.
Table 6-11 (NOx Control Cost Effectiveness Without/With CEM System, Natural-Gas-Fired ICI Boilers) in EPA’s
Alternative Control Techniques Document -- NOx Emissions from Industrial / Commercial / Institutional (lCI)
Boilers (EPA-453/R-94-022) provides an estimated cost-effectiveness thresholds for retrofitting an existing
10 MMBtu/hr boiler with low NOx burners. The costs provided range from $3,260 to $4,300 per ton NOx re-
moved (in 1992 dollars). When the upper end of this cost range is escalated to current (year 2023) costs,
the cost-effectiveness threshold is estimated to be roughly $11,400/ton NOx removed (based on
Reasonably Available Control Technology Analysis for NOx

14
1_RACT Analysis
Engineering News Record cost data). When we compare the estimated cost of control to the cost-effective-
ness guideline, retrofitting the boilers with low NOx burners is not considered cost-effective.
Therefore, we find retrotting the existing boilers for NOx control to be infeasible.
2.5.5 Select RACT
Per the analysis in Section 2.5.4, no RACT has been identified that is economically feasible for the existing
boilers.
Reasonably Available Control Technology Analysis for NOx

15
1_RACT Analysis
Section 3: Conclusion
In conclusion, control technologies were identified for the following equipment:
1. Cogeneration engines
2. Diesel powered emergency generators
3. Flares
4. Boilers
All control technologies identified were determined to be technically or economically infeasible.
Reasonably Available Control Technology Analysis for NOx

A
1_RACT Analysis

Attachment A: 2021 BACT - Cogen Engines

Technical Memorandum

Limitations:
This document was prepared solely for Central Valley Water Reclamation Facility in accordance with professional standards at the time the services
were performed and in accordance with the contract between Central Valley Water Reclamation Facility and Brown and Caldwell dated
December 16, 2020. This document is governed by the specific scope of work authorized by Central Valley Water Reclamation Facility; it is not
intended to be relied upon by any other party except for regulatory authorities contemplated by the scope of work. We have relied on information or
instructions provided by Central Valley Water Reclamation Facility and other parties and, unless otherwise expressly indicated, have made no
independent investigation as to the validity, completeness, or accuracy of such information.
11020 White Rock Road, Suite 200
Rancho Cordova, CA 95670

T: 916-444-0123

Prepared for: Central Valley Water Reclamation Facility
Project Title: TO 2016-01 Cogen Replacement
Project No.: 148855
Technical Memorandum
Subject: Best Available Control Technology Determination for Cogen Engines 3 and 4
Date: February 11, 2021
To: Bryan Mansell, Plant Engineer
From: Jennifer Marchek
Copy to: File

Prepared by:
Jennifer Marchek, Principal Engineer

Reviewed by:
Jason Wiser, Project Manager

Technical Memorandum Best Available Control Technology Determination for Cogen Engines 3 and 4

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Table of Contents
Section 1: Background ............................................................................................................................................. 1
1.1 Site History and Permitting Timeline .............................................................................................................. 1
1.2 Attainment Status............................................................................................................................................ 2
1.3 Description of Engines .................................................................................................................................... 2
Section 2: BACT Analysis .......................................................................................................................................... 2
2.1 Pollutants for Which BACT is Required .......................................................................................................... 3
2.2 Control Technologies and/or Emission Limits ............................................................................................... 3
Section 3: Infeasibility of Controls ........................................................................................................................... 4
Section 4: Conclusion ............................................................................................................................................... 5
Attachment A: Engine Specifications ....................................................................................................................... A
Attachment B: BACT Database Search Results ...................................................................................................... B
Attachment C: Additional Controls Retrofit Cost Estimate ..................................................................................... C

List of Tables
Table 1. CVRWF Title V Emissions Limits for Jenbacher Engines 1 and 2 ............................................................ 1
Table 2. Manufacturer's Emission Guarantees ...................................................................................................... 2
Table 3. Applicable Emission Limits from 40 CFR, Part 60, Subpart JJJ for
Landfill/Digester Gas >1,350hp ........................................................................................................... 4
Table 4. Most Stringent Emission Rates Identified for Digester Gas Fired Engines ............................................ 4

Technical Memorandum Best Available Control Technology Determination for Cogen Engines 3 and 4

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Section 1: Background
The Central Valley Water Reclamation Facility (CVWRF) is located at 800 West Central Valley Road in Salt
Lake City, Salt Lake County, Utah. CVWRF treats wastewater using a combination of processes. Every day,
between 50 and 60 million gallons of wastewater are collected and flow into the facility for treatment. Those
millions of gallons of water are processed, impurities are separated and treated, and harmful bacteria,
protozoa, and viruses are eliminated so that only clean water is returned to Mill Creek and the Jordan River.
1.1 Site History and Permitting Timeline
CVWRF has a Title V Air Permit though the State of Utah, Department of Environmental Quality, Division of Air
Quality (DAQ), Permit 3500191001, issued March 16, 2020, which expires March 16, 2025. Emissions are
primarily associated with electrical generation from the operation of digester gas engines and emergency
generators.
In 2016 CVWRF began a project to update its five older Waukesha digester gas/natural gas engines with
four 2,509 horsepower (hp) GE Jenbacher engines (engine details are provided in Attachment A). The newer
engines must be installed and commissioned one at a time to ensure continuous operation. The facility
obtained an air permit (DAQE-AN104140012-17) from DAQ for all four new Jenbacher engines in 2017 and
purchased all four engines at that time. DAQ conducted the Best Available Control Technology (BACT)
analysis and approved all four engines as meeting BACT at the time of permit approval. The project
experienced several delays in scheduling and in 2019 the DAQ modified the permit to include only engines 1
and 2, with CVWRF intending to install the new engines in 2023. In 2020 CVWRF made gains in the
schedule and is now prepared to install engines 3 and 4 in 2021. Upon submittal of an NOI to add engines 3
and 4 into the permit, DAQ asked for an updated BACT analysis for engines 3 and 4. This document is the
response to that request.
The Title V permit contains the following emission limits for the new engines as shown in Table 1.

Table 1. CVRWF Title V Emissions Limits for Jenbacher Engines 1 and 2
Pollutant Digester Gas Mode Emission Limit (g/bhp-hr) Natural Gas Mode Emission Limit (g/bhp-hr)
VOC 1 0.7
NOx 0.55 0.55
CO 2.5 2.0
CO = Carbon Monoxide
NOx = Nitrogen Oxides
VOC = volatile organic compound

Engines 1 and 2 have been source tested and meet these emission limits. The permit does not contain limits
for sulfur dioxide (SO2), Particulate Matter less than 10 Microns (PM10), or Particulate Matter less than 2.5
microns (PM2.5).
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1.2 Attainment Status
CVWRF is located in Salt Lake County, which is currently a non-attainment area for PM2.5, SO2 and Ozone,
and designated as maintenance status for PM10. At the commencement of the engine replacement project,
Salt Lake County was in attainment with the Federal 8-hour Ozone standard. In 2018, the area’s status was
changed to marginal non-attainment for Ozone.
1.3 Description of Engines
At the time of purchase of all four engines and installation of engines 1 and 2, the manufacturer emission
guarantees for the engines were as noted in Table 2 below and included as Attachment A

Table 2. Manufacturer's Emission Guarantees
Pollutant Emission Rate (g/bhp-hr)
NOx 0.55
CO 2.5
Non-methane Hydrocarbons 0.3
Non-methane Ethane Hydrocarbons 0.2
PM10 0.03
PM2.5 0.02

Section 2: BACT Analysis
Following United States Environmental Protection Agency (USEPA) Guidance, BACT can be defined as the
most stringent of the following:
• The lowest emission rate or most effective emission limitation successfully achieved in practice by the
same type of equipment, combusting the same type of fuel.
• The lowest emission rate or most effective emission control device determined to be technically feasible
and cost effective for the equipment being installed, combusting the same type of fuel.
• The requirements of a Utah or Federal Performance Standard Regulation.
A BACT analysis is performed on a case-by-case basis and must consider emission rates and/or control
technologies that have been achieved on similar equipment or that are technically feasible and cost
effective. These requirements have led to development of a standard procedure for case-by-case “top down”
BACT analyses.
• Step 1: Identify pollutants for which BACT is required. Utah Department of Environmental Quality (DEQ)
regulations require BACT for all criteria pollutants.
• Step 2: Identify emission rates and/or control technologies. Once the pollutants for which the BACT
analysis is required are identified, candidate emission rates and/or control technologies must be
identified.
• Step 3: Evaluate technical feasibility of the emission rates and/or control technologies identified in Step
2. Any emission rates and/or control technologies that are not technically feasible should be eliminated
at this step.
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• Step 4: Ranking of remaining emission rates and/or control technologies by effectiveness. This ranking
should consider, as appropriate, control efficiency, resulting emission rates, energy impacts (fuel use,
etc.), and environmental impacts (secondary air emissions, hazardous waste production, impacts to
other media, etc.).
• Step 5: Cost effectiveness evaluation of the most stringent emission rates and/or most effective
controls.
• Step 6: Select BACT.
2.1 Pollutants for Which BACT is Required
This BACT analysis considered emissions of NOx, CO, VOC, PM10, PM2.5, and SO2.
2.2 Control Technologies and/or Emission Limits
Several Sources of information were used to identify emission controls that had been used for similar
projects. The Utah DEQ, Air Quality Division did not have any BACT determination for a comparable digester
gas engine. BC conducted an initial BACT determinations search of the following databases:
• USEPA Reasonable Available Control Technology (RACT)/BACT/Lowest Achievable Emission Rate (LAER)
Clearinghouse - Category 17.140 – Internal Combustion Engines (ICE) – Large (>500 hp) –
Landfill/Digester/Bio-Gas
• California Statewide BACT Clearinghouse –ICE: Landfill or Digested Gas Fired
The results of these searches are found in Attachment B. Table B-1 contains the BACT Determinations for
Engines that were found in the USEPA RACT/BACT/LAER Clearinghouse for Category 17.140 (ICE) firing on
landfill/digester/bio-gas). The search yielded 20 potential projects for consideration. Table B-2 contains the
results of a search of the California Statewide BACT Clearinghouse. Three projects were found, although one
is a repeat from the USEPA RBLC.
All of the projects from the EPA database used landfill gas as fuel. Landfill gas and digester gas, while both
can be categorized as “biogas”, are dissimilar in composition. Digester gas is generally higher in heat
content than landfill gas and is made up of almost pure methane and carbon dioxide (CO2). Landfill gas, on
the other hand, is made up of a mixture of various organic chemicals. As a consequence, combustion of
digester gas and landfill gas will emit different pollutants at different levels. Therefore, landfill gas projects
are not considered comparable to the proposed project.
The California Air Resources Board Statewide search yielded two digester gas fired projects, both of which
have lower emissions limits for NOx, VOC, and CO than engines 3 and 4. Neither digester gas projects
contained emission limits for PM10, PM2.5 and SO2. The City of Santa Maria Wastewater Treatment Plant is
a much smaller engine and does not provide many details on emission control, therefore it was excluded.
The project most similar in design, by engine size, is Orange County Sanitation District which uses an
oxidation catalyst and selective catalytic reduction (SCR) for emission controls. This document will go into
further detail about the infeasibility of installing this level of controls for engines 3 and 4. Orange County
Sanitation District is located in the South Coast Air Quality Management District (SCAQMD) noted for its
extremely severe air pollution (serious non-attainment for PM2.5 and extreme nonattainment for Ozone),
with three times the population of Salt Lake County. The emission controls required in SCAQMD are much
stricter than in any other part of the United States, making that project not comparable.
Additionally, BACT must consider applicable regulatory performance standards. For the engines, 40 Code of
Federal Regulations (CFR), Part 60, Subpart JJJJ is applicable. The following ICE emission limitations are
imposed by these regulations as shown in Table 3.

Technical Memorandum Best Available Control Technology Determination for Cogen Engines 3 and 4

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Table 3. Applicable Emission Limits from 40 CFR, Part 60, Subpart JJJ for
Landfill/Digester Gas >1,350hp
Pollutant Emission Limit (g/hp/hr)
NOx 2
VOC 1
CO 5
g/hp/hr = grams per horsepower per hour

Based on the investigation described herein, it was determined that one comparable project had stricter
requirements identified for NOx, CO, and VOC, while the BACT search did not specify stricter emission limits
for PM10, or PM2.5. For PM10, and PM2.5 the manufacturer’s guarantee or Title V limit will be considered
most stringent as identified in Table 4.

Table 4. Most Stringent Emission Rates Identified for Digester Gas Fired Engines
Pollutant Emission Limit (g/hp/hr) Source
NOx 0.15 Orange County Sanitation District a
CO 2.03 Orange County Sanitation District a
VOC 0.14 Orange County Sanitation District a
PM10 0.03 Manufacturer's Specifications
PM2.5 0.02 Manufacturer's Specifications
a. Project contains additional emission controls which are infeasible for this project

Section 3: Infeasibility of Controls
Mr. Jim Schettler, PE, Brown and Caldwell’s Vice President of Mechanical Engineering, completed a
conceptual cost analysis to retrofit engines 3 and 4 with oxidation catalyst and a SCR system. This analysis
is found in Attachment C. To add these controls would require significant redesign including:
• Additional equipment cost for the control equipment.
• Redesign and reconfiguration of all exhaust piping for both engines.
• Additional sensors, wiring and controls.
• Additional equipment installation costs.
• Structural modifications to the engine building, including the 2nd and 3rd deck, roof, and building wall.
• Increased engineering costs.
As detailed in Attachment C, these combined costs would total $656,000 per engine or $1,312,000 total. In
addition, this would add a significant time delay for the project; meanwhile the existing Waukesha engine 5,
which pollutes at a much higher level than the new engines 3 and 4, would continue to operate. As the
existing engine is operating outside of its useful life and prone to mechanical malfunctions, it could also lead
to shutdowns at the facility which would result in more frequent operation of the diesel standby engines and
reduce the reliability of the wastewater treatment systems. Therefore, for these reasons, we find additional
emissions controls to be infeasible for engines 3 and 4.
Technical Memorandum Best Available Control Technology Determination for Cogen Engines 3 and 4

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Section 4: Conclusion
In conclusion, CVWRF purchased and initially permitted Jenbacher engines 1, 2, 3 and 4, which at the time
were all deemed to meet BACT. Engines 1 and 2 were installed and are operational, but due to a series of
construction delays the facility was unable to meet the original schedule for installation of engines 3 and 4.
One digester gas fired ICE project found in the BACT database search utilized oxidation catalyst and SCR to
meet lower NOx and CO limits. However, at this point to install these controls for engines 3 and 4 would
require extensive redesign and significantly increased construction costs as outlined in Section 3 above. For
these reasons, we are requesting that engines 3 and 4 be considered to meet BACT without modification, as
was previously determined, and be permitted for installation by DAQ.

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Technical Memorandum Best Available Control Technology Determination for Cogen Engines 3 and 4

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Attachment A: Engine Specifications

Technical Memorandum Best Available Control Technology Determination for Cogen Engines 3 and 4

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GE Distributed Power
GE Gas Engines
Emissions Letter 8/16/2016 Page 1 of 3

16 August 2016
GE Distributed Power – GE Gas Engines confirms that the pollutants, in the amounts listed below, are confirmed as
valid "NOT TO EXCEED" values, for stationary applications per engine, and based on site gas conditions that meet
TI 1000-0300 standards for the:
Brown and Caldwell: J612 F28/F02
Pollutant Emission Limit
 NOx 0.55 g/bhp-hr (NO2)
Evaluated using EPA method 7E

 CO 2.5 g/bhp-hr
Evaluated using EPA method 10

 NMHC 0.3 g/bhp-hr
Evaluated using EPA method 18 (non-aldehydes, non-methane hydrocarbons, all CxHy with x>1)

 NMNEHC 0.2 g/bhp-hr
Evaluated using EPA method 18 (non-aldehydes, non-methane ethane hydrocarbons, all CxHy with x>2)

 PM 10 0.03 g/bhp-hr

 PM 2.5 0.02 g/bhp-hr

The following criteria apply for demonstration purposes:
(1) Operations will be on Sewage Gas, Natural Gas or a Blend all of which must meet the GE Gas Engines gas
quality requirements stated in the Technical Instruction 1000 -0300.

(2) A minimum content of 60% CH4 (air free) is required to ensure a stable combustion in our engines when
run on Sewage Gas.

(3) A minimum content of 80% CH4 (air free) is required to ensure a stable combustion in our engines when
run on Natural Gas

(4) Based on nominal mass flow as provided by the project specific data sheets or mass flow calculations
according EPA method 19.

(5) Formaldehyde – GE Gas Engines has done a significant amount of research studying formaldehyde (CH 2O)
concentrations in our engine exhaust streams. The results of this research find that formaldehyde is in
itself a difficult quantity to measure accurately and consiste ntly, however, what can be stated from our
studies is that typically, the range of formaldehyde in raw exhaust can go from 50 to 150 mg/Nm3 at 5%
O2 (0.14 TO 0.45 g/bhp-hr).

GE Distributed Power
GE Gas Engines
Emissions Letter 8/16/2016 Page 2 of 3
If a unit is running on Biogas or Landfill Gas (LFG), formaldehyde (CH 2O) is then even more difficult to
maintain and measure since Biogas/LFG are high in moisture and sulfur concentrations, which make the
use of catalysts very difficult due to the potential of catalyst poisoning.

GE Gas Engines can only guarantee formaldehyde values with an Oxidation Catalyst when we run a GE Gas
Engines Standard Natural Gas. In this case, we could achieve levels of 60~70 mg/Nm3 @ 5% O2 (0.18 to
0.22 g/bhp-hr) on the measurement method VDI 3862.

(6) For emissions shown in units of g/bhp-hr, values are valid between 80% and 100% rated stable load (not
for island mode).

(7) For emissions shown in units of mg/Nm3, values are valid between 50% and 100% rated stable load (not
for island mode).

(8) Please note that the CO and NMHC levels are for start-up only and are expected to drift slowly upwards as
deposits build up in the engine and as the engine experiences normal wear. CO drift can be decreased by
following GE Gas Engines specific maintenance and repair schedules along with the use of genuine GE Gas
Engines parts and components.

(9) Please note that the NOx level is expected to drift slowly upwards as deposits caused by contaminations in
the gas build up in the engine and as the engine experiences normal wear. NOx drift can be compensated
up to a certain extent, by calibrations to engine operating parameters in the Diane XT controls system.
Excessive deposits resulting from gas contamination may require the cleaning of the combustion chamber
and turbochargers depending on gas quality and the severity of gas contaminations.
(10) Maintenance and component repairs for the GE Gas Engines equipment is carried out by qualified
personnel strictly according to the schedules and repair requirements set by GE Gas Engines along with the
use of genuine GE Gas Engines parts and components.

(11) Testing to determine compliance with this commitment will be at the expense of the customer and
accomplished by a certified laboratory chosen by the customer. The engine/installation is to be in good
working order consistent with GE Gas Engines recommende d maintenance practices prior to any testing.
GE Gas Engines reserves the right to participate and/or challenge the results of any testing.
If the engine fails to meet the emissions representations the customer must provide the following supporting
documentation to GE Gas Engines:
(1) Fuel gas samples
(2) Complete maintenance records
(3) A full report including the calculations and results of any emissions testing.
GE Gas Engines will be given a reasonable amount of time to take any or all of the followin g actions:
 Perform additional testing in an effort demonstrate the emissions representations. If this testing
demonstrates compliance with no adjustments required to the engine, customer will pay for added testing. If
testing fails to demonstrate compliance with the emissions representations, the testing will be paid for by GE
Gas Engines.
 Make such adjustments to the engine so as to bring the engine into compliance with the emissions limits
provided in this letter.

GE Distributed Power
GE Gas Engines
Emissions Letter 8/16/2016 Page 3 of 3
Conformity Declaration (acc. ISO/IEC 17050-1:2004)
We hereby confirm that stationary GE Gas Engines comply with 40 CFR Part 60, subpart JJJJ and be labelled as
follows:

“THIS ENGINE IS EXCLUDED FROM THE REQUIREMENT OF 40 CFR PART 1048 AS A “STATIONARY ENGINE”.
INSTALLING OR USING THIS ENGINE IN ANY OTHER APPLICATION MAY BE A VIOLATION OF FEDERAL LAW
SUBJECTED TO CIVIL PENALTY AND THE OWNER/OPERATOR MUST COMPLY WITH THE REQUIREMENT OF CFR PART
60. THIS ENGINE IS NOT PART OF A REQUI RED OR VOLUNTARY CERTIFICATION PROGRAM AND IS CLASSIFIED AS
NON-CERTIFIED PER 40 CFR PART 60, SUBPART JJJJ”.

GE Distributed Power
GE Gas Engines
11330 Clay Road
Houston, TX 77041
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Technical Description
Cogeneration Unit
JMS 612 GS-B.L
with Island Operation

Brown & Caldwell
JMS 612 F28/F02, 4160V Dual Fuel
The ratings in the specification are valid for full load operation at a site installation of 4240 ft (1292 m) and an air intake
temperature of T1 < 95 F (35C). At T1 > 95 F (35C), an output deration of 1.11%/F (2.0%/C) will occur.

Electrical output 1812 kWe

Thermal output ( Biogas / Natural Gas ) 2594 / 2752 Mbtu/hr

Emission values
NOx < 0.5 g/bhp.hr (NO2)

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0.01a Technical Data on Sewage Gas (F28) (at module) ______________________ 5
0.01b Technical Data on Natural Gas (F02) (at module) ______________________ 6
Main dimensions and weights (at module)(with gearbox) 7
Connections 7
Output / fuel consumption 7
0.02 Technical data of engine ___________________________________________ 8
Thermal energy balance 8
Exhaust gas data 8
Combustion air data 8
Sound pressure level 9
Sound power level 9
0.02.01 Technical data of gearbox _______________________________________ 9
0.03 Technical data of generator ________________________________________ 10
Reactance and time constants (saturated) 10
0.04 Technical data of heat recovery ____________________________________ 11
General data - Hot water circuit 11
General data - Cooling water circuit 11
100% Biogas Thermal Connection Variant K ______________________________ 12
100% Natural Gas Thermal Connection Variant K __________________________ 13
0.10 Technical parameters_____________________________________________ 14
1.00 Scope of supply - Module _________________________________________ 16
1.01 Spark ignited gas engine __________________________________________ 16
1.01.01 Engine design (Air Start) _______________________________________ 17
1.01.02 Additional equipment for the engine (spares for commissioning) ______ 18
1.01.03 Engine accessories ____________________________________________ 19
1.01.04 Standard tools (per installation)__________________________________ 19
1.02 Generator-medium voltage ________________________________________ 20
1.03 Module Accessories ______________________________________________ 23
1.03.01 Engine jacket water system _____________________________________ 25
1.03.02 Automatic lube oil replenishing system incl. extension tank __________ 25
1.04 Heat recovery ___________________________________________________ 26
1.05a Gas train (Biogas) ______________________________________________ 26
1.05b Gas train (Natural Gas) __________________________________________ 27
1.05c Pre-chamber Gas train (Natural Gas) _______________________________ 27

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1.07 Painting ________________________________________________________ 28
1.11 Engine generator control panel per module- Dia.ne XT4 incl. Single
synchronization of the generator breaker ________________________________ 29
Touch Display Screen: 30
Central engine and module control: 32
Malfunction Notice list: 34
1.11.01 Remote messaging over MODBUS-TCP ___________________________ 36
1.11.06 Remote Data-Transfer with DIA.NE XT4 ___________________________ 37
1.11.14 Generator Overload / Short Circuit Protection ______________________ 41
1.11.15 Generator Differential Protection _________________________________ 41
1.11.16 Generator Earth Fault Protection (nondirectional) ___________________ 41
1.11.31 Interfaces to customer Master synchronization (Synchronization of grid CB)
42
1.20.03 Start System (Air Start) _________________________________________ 42
1.20.04 Battery System _______________________________________________ 43
1.20.05 Electric jacket water preheating __________________________________ 43
1.20.08 Flexible connections ___________________________________________ 44
1.20.45 Fuel Blending _________________________________________________ 44
2.00 Electrical equipment _____________________________________________ 45
2.02 Grid monitoring device ___________________________________________ 45
2.12 Gas warning device ______________________________________________ 47
2.13 Smoke warning device ____________________________________________ 47
3.70 Control Strategy and Options ______________________________________ 48
3.71 Vibration Sensor _________________________________________________ 50
3.72 Seismic Protection _______________________________________________ 50
4.00 Delivery, installation and commissioning ____________________________ 51
4.01 Carriage 51
4.02 Unloading 51
4.03 Assembly and installation 51
4.04 Storage 51
4.05 Start-up and commissioning 51
4.06 Trial run 51
4.07 Emission measurement (exhaust gas analyser) 51
5.01 Limits of delivery ________________________________________________ 52
5.02 Factory tests and inspections ______________________________________ 53

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5.02.01 Engine tests 53
5.02.02 Generator tests 53
5.02.03 Module tests 53
5.03 Documentation __________________________________________________ 54

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0.01a Technical Data on Sewage Gas (F28) (at module)

Data at: Full
load
Part Load
Fuel gas LHV BTU/scft 548
100% 75% 50%

Energy input MBTU/hr [2] 14,670 11,336 8,002
Gas volume scfhr *) 26,770 20,686 14,602
Mechanical output bhp [1] 2,509 1,881 1,255
Electrical output kW el. [4] 1,812 1,355 896
Recoverable thermal output
~ Intercooler 1st stage MBTU/hr 1,618 914 366
~ Lube oil MBTU/hr ~ ~ ~
~ Jacket water MBTU/hr 976 864 740
~ Exhaust gas cooled to 727 °F MBTU/hr ~ ~ ~
Total recoverable thermal output MBTU/hr [5] 2,594 1,778 1,106

Heat to be dissipated
~ Intercooler 2nd stage (with gearbox) MBTU/hr [9] 503 338 214
~ Lube oil MBTU/hr 752 674 578
~ Surface heat ca. MBTU/hr [7] 506 ~ ~

Spec. fuel consumption of engine electric BTU/kWel.hr [2] 8,098 8,367 8,929
Spec. fuel consumption of engine BTU/bhp.hr [2] 5,847 6,025 6,375
Lube oil consumption ca. gal/hr [3] 0.12 ~ ~
Electrical efficiency % 42.1% 40.8% 38.2%
Thermal efficiency % 17.7% 15.7% 13.8%
Total efficiency % [6] 59.8% 56.5% 52.0%

Hot water circuit:
Forward temperature °F 186.0 181.0 176.8
Return temperature °F 170.0 170.0 170.0
Hot water flow rate GPM 324.2 324.2 324.2
*) approximate value for pipework dimensioning
[_] Explanations: see 0.10 - Technical parameters

All heat data is based on standard conditions according to attachment 0.10. Deviations from the standard conditions can result in a
change of values within the heat balance, and must be taken into consideration in the layout of the cooling circuit/equipment
(intercooler; emergency cooling; ...). In the specifications in addition to the general tolerance of ±8 % on the thermal output a further
reserve of +5 % is recommended for the dimensioning of the cooling requirements.

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0.01b Technical Data on Natural Gas (F02) (at module)

Data at: Full
load
Part Load
Fuel gas LHV BTU/scft 917
100% 75% 50%

Energy input MBTU/hr [2] 14,245 10,947 7,651
Gas volume scfhr *) 15,534 11,938 8,344
Mechanical output bhp [1] 2,509 1,881 1,255
Electrical output kW el. [4] 1,812 1,355 896
Recoverable thermal output
~ Intercooler 1st stage MBTU/hr 1,437 808 279
~ Lube oil MBTU/hr ~ ~ ~
~ Jacket water MBTU/hr 1,135 1,009 839
~ Exhaust gas cooled to 677 °F MBTU/hr ~ ~ ~
Total recoverable thermal output MBTU/hr [5] 2,572 1,817 1,118

Heat to be dissipated
~ Intercooler 2nd stage (with gearbox) MBTU/hr [9] 608 373 218
~ Lube oil MBTU/hr 582 518 446
~ Surface heat ca. MBTU/hr [7] 577 ~ ~

Spec. fuel consumption of engine electric BTU/kWel.hr [2] 7,863 8,080 8,538
Spec. fuel consumption of engine BTU/bhp.hr [2] 5,677 5,818 6,095
Lube oil consumption ca. gal/hr [3] 0.12 ~ ~
Electrical efficiency % 43.4% 42.2% 40.0%
Thermal efficiency % 18.1% 16.6% 14.6%
Total efficiency % [6] 61.5% 58.8% 54.6%

Hot water circuit:
Forward temperature °F 185.9 181.2 176.9
Return temperature °F 170.0 170.0 170.0
Hot water flow rate GPM 324.2 324.2 324.2

*) approximate value for pipework dimensioning
[_] Explanations: see 0.10 - Technical parameters

All heat data is based on standard conditions according to attachment 0.10. Deviations from the standard conditions can result in a
change of values within the heat balance, and must be taken into consideration in the layout of the cooling circuit/equipment
(intercooler; emergency cooling; ...). In the specifications in addition to the general tolerance of ±8 % on the thermal output a further
reserve of +5 % is recommended for the dimensioning of the cooling requirements.

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Main dimensions and weights (at module)(with gearbox)
Length in ~ 360
Width in ~ 90
Height in ~ 110
Weight empty lbs ~ 51,460
Weight filled lbs ~ 53,660

Connections
Hot water inlet and outlet in/lbs 4''/145
Exhaust gas outlet in/lbs 20''/145
Fuel Gas (at module) in/lbs 4''/145
Water drain ISO 228 G ½''
Condensate drain in/lbs 2''/145
Safety valve - jacket water ISO 228 in/lbs 2x1½''/2.5
Safety valve - hot water in/lbs 2½''/232
Lube oil replenishing (pipe) in 1.1
Lube oil drain (pipe) in 1.1
Jacket water - filling (flex pipe) in 0.5
Intercooler water-Inlet/Outlet 1st stage in/lbs 4''/145
Intercooler water-Inlet/Outlet 2nd stage in/lbs 2½''/145

Output / fuel consumption
ISO standard fuel stop power ICFN bhp 2,509
Mean effe. press. at stand. power and nom. speed psi 290
Fuel gas type Sewage gas | Natural gas
Based on methane number | Min. methane number MN d) 135 | 100 | 94 | 80
Compression ratio Epsilon 12.5
Min. fuel gas pressure for the pre chamber psi 53.6639638
Min./Max. fuel gas pressure at inlet to gas train psi 1.74 - 2.9 c)
Allowed Fluctuation of fuel gas pressure % ± 10
Max. rate of gas pressure fluctuation psi/sec 0.145
Maximum Intercooler 2nd stage inlet water temperature °F 122
Spec. fuel consumption of engine BTU/bhp.hr 5,847 | 5,677
Specific lube oil consumption g/bhp.hr 0.15
Max. Oil temperature °F 176
Jacket-water temperature max. °F 203
Filling capacity lube oil (refill) gal ~ 145
c) Lower gas pressures upon inquiry
d) based on methane number calculation software AVL 3.2

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0.02 Technical data of engine

Manufacturer GE Jenbacher
Engine type J 612 GS-F28
Working principle 4-Stroke
Configuration V 60°
No. of cylinders 12
Bore in 7.48
Stroke in 8.66
Piston displacement cu.in 4,568
Nominal speed rpm 1,500
Mean piston speed in/s 433
Length in 167
Width in 74
Height in 99
Weight dry lbs 20,944
Weight filled lbs 22,708
Moment of inertia lbs-ft² 1345.01
Direction of rotation (from flywheel view) left
Radio interference level to VDE 0875 N
Starter motor output kW 13
Starter motor voltage V 24
Thermal energy balance
Energy input MBTU/hr 14,670 | 14,245
Intercooler MBTU/hr 2,121 | 2,045
Lube oil MBTU/hr 752 | 582
Jacket water MBTU/hr 976 | 1,135
Exhaust gas cooled to 356 °F MBTU/hr 2,393 | 2.019
Exhaust gas cooled to 212 °F MBTU/hr 3,290 | 2,900
Surface heat MBTU/hr 278 | 349
Exhaust gas data
Exhaust gas temperature at full load °F [8] 727 | 677
Exhaust gas mass flow rate, wet lbs/hr 24,368 | 23,888
Exhaust gas mass flow rate, dry lbs/hr 22,864 | 22,440
Exhaust gas volume, wet scfhr 304,560 | 302,520
Exhaust gas volume, dry scfhr 274,560 | 273,660
Max.admissible exhaust back pressure after engine psi 0.725
Combustion air data
Combustion air mass flow rate lbs/hr 22,709 | 23,243
Combustion air volume SCFM 4,692 | 4,802
Max. admissible pressure drop at air-intake filter psi 0.145

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Sound pressure level
Aggregate a) dB(A) re 20µPa 100
31,5 Hz dB 90
63 Hz dB 88
125 Hz dB 100
250 Hz dB 95
500 Hz dB 94
1000 Hz dB 93
2000 Hz dB 91
4000 Hz dB 91
8000 Hz dB 94
Exhaust gas b) dB(A) re 20µPa 116
31,5 Hz dB 104
63 Hz dB 121
125 Hz dB 124
250 Hz dB 116
500 Hz dB 111
1000 Hz dB 110
2000 Hz dB 108
4000 Hz dB 104
8000 Hz dB 86
Sound power level
Aggregate dB(A) re 1pW 122
Measurement surface ft² 1,528
Exhaust gas dB(A) re 1pW 124
Measurement surface ft² 67.60
a) average sound pressure level on measurement surface in a distance of 3.28ft (converted to free field) according to DIN 45635,
precision class 3.

b) average sound pressure level on measurement surface in a distance of 3.28ft according to DIN 45635, precision class 2.
The spectra are valid for aggregates up to bmep=319.083028 psi. (for higher bmep add safety margin of 1dB to all values per
increase of 15 PSI pressure).

Engine tolerance ± 3 dB

0.02.01 Technical data of gearbox
Manufacturer EISENBEISS
Type ~
Gearbox ratio 1:1.2
Efficiency % 99.46
Mass lbs 2,822

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0.03 Technical data of generator
Manufacturer STAMFORD e)
Type MVSI 804 R e)
Type rating kVA 2,441
Driving power bhp 2,496
Ratings at p.f.= 1.0 kW 1,812
Ratings at p.f. = 0.8 kW 1,794
Rated output at p.f. = 0.8 kVA 2,243
Rated reactive power at p.f. = 0.8 kVAr 1,346
Rated current at p.f. = 0.8 A 311
Frequency Hz 60
Voltage kV 4.16
Speed rpm 1,800
Permissible overspeed rpm 2,250
Power factor (lagging - leading) 0,8 - 1,0
Efficiency at p.f.= 1.0 % 97.3%
Efficiency at p.f. = 0.8 % 96.4%
Moment of inertia lbs-ft² 1774.12
Mass lbs 11,228
Radio interference level to EN 55011 Class A (EN 61000-6-4) N
Ik'' Initial symmetrical short-circuit current kA 2.57
Is Peak current kA 6.53
Insulation class H
Temperature rise (at driving power) F
Maximum ambient temperature °F 104

Reactance and time constants (saturated)
xd direct axis synchronous reactance p.u. 1.67
xd' direct axis transient reactance p.u. 0.16
xd'' direct axis sub transient reactance p.u. 0.12
x2 negative sequence reactance p.u. 0.17
Td'' sub transient reactance time constant ms 15
Ta Time constant direct-current ms 91
Tdo' open circuit field time constant s 4.00
e) GE Jenbacher reserves the right to change the generator supplier and the generator type. The contractual data of the
generator may thereby change slightly. The contractual produced electrical power will not change.

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0.04 Technical data of heat recovery
General data - Hot water circuit
Total recoverable thermal output MBTU/hr 2,594 | 2,572
Return temperature °F 170.0
Forward temperature °F 186.0 | 185.9
Hot water flow rate GPM 324.2
Design pressure of hot water lbs 145
min. operating pressure psi 51.0
max. operating pressure psi 131.0
Pressure drop hot water circuit psi 15.23
Maximum Variation in return temperature °F +0/-21
Max. rate of return temperature fluctuation °F/min 18

General data - Cooling water circuit
Heat to be dissipated MBTU/hr 1,255 | 1,190
Return temperature °F 122
Cooling water flow rate GPM 110
Design pressure of cooling water lbs 145
min. operating pressure psi 7.0
max. operating pressure psi 73.0
Loss of nominal pressure of cooling water psi ~
Maximum Variation in return temperature °F +0/-21
Max. rate of return temperature fluctuation °F/min 18

The final pressure drop will be given after final order clarification and must be taken from the P&ID order documentation.

100% Biogas Thermal Connection Variant K

100% Natural Gas Thermal Connection Variant K

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0.10 Technical parameters

The following “Technical Instruction (TI) of GE JENBACHER” form an integral part of the contract and must
be strictly observed:

TI 1100-0110 – Boundary Conditions for GE Jenbacher Gas Engines
TI 1100-0111 – General Conditions – Operation and Maintenance
TI 1100-0112 – Installation of GE Jenbacher Units

These Technical Instructions reference other guides and instructions which can be provided upon request.
These should be reviewed carefully by all personnel involve d with the application, installation, and
maintenance of any GE Jenbacher gas engine.

All data in the technical specification are based on engine full load (unless stated otherwise) at specified
temperatures as well as the methane number and subject to technical development and modifications. For
isolated operation an output reduction may apply according to the block load diagram. Before being able to
provide exact output numbers, a detailed site load profile needs to be provided (motor starting curves, etc.).

All pressure indications are to be measured and read with pressure gauges (psig).

(1) At nominal speed and standard reference conditions ICFN according to DIN-ISO 3046 and DIN 6271,
respectively
(2) According to DIN-ISO 3046 and DIN 6271, respectively, with a tolerance of + 5 %.
Efficiency performance is based on a new unit (immediately upon commissioning).Effects of degradation
during normal operation can be mitigated through regular service and maintenance work.
(3) Average value between oil change intervals according to maintenance schedule, without oil change
amount
(4) At p. f. = 1.0 according to VDE 0530 REM / IEC 34.1 with relative tolerances
(5) Total output with a tolerance of +/- 8 %
(6) According to above parameters (1) through (5)
(7) Only valid for engine and generator; module and peripheral equipment not considered (at p. f. = 0.8)
(8) Exhaust temperature with a tolerance of +/- 8 %
(9) Intercooler heat on:
* standard conditions (Vxx) - If the turbocharger design is done for air intake temperature > 86°F w/o de-
rating, the intercooler heat of the 1st stage need to be increased by 2%/K starting from 77°F. Deviations
between 77 – 86°F will be covered with the standard tolerance.
* Hot Country application (Vxxx) - If the turbocharger design is done for air intake temperature > 104°F
w/o de-rating, the intercooler heat of the 1st stage need to be inc reased by 2%/K starting from 95°F.
Deviations between 95 – 104°F will be covered with the standard tolerance.

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Definition of output
 ISO-ICFN continuous rated power:
Net break power that the engine manufacturer declares an engine is capable of delivering continuously, at
stated speed, between the normal maintenance intervals and overhauls as required by the manufacturer.
Power determined under the operating conditions of the manufacturer’s test bench and adjusted to the
standard reference conditions.

 Standard reference conditions:
Barometric pressure: 14.5 psi (1000 mbar) or 328 ft (100 m) above sea level
Air temperature: 77°F (25°C) or 298 K
Relative humidity: 30 %

 Volume values at standard conditions (fuel gas, combustion air, exhaust gas)
Pressure: 1 atmosphere (1013.25 mbar)
Temperature: 32°F (0°C)

Output adjustment for turbo charged engines
The ratings in the specification are valid for full load operation at a site installation of 4240 ft (1292 m) and an
air intake temperature of T1 < 95 F (35 C). At T1 > 95 F (35 C), an output deration of 1.11%/F (2.0%/C) will
occur.

Radio interference level
The ignition system of the gas engines complies the radio interference levels of CISPR 12 and EN 55011
class B, (30-75 MHz, 75-400 MHz, 400-1000 MHz) and (30-230 MHz, 230-1000 MHz), respectively.

Parameters for the operation of GE Jenbacher gas engines

Maximum room temperature: 122°F (T2) -> engine stop

If the actual methane number is lower than the specified, the knock control responds. First the ignition timing
is changed at full rated power. Secondly the rated power is reduced. These functions are carried out by the
engine management.

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Operation of Voltage and frequency outside of stated li mits for the generator as per IEC 60034-1 Zone A will
result in a power de-rate up to and including tripping of the equipment.

The generator set fulfills the limits for mechanical vibrations according to ISO 8528-9.
If possible, railway trucks must not be used for transport (TI 1000-0046).

Parameters for the operation of control unit and the electrical equipment

Relative humidity: 50%
Maximum temperature: 40°C.
Altitude: <2000m above the sea level.
The gas quantity indicated under the technical data ref ers to standard conditions with the given calorific
value. The actual volume flow (under operating conditions) has to be considered for dimensioning the gas
compressor and each gas feeding component – it will be affected by:
 Actual gas temperature (limiting temperature according to TI 1000-0300)
 Gas humidity (limiting value according to TI 1000-0300)
 Gas Pressure
 Biogas is based on 60% CH4, 40% CO2 unless otherwise detailed.

1.00 Scope of supply - Module
Design:
The module is built as a compact package. The engine base is bolted to the gearbox/generator base.
The Engine output shafting is connected through a coupling to a gearbox. A second coupling is then
provided connecting the gearbox to the generator. To provide the best possible isolation from the
transmission of vibrations, the engine rests on the engine base -frame by means of anti-vibration mounts. The
remaining vibrations are eliminated by mounting the complete module (engine and gearbox/generator
frames) on isolating pads (e.g. Sylomer). This, in principle, allows for placing of the module to be directly on
any floor capable of carrying the static load. No special foundation is required. Prevention of sound
conducted through solids has to be provided locally.

1.01 Spark ignited gas engine
Four-stroke, air/gas mixture turbocharged, aftercooled, with high performance ignition system and
electronically controlled air/gas mixture system.
The engine is equipped with the most advanced

LEANOX® LEAN-BURN COMBUSTION SYSTEM

developed by GE JENBACHER.

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1.01.01 Engine design (Air Start)
Engine block
Single-piece crankcase and cylinder block made of special casting; crank case covers for engine inspection,
welded steel oil pan.

Crankshaft and main bearings
Drop-forged, precision ground, surface hardened, statically and dynamically balanced; main bearings (upper
bearing shell: grooved bearing / lower bearing shell: sputter bearing) arranged between crank pins, drilled oil
passages for forced-feed lubrication of connecting rods.

Vibration damper
Maintenance free viscous damper

Flywheel
With ring gear for starter motor and additionally screwed on.

Pistons
Single-piece made of steel, with piston ring carrier and oil passages for cooling; piston rings made of high
quality material, main combustion chamber specially designed for lean burn operation.

Connecting rods
Drop-forged, heat-treated, big end diagonally split and toothed. Big end bearings (upper bearing shell: sputter
bearing / lower bearing shell: sputter bearing) and connecting rod bushing for piston pin.

Cylinder liner
Chromium alloy gray cast iron, wet, individually replaceable.

Cylinder head
Specially designed and developed for GE JENBACHER-lean burn engines with optimized fuel consumption
and emissions; water cooled, made of special casting, individually replaceable; Valve seats and valve guides
and spark plug sleeves individually replaceable; exhaust and inlet valve made of high quality material; Pre-
chamber with check-valve.

Crankcase breather
Connected to combustion air intake system

Valve train
Camshaft, with replaceable bushings, driven by crankshaft through intermediate gears, valve lubrication by
splash oil through rocker arms.

Combustion air/fuel gas system
Motorized carburetor for automatic adjustment according fuel gas characteristic. Exhaust driven turbocharger,
mixture manifold with bellows, water-cooled intercooler, throttle valve and distribution manifolds to cylinders.

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Ignition system
Most advanced, fully electronic high performance ignition s ystem, external ignition control.
MORIS: Automatically, cylinder selective registration and control of the current needed ignition voltage.

Lubricating system
Gear-type lube oil pump to supply all moving parts with filtered lube oil, pressure control valv e, pressure relief
valve and full-flow filter cartridges. Cooling of the lube oil is arranged by a heat exchanger.

Engine cooling system
Jacket water pump complete with distribution pipework and manifolds.

Exhaust system
Turbocharger and exhaust manifold

Exhaust gas temperature measuring
Thermocouple for each cylinder

Electric actuator
For electronic speed and output control

Electronic speed monitoring for speed and output control
By magnetic inductive pick up over ring gear on flywheel

Air Starter motor
Engine mounted air starter motor

1.01.02 Additional equipment for the engine (spares for commissioning)
The initial set of equipment with the essential spare parts for operation after commiss ioning is included in the
scope of supply.

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1.01.03 Engine accessories
Insulation of exhaust manifold:
Insulation of exhaust manifold is easily installed and removed

Sensors at the engine:
 Jacket water temperature sensor
 Jacket water pressure sensor
 Lube oil temperature sensor
 Lube oil pressure sensor
 Mixture temperature sensor
 Charge pressure sensor
 Minimum and maximum lube oil level switch
 Exhaust gas thermocouple for each cylinder
 Knock sensors
 Gas mixer / gas dosing valve position reporting.

Actuator at the engine:
 Actuator - throttle valve
 Bypass-valve for turbocharger
 Control of the gas mixer / gas dosing valve

1.01.04 Standard tools (per installation)
The tools required for carrying out the most important maintenance work are included in the scope of supply
and delivered in a toolbox.

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1.02 Generator-Medium Voltage

The 2 bearing generator consists of the main generator (built as rotating field machine), the exciter
machine (built as rotating armature machine) and the digital excitation system.
The digital regulator is powered by an auxiliary winding at the main stator or a PMG system

Main components:
 Enclosure of welded steel construction
 Stator core consist of thin insulated electrical sheet metal with integrated cooling channels.
 Stator winding with 5/6 Pitch
 Rotor consist of shaft with shrunken laminated poles, Exciter rotor, PMG (depending on Type) and fan.
 Damper cage
 Excitation unit with rotating rectifier diodes and overvoltage protection
 Dynamically balanced as per ISO 1940, Balance quality G2,5
 Drive end bracket with re greaseable antifriction bearing
 Non-drive end bracket with re grease antifriction bearing
 Cooling IC01 - open ventilated, air entry at n on-drive end, air outlet at the drive end side
 Main terminal box includes main terminals for power cables
 Regulator terminal box with auxiliary terminals for thermistor connection and regulator.
 Anti-condensation heater
 3 PT100 for winding temperature monitoring+3 PT100 Spare
 2 PT100 for bearing temperature monitoring
 Current transformer for protection and measuring in the star point
xx/1A, 10P10 15VA , xx/1A, 1FS5, 15VA

Electrical data and features:
 Standards: IEC 60034, EN 60034, VDE 0530, ISO 8528-3, ISO 8528-9
 Voltage adjustment range: +/- 10 % of rated voltage (continuous)
 Frequency: -6/+4% of rated frequency
 Overload capacity: 10% for one hour within 6 hours, 50% for 30 seconds
 Asymmetric load: max. 8% I2 continuous, in case of fault I2 x t=20
 Altitude: < 1000m
 Max permitted generator intake air temperature: 5°C - 40°C
 Max. relative air humidity: 90%
 Voltage curve THD Ph-Ph: <3% at idle operation and <3% at full load operation with linear symmetrical
load
 Generator suitable for parallel operating with the grid and other generators
 Sustained short circuit current at 3-pole terminal short circuit: minimum 3 times rated current for 5 seconds.
 Over speed test with 1.2 times of rated speed for 2 minutes according to IEC 60034

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Digital Excitation system ABB Unitrol 1010 mounted within the AVR Terminal box with following
features:

 Compact and robust Digital Excitation system for Continuous output current up to 10 A (20A Overload
current 10s)
 Fast AVR response combined with high excitation voltage improves the transient stability during LVRT
events.
 The system has free configurable measurement and analog or digital I/Os. The configuration is done via the
local human machine interface or CMT1000
 Power Terminals
3 phase excitation power input from PMG or auxiliary windings
Auxiliary power input 24VDC
 Excitation output
 Measurement terminals: 3 phase machine voltage, 1 phase network voltage, 1 phase machine current
 Analog I/Os: 2 outputs / 3 inputs (configurable), +10 V / -10 V
 Digital I/O: 4 inputs only (configurable), 8 inputs / outputs (configurable)
 Serial fieldbus: RS485 for Modbus RTU or VDC (Reactive power load sharing for up to 31 GEJ engines in
island operation), CAN-Bus for dual channel communication
 Regulator Control modes: Bump less transfer between all modes
Automatic Voltage Regulator (AVR) accuracy 0,1% at 25°C ambient temperature
Field Current Regulator (FCR)
Power Factor Regulator (PF)
Reactive Power Regulator (VAR)
 Limiters: Keeping synchronous machines in a safe and stable operation area
Excitation current limiter (UEL min / OEL max)
PQ minimum limiter
Machine current limiter
V / Hz limiter
Machine voltage limiter
 Voltage matching during synchronization
 Rotating diode monitoring
 Dual channel / monitoring: Enables the dual channel operation based on self -diagnostics and setpoint
follow up over CAN communication. As Option available
 Power System Stabilizer (PSS) is available as option. Compliant with the standard IEEE 421.5 -2005 2A /
2B, the PSS improves the stability of the generator over the highest possible operation range.
 Computer representation for power s ystem stability studies: ABB 3BHS354059 E01
 Certifications: CE, cUL certification according UL 508c (compliant with CSA), DNV Class B,

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 Commissioning and maintenance Tool CMT1000 (for trained commissioning/ maintenance personal)
 With this tool the technician can setup all parameters and tune the PID to guarantee stable operation. The
CMT1000 software allows an extensive supervision of the system, which helps the user to identify and
locate problems during commissioning on site. The CMT1000 is connected to the target over USB or
Ethernet port, where Ethernet connection allows remote access over 100 m.
 Main window
 Indication of access mode and device information.
 Change of parameter is only possible in CONTROL access mode.
 LED symbol indicates that all parameter are stored on none volatile memory.
 Setpoint adjust window
 Overview of all control modes, generator status, active limiters status and alarms.
 Adjust set point and apply steps for tuning of the PID.
 Oscilloscope
 4 signals can be selected out of 20 recorded channels. The time resolution is 50 ms.Save files to your PC
for further investigation.
 Measurement
 All measurements on one screen.

Routine Test
Following routine tests will be carried out by the generator manufacturer
 Measuring of the DC-resistance of stator and rotor windings
 Check of the function of the fitted components (e.g. RTDs, space heater etc.)
 Insulation resistance of the following components
Stator winding, rotor winding
Stator winding RTDs
Bearing RTDs
Space heater
 No Load saturation characteristic (remanent voltage)
 Stator voltage unbalance
 Direction of rotation, phase sequence
 High voltage test of the stator windings (2 x Unom. + 1000 V) and the rotor windings (min. 1500 V)

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1.03 Module Accessories
Base frame
Split Base Frame fabricated with welded structural steel. First frame to mount the engine, jacket water heat
exchangers, pumps and engine auxiliaries, the second to mount the gearbox and generator.

Coupling #1
Engine to Gearbox coupling is provided. The coupling isolates the major sub-harmonics of engine alternating
torque from gear box.

Coupling #2
Gearbox to Generator Coupling is provided. This coupling is designed with a torque limiter to couple gear
box with alternator.

Coupling housings
Provided for both Couplings

Anti-vibration mounts
2 sets of isolation, one is arranged between engine block assembly and base frame. The second is via
insulating pads (SYLOMER) for placement between base frame and foundation, delivered loose.

Gear box:
A Single-stage spur gear with overhead shaft and closed loop lube oil system, completely mounted on the
gearbox/generator base frame. The lube oil heat exchanger is integrated with the warm/cooling water circuit.
The gear transmission ratio is 1:1.2. Oil volume is approximately 52 gals (196 liters).

Exhaust gas connection
A flanged connection is provided that collects the exhaust gas turbocharger output flows, inc ludes flexible
pipe connections (compensators) to compensate for heat expansions and vibrations.

Combustion air filter
A Dry type air filter with replaceable filter cartridges is fitted. The assembly includes flexible connections to
the fuel mixer/carburetor and service indicator.

Interface panel (M1 cabinet)
Totally enclosed sheet steel cubicle with hinged doors, pre-wired to terminals, ready to operate. All Cable
entry will be via bottom mounted cable gland plates.

Painting: RAL 7035

Protection: External NEMA 3 (IP 54), Internal IP 20 (protection against direct contact with live parts)

Cabinet design is according to IEC 439-1 (EN 60 439-1/1990) and DIN VDE 0660 part 500, respectively.
Ambient temperature 41 - 104 °F (5 - 40 °C), Relative humidity 70%

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Dimensions:
 Height: 51 in - 82 in (1300 mm-2100 mm)
 Width: 40 in - 47 in (1000 mm -1200 mm)
 Depth: 16 in - 24 in (400 mm-600 mm)

Control Power Source: The starter batteries and the cabinet mounted battery chargers will provide the power
source for this enclosure.

Interface Panel contents and control functions:
 The cabinet houses the unit Battery Charger and primary 24VDC Control Power Distribution (breakers,
fuses, and terminals) from the unit Batteries
 Distributed PLC Input and Output cards, located in the cabinet, gather all Engine, Gearbox and Generator
Control I/O. These cards transmit data via data bus interface to the central engine control of the module
control panel located in the A1 cabinet. Data bus is via CAN and B&R Proprietary Data Highw ay (Data
Cables provided by GE)
 Speed monitoring relays for protection are provided.
 Gas Train I/O Collection, including interface relays and terminals for gas train shutoff valves.
 Transducer for generator functions, such as excitation voltage.
 Door Mounted Emergency Stop Switch with associated Emergency Stop Loop interface relays.
 Miscellaneous control relays, contacts, fuses, etc. for additional control valves, and auxiliaries.
 Interface Terminal Strips

Skid Mounted 3 Phase Devices are Powered by 3 x 480/277 V, 60 Hz, 50 A

AC Power for engine mounted auxiliaries (heater, pumps, etc.) are routed through a separate J -box mounted
on the side M1 cabinet (Box E1). This is done to maintain signal segregation (AC from control)

NOTE: Generator Current Transformer wiring is connected directly to the Generator and does NOT
pass through the M1 cabinet.

Exhaust gas scavenging blower
An exhaust gas scavenging blower is used to scavenge the remaining exhaust gas out of the exhaust gas
pipe work, to prevent the appearance of deflagrations.

Function:
Before each start scavenging by blower is done for app. 1 minute (except at black out – start)

Supervisions:
 Scavenging air fan failure
 Scavenging air flap failure

Consisting of:
 Fan
 Exhaust gas flap
 Temperature switch
 Compensator and pipe work

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1.03.01 Engine jacket water system
Engine jacket water system
Closed cooling circuit, consisting of:
 Expansion tank
 Filling device (check and pressure reducing valves, pressure gauge)
 Safety valve(s)
 Thermostatic valve
 Required pipework on module
 Vents and drains
 Electrical jacket water pump, including check valve
 Jacket water preheat device

1.03.02 Automatic lube oil replenishing system incl. extension tank
Automatic lube oil replenishing system:
Includes float valve in lube oil feed line, including inspection glass. Electric monitoring system will be provided
for engine shut-down at lube oil levels "MINIMUM" and "MAXIMUM". Solenoid valve in oil feed line is only
activated during engine operation. Manual override of the solenoid valve, for filling procedure during oil
changes is included.

Oil drain
By set mounted cock

Oil sump extension tank (delivered loose) 79.3 gal
To increase the time between oil changes

Pre-lubrication- and aftercooling oil pump:
Mounted on the module base fram e; it is used for pre-lubrication and aftercooling of the turbochargers.
Period of operation: Pre-lubrication: 1 minute both pumps
Aftercooling: 15 minutes from engine stop only the 480/277 V pump
Consisting of:
 1 piece oil pump 1500 W, 480/277 V
 1 piece oil pump 1500 W, 24 V
 All necessary vents
 Necessary pipework

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1.04 Heat recovery
Engine-mounted intercooler and lube oil heat exchanger; jacket water heat exchanger mounted to the engine
res. to the module base frame, complete with interconnecting pipe work.
The exhaust gas heat exchanger is mounted to the heat recovery module.
The insulation of heat exchangers and pipework is not included in GE Jenbacher scope of supply.

Heat exchanger - air/fuel mixture to warm water (intercooler)
The engine-mounted intercooler is of two stage design. The first stage is integrated with the warm water
circuit. The second stage requires low temperature water.

Heat exchanger - lube oil to water
The engine mounted lube oil heat exchanger is not integrated. The heat must be taken away by a separate
cooling circuit.

Heat exchanger - engine jacket water to warm water
Mounted to module base frame complete with interconnecting pipe work, for recovery of engine jacket water
heat.

1.05a Gas train (Biogas)
Pre-assembled, delivered loose, for installation into gas pipework to the engine.

Consisting of:
 Main Biogas gas train:
 Manual shut off valve
 Gas filter, filter to <3 µm
 Adapter with dismount to the pre-chamber gas train
 Gas admission pressure regulator
 Pressure gauge with push button valve; 0-7.25 psi (0-500 mbar)
 Solenoid valves
 Gas pressure switch (min.)
 Leakage detector
 Gas pressure regulator
 TEC JET (has to be implemented horizontal)

The gas train complies with DIN - DVGW regulations.

Maximum distance from TEC JET outlet to gas entry on engine, including flexible connections, is 39.37 in (1
m). Reference GE Jenbacher Technical Instruction TI 1510-0064 for Tec Jet and Gas Train installation
details

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1.05b Gas train (Natural Gas)
Pre-assembled, delivered loose, for installation into gas pipework to the engine.

Consisting of:
 Main Natural Gas train:
 Manual shut off valve
 Gas filter, filter to <3 µm
 Adapter with dismount to the pre-chamber gas train
 Gas admission pressure regulator
 Pressure gauge with push button valve; 0-7.25 psi (0-500 mbar)
 Solenoid valves
 Gas pressure switch (min.)
 Leakage detector
 Gas pressure regulator
 TEC JET (has to be implemented horizontal)

The gas train complies with DIN - DVGW regulations.

Maximum distance from TEC JET outlet to gas entry on engine, including flexible connections, is 39.37 in (1
m). Reference GE Jenbacher Technical Instruction TI 1510-0064 for Tec Jet and Gas Train installation
details

1.05c Pre-chamber Gas train (Natural Gas)
Pre-assembled, delivered loose, for installation into gas pipework to the engine.

Consisting of:
 Pre-chamber gas train:
 Manual shut off valve
 Gas filter, filter fineness <3 µm
 Solenoid valves
 Pressure regulator
 Calming distance with reducer
 Pressure gauge with push button valve; 0-72.5 psi (1-5 bar)

Pre chamber gas pressure regulator (incl. stabilization section) assembled at the flexible connection pre
chamber gas.

Use of fuel other than Natural Gas in Prechamber to be noted.

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1.07 Painting
 Quality: Oil resistant prime layer
Synthetic resin varnish finishing coat

 Color: Engine: RAL 6018 (green)
Base frame: RAL 6018 (green)
Generator: RAL 6018 (green)
Module interface
panel: RAL 7035 (light grey)
Control panel: RAL 7035 (light grey)

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1.11 Engine generator control panel per module- Dia.ne XT4 incl. Single
synchronization of the generator breaker
Dimensions:
 Height: 87 in (including 8 in pedestal *)
 Width: 32 -48 in*)
 Depth: 24 in *)

Protection class:
 external IP42
 Internal IP 20 (protection again direct contact with live parts)

*) Control panels will be dimensioned on a project specific basis. Actual dimensions will be provided i n the
preliminary documentation for the project.

Control supply voltage from starter and control panel batteries: 24V DC

Auxiliaries power supply: (from provider of the auxiliary supply)
3 x 480/277 V, 60 Hz

Consisting of:
Motor - Management - System DIA.NE

Setup:
 a) Touch display visualization
 b) Central engine and unit control

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Touch Display Screen:

15“ Industrial color graphic display with resistive touch.

Interfaces:
 24V voltage supply
 VGA display connection
 USB interface for resistive touch

Protection class of DIA.NE XT panel front: IP 65
Dimensions: W x H x D = approx. 16x12x3in

The screen shows a clear and functional summary of the measurement values and simul taneously shows a
graphical summary.

Operation is via the screen buttons on the touch screen
Numeric entries (set point values, parameters…) are entered on the touch numeric pad or via a scroll bar.
Determination of the operation mode and the method of synchronization via a permanently displayed button
panel on the touch screen.

Main screens (examples):

Main: Display of the overview, auxiliaries status, engine start and operating data.

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ELE: Display of the generator connection with electrical measurement values and synchronization status

OPTION: Generator winding and bearing temperature
Trending
Trend with 100ms resolution

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Measurement values:
 510 data points are stored
 Measurement interval = 100ms
 Raw data availability with 100ms resolution: 24 hours + max. 5.000.000 changes in value at shut down
(60 mins per shut down)
 Compression level 1: min, max, and average values with 1000ms resolution: 3 days
 Compression level 2: min, max, and average values with 30s resolution: 32 days
 Compression level 3: min, max, and average values with 10min resolution: 10 years

Messages:
10.000.000 message events

Actions (operator control actions):
1.000.000 Actions

System messages:
100.000 system messages

Central engine and module control:

An industrial PC- based modular industrial control system for module and engine sequencing control (start
preparation, start, stop, aftercooling and control of auxiliaries) as well as all control functions.

Interfaces:
 Ethernet (twisted pair) for remote monitoring access
 Ethernet (twisted pair) for connection between engines
 Ethernet (twisted pair) for the Powerlink connection to the control input and output modules.
 USB interface for software updates

Connection to the local building management system according t o the GE Jenbacher option list
(OPTION)
 MODBUS-RTU Slave
 MODBUS-TCP Slave,
 PROFIBUS-DP Slave (160 words),
 PROFIBUS-DP Slave (190 words),
 ProfiNet
 OPC

Control functions:
 Speed control in idle and in island mode
 Power output control in grid parallel operation, or according to an internal or external set point value on a
case by case basis
 LEANOX control system which controls boost pressure according to the power at the generator terminals,
and controls the mixture temperature according to the engine driven air-gas mixer

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 Knocking control: in the event of knocking detection, ignition timing adjustment, power reduction and
mixture temperature reduction (if this feature is installed)
 Load sharing between engines in island mode operation (option)
 Linear power reduction in the event of excessive mixture temperature and misfiring
 Linear power reduction according to CH4 signal (if available)
 Linear power reduction according to gas pressure (option)
 Linear power reduction according to air intake temperature (option )

Multi-transducer to record the following alternator electrical values:
 Phase current (with slave pointer))
 Neutral conductor current
 Voltages Ph/Ph and Ph/N
 Active power (with slave pointer)
 Reactive power
 Apparent power
 Power factor
 Frequency
 Active and reactive energy counter

Additional 0 (4) - 20 mA interface for active power as well as a pulse signal for active energy

The following alternator monitoring functions are integrated in the multi-measuring device:
 Overload/short-circuit [51], [50]
 Over voltage [59]
 Under voltage [27]
 Asymmetric voltage [64], [59N]
 Unbalance current [46]
 Excitation failure [40]
 Over frequency [81>]
 Under frequency [81<]

Lockable operation modes selectable via touch screen:
 "OFF" operation is not possible, running units will shut down immediately;
 "MANUAL" manual operation (start, stop) possible, unit is not available for fully automatic
operation.
 "AUTOMATIC" fully automatic operation according to external demand signal:

Demand modes selectable via touch screen:
 external demand off („OFF“)
 external demand on („REMOTE“)
 overide external demand („ON“)

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Malfunction Notice list:

Shut down functions e.g.:
 Low lube oil pressure
 Low lube oil level
 High lube oil level
 High lube oil temperature
 Low jacket water pressure
 High jacket water pressure
 High jacket water temperature
 Overspeed
 Emergency stop/safety loop
 Gas train failure
 Start failure
 Stop failure
 Engine start blocked
 Engine operation blocked
 Misfiring
 High mixture temperature
 Measuring signal failure
 Overload/output signal failure
 Generator overload/short circuit
 Generator over/undervoltage
 Generator over/underfrequency
 Generator asymmetric voltage
 Generator unbalanced load
 Generator reverse power
 High generator winding temperature
 Synchronizing failure
 Cylinder selective Knocking failure

Warning functions e.g.:
 Cooling water temperature min.
 Cooling water pressure min.
 Generator winding temperature max.

Remote signals:
(volt free contacts)
1NO = 1 normally open
1NC = 1 normally closed
1COC = 1 change over contact

 Ready for automatic start (to Master control) 1NO
 Operation (engine running) 1NO
 Demand auxiliaries 1NO
 Collective signal "shut down" 1NC

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 Collective signal "warning" 1NC

External (by others) provided command/status signals:
 Engine demand (from Master control) 1S
 Auxiliaries demanded and released 1S

Single synchronizing Automatic

For automatic synchronizing of the module with the generator circuit breaker to the grid by PLC - technology,
integrated within the module control panel.

Consisting of:
 Hardware extension of the programmable control for fully automatic synchronization selection and
synchronization of the module and for monitoring of the generator circuit breaker closed signal.
 Lockable synchronization selection via touch screen with the following selection modes:
 "MANUAL" Manual initiation of synchronization via touch screen button followed by fully
automatic synchronization of the module
 "AUTOMATIC" Automatic module synchronization, after synchronizing release from the module
control
 "OFF" Selection and synchronization disabled
Control of the generator circuit breaker according to the synchronization mode select ed via touch
screen.
 "Generator circuit breaker CLOSED/ Select" Touch-button on DIA.NE XT
 "Generator circuit breaker OPEN" Touch-button on DIA.NE XT

Status signals:
Generator circuit breaker closed
Generator circuit breaker open

Remote signals:
(volt free contacts)
Generator circuit breaker closed 1 NO

The following reference and status signals must be provided by the switchgear supplier:

 Generator circuit breaker CLOSED 1 NO
 Generator circuit breaker OPEN 1 NO
 Generator circuit breaker READY TO CLOSE 1 NO
 Mains circuit breaker CLOSED 1 NO
 Mains circuit breaker OPEN 1 NO

Mains voltage 3 x 4160V or 3x 110V/v3 - other measurement voltages available on request
Bus bar voltage 3 x 4160 V or 3x 110V/v3 – other measurement voltages available on request
Generator voltage 3 x 4160 V or 3x 110V/v3 – other measurement voltages available on request

Voltage transformer in the star point with minimum 50VA and Class 0,5

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The following volt free interface-signals will be provided by GE Jenbacher to be incorporated in
switchgear:

 CLOSING/OPENING command for generator circuit breaker
(permanent contact) 1 NO + 1 NC
 Signal for circuit breaker undervoltage trip 1 NO

Maximum distance between module control panel and engine/interface panel: 99ft
Maximum distance between module control panel and power panel: 164ft
Maximum distance between module control panel and master control panel: 164ft
Maximum distance between alternator and generator circuit breaker: 99ft

1.11.01 Remote messaging over MODBUS-TCP
Data transfer from the Jenbacher module control system to the customer's on -site central control system via
MODBUS TCP using the ETHERNET 10 BASE-T/100BASE-TX protocol TCP/IP.

The Jenbacher module control system operates as a SLAVE unit.
The data transfer via the customer's MASTER must be carried out in cycles.

Data transmitted:
Individual error messages, operational messages, measured values for generator power, o il pressure, oil
temperature, cooling water pressure, cooling water temperature, cylinder and collective exhaust gas
temperatures.

GE Jenbacher limit of supply:
RJ45 socket at the interface module in the module control cabinet

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1.11.06 Remote Data-Transfer with DIA.NE XT4
General
DIA.NE XT4 offers remote connection with Ethernet.

Applications:

1.) DIA.NE XT4 HMI
DIA.NE XT4 HMI is the human-machine-interface of DIA.NE XT4 engine control and visualization system for
GE Jenbacher gas engines.
The system offers extensive facilities for commissioning, monitoring, servicing and analysis of the site.
By installation of the DIA.NE XT4 HMI client program it can be used to establish connection to site, if
connected to a network and access rights are provided.
The system runs on Microsoft Windows Operating systems (Windows XP, Windows 7, Windows 8)

Function
Functions of the visualization system at the engine control panel can be used remotely. These are among
others control and monitoring, trend indications, alarm management, parameter management, and access to
long term data recording. By providing access to multiple systems, also with multiple clients in parallel,
additional useful functions are available like multi-user system, remote control, print and export functions and
data backup.DIA.NE XT4 is available in several languages.

Option - Remote demand/blocking

If the service selectors switch at the module control panel is in pos."Automatic" and the demand -selector
switch in pos."Remote", it is possible to enable (demanded) or disable (demand off) the module wit h a control
button at the DIA.NE XT4 HMI
Note:
With this option it makes no sense to have an additional clients demand (via hardware or data bus)
or a self-guided operation (via GE Jenbacher master control, grid import /export et c.).

Option - Remote - reset (see TA-No. 1100-0111 chapter 1.7 an d1.9)

Scope of supply
 Software package DIA.NE XT4 HMI Client Setup (Download)
 Number of DIA.NE XT4 HMI - Client user license (Simultaneous right to access of one user to the
engine control)

Nr. of license Access
1 1 Users can be logged in at the same time with a PC
(Workplace, control room or at home).
2 - “n“ (Optional) 2- “n” Users can be logged in at the same time with a PC
(Workplace, control room or at home).
If 2- “n” users are locally connected at Computers from office
or control room, then it is not possible to log in from home.

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Caution! This option includes the DIA.NE XT4 HMI client application and its license only – NO secured,
encrypted connection will be provided by GE Jenbacher! A secured, en crypted connection – which is
mandatory – has to be provided by the customer (via LAN connection or customer-side VPN), or can be
realized by using option myPlant™.

Customer requirements
 Broad band network connection via Ethernet(100/1000BASE-TX) at RJ45 Connector (ETH3) at
DIA.NE XT4 server inside module control panel
 Standard PC with keyboard, mouse or touch and monitor (min. resolution 1024*768)
 Operating system Windows XP, Windows 7, Windows 8
 DirectX 9.0 c compatible or newer 3D display adapter wit h 64 MB or higher memory

2.) myPlant™

myPlant™ is the GE Jenbacher remote monitoring and diagnostic (RM&D) service

Offering Feature Connect Protect
Asset
Management
Online data transfer 
Big Data cloud storage 
Engine status visibility 
Control alarms visibility 
Basic data trends 
Remote access to DIA.NE HMI - 
Unlimited data trending - 
Advanced diagnostics - 
WINSERVER Protection Plan - 
Fleet
Management
Fleet status on world map - 
Fleet summaries and reporting - 
Mobility SMS/Email notifications - 
Smartphone app 

Web application with following features:
 Visualization of the current state of the engine (available, in operation, fault)
 View of various readings of the Gen-set
 Visualization of counts as a trend graph (if plant available online, or by manually entering of the counter
readings)
 Trend graph of the performance value (low resolution; only if system available online)

myPlant™ Connect is free of charge for registered customers
myPlant™ Protect is free of charge within the warranty period and is also included as part of any contractual
service agreement (CSA).

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Scope of supply
 Access to myPlant™ Discovery version for up to 4 users
 Connection between plant server and myPlant™ system

Customer requirements
 Permanent Internet line (wired or mobile, (see option 4))
 See technical instruction TA 2300-0008
 Outbound data connectivity (from plant server to Internet) ONLY – INBOUND connections must NOT
be allowed!

CAUTION!
It is in the responsibility of the customer to prevent direct access from the Internet to the plant server using
technical equipment like firewalls.
GE Jenbacher does not provide such security devices and services as part of this option!

3.) myPlant™ notification service

Automatic alarm notification system for myPlant™ - enabled DIA.NE XT systems (all versions).

Function
 Automatic transfer of engine messages to the customer via email or SMS in case of engine trip, engine
start/stop or connectivity loss.

Scope of supply
 Feature of myPlant™ web portal

Customer requirements
 Engine must be connected to the myPlant™ system via Internet connection

myPlant™ notification is free of charge within the warranty period and is also included as part of any
contractual service agreement (CSA).

4.) Mobile Internet (OPTION)
Connection Plant - Customer via secured Internet - connection
See also technical instruction TA 2300 - 0006

Scope of delivery
 Mobile Internet router with antenna to connect to the DIA.NE Server XT4

Customer requirements
 SIM card for 3G / 4G

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5.) Network overview

For information only!

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1.11.14 Generator Overload / Short Circuit Protection
ANSI Function Code 50/51

Digital protection relay, 3-phase, integrated into the module control panel.
Connected to the protective current transformers in the generator star point
Acting on the generator circuit breaker and on the generator de-excitation
Alarm message on the DIA.NE screen

Characteristics / settings:
 Setting for overload: to 1,1 times of the generating set rated current,
 Dependent time characteristic acc. to IEC 60255-151: very inverse, time multiplier setting 0,6.
 Setting for short circuit: to 2,0 times of generating set rated current,
 Independent time characteristic: 300 ms (800 ms when dynamic network support).

1.11.15 Generator Differential Protection
ANSI function code 87

Digital protection relay, 3-phase, integrated into the module control panel.
Connected to the protective current transformers in the generator star point (GEJ scope of supply) and to the
protective current transformers in the generator circuit breaker panel (current transformers by client,
secondary 1A, optionally: 5A).
Acting on the generator circuit breaker and on the generator de-excitation
Alarm message on the DIA.NE screen

In plants with a unit generator-transformer configuration the protection is realized as generator/transformer
differential protection.

1.11.16 Generator Earth Fault Protection (nondirectional)
Digital protection relay, integrated into the module control panel.
Acting on the generator circuit breaker and on the generator de-excitation
Alarm message on the DIA.NE screen

Dependent on the generator grounding method one of the following protection functions is applied:
1) ANSI function code 50N/G
Detection of the earth fault current e.g. by means of a window-type current transformer
(Current transformer by client, secondary 1A, optionally: 5A).
2) ANSI function code 59N/G
Detection of the residual voltage e.g. by means of the voltage measured across the broken -delta
secondary windings of grounded voltage transformers (voltage transformers by client)

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1.11.31 Interfaces to customer Master synchronization
(Synchronization of grid CB)
Scope:
Interfaces from/to each module control panel and customer Master panel with potential free c ontacts.
Further project specific interfaces must be checked during project phase

The engines can run in island mode according to technical instruction TA 2108-0031 based on the condition
that island mode function of the control system is properly designed, supplied, installed and commissioned by
the customer in accordance with GE Jenbacher requirements.

Request to customer master synchronization:

Manual synchronization
For manual synchronization a "synchronizing check relay" is necessary.

Signal monitoring
The synchronizing panel has to have monitoring to detect unlogical signals and operations (such as trip
errors) to ensure safe operation.

Grid protection device (supplied locally):
Protections and settings must be according to GE requirements

Max. distance between customer Master synchronization panel and GE Module control panel: 164 ft

Scope of supply GE Jenbacher:
Terminals at each module control panel.

1.20.03 Start System (Air Start)
Pneumatic Start System:
6.2 bar (90 psig) Starter Motor requiring 2730 Nm3/hr (1610 scft/min) for 10 minutes.

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1.20.04 Battery System
Battery (is not included in GE Jenbacher scope):
4 piece 12 V Pb battery, 160 Ah (according to DIN 72311), complete with cover plate, terminals and acid
tester.

Battery voltage monitoring:
Monitoring by an under voltage relay.

Battery charging equipment:
Capable for charging the starter battery with I/U characteristic and for the supply of all connected D.C.
consumers.
Charging device is mounted inside of the module interface panel or module control panel.

 General data:
 Power supply 3 x 320 - 550 V, 47 - 63 Hz
 max. power consumption 1060 W
 Nominal D.C. voltage 24 V (+/-1%)
 Voltage setting range 24 V to 28,8V (adjustable)
 Nominal current (max.) 40 A
 Dimensions ca. 10 x 5 x 5 inch (240 x 125 x 125 mm)
 Degree of protection IP20 to IEC 529
 Operating temperature 32 °F – 140 °F (0 °C - 60 °C)
 Protection class 1
 Humidity class 3K3, no condensation.
 Natural air convection
 Standards EN60950,EN50178
UL/cUL (UL508/CSA 22.2)
Signalling:
Green Led: Output voltage > 20,5V
Yellow Led: Overload, Output Voltage < 20,5V
Red Led: shutdown

Control accumulator:
 Pb battery 24 VDC/18 Ah

1.20.05 Electric jacket water preheating
Installed in the jacket water cooling circuit, consisting of:
 Heating elements
 Water circulating pump

The jacket water temperature of a stopped engine is maintained between 133 °F (56°C) and 140°F (60°C), to
allow for immediate loading after engine start.

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1.20.08 Flexible connections
Following flexible connections per module are included in the GE Jenbacher -scope of supply:

No.Connection Unit Dimension Material

2 Warm water in-/outlet in/lbs 4''/145 Stainless steel
1 Exhaust gas outlet in/lbs 20''/145 Stainless steel
1 Fuel gas inlet in/lbs 4-6''/232 Stainless steel
2 Intercooler in-/outlet in/lbs 2½''/ Stainless steel
2 Lube oil connection in 1.1 Hose

Seals and flanges for all flexible connections are included.

1.20.45 Fuel Blending
As a prerequisite to any discussions regarding on online fuel blending, both gases must comply with GE
Jenbacher TI 1000-0300.

Physically, the engine must be installed with two Tec Jet based gas train systems sized as required. To
function properly, each individual gas train should be able to provide the full fuel flow required to maintain
rated load of the engine generator set. If 0-100% blending on each fuel is specified, the technician must have
the capability to operate the engine on each fuel (from Start to Full Load) independently. Intermediate or
partial blending can be done by request.

From a controls perspective, the customer must provide the following Dual Fuel Blending signals (at a
minimum)

1) Fuel Gas Selection - Discrete Contact Input to the Diane Control System that represents the fuel that
the unit will start with (1 = High Btu (Gas1), 0 = Low Btu (Gas2)).
2) Release for Gas Mixing – Discrete contact input to the Diane Control System that represents a
release of the fuel delivery system to operate in mixing mode. This signal is used in conjunction
with Mixing Percentage in order to establish the amount of fuel to mix.
3) Mixing Percentage – An Analog (4-20mA) input to the Diane Control System representing the
percentage of Gas 2 fuel to mix.

As prerequisite for blending, the following permissive conditions must be met

1) Breaker is Closed
2) Unit is operating in Leanox control (No Island Mode)
3) No Gas Train 1 Low Pressure
4) Gas Train 1 READY (internal health signal)
5) No Gas Train 2 Low Pressure

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6) Gas Train 2 Ready (internal health signal)
7) Mixing Percentage signal healthy

Fuel Transfers are not permitted as long as the health of each gas train is not clear or if Gas Pressure of the
other train is Low. Diane Warning alarm signals 3221 (Gas Train 1 Low Pressure) or 3222 (Gas Train 2 Low
Pressure) will be displayed if this is the case.

Provided the above permissive conditions are met, to activate mixing, Release for Gas Mixing must be
enabled. Once enabled, the engine will ramp to the mixing percentage specified by Mixing Percentage.
The transfer rate is 1.7% per second, or if the transfer is to 100% of the other fuel, expect a ramp time of 60
seconds to get from one fuel to the other. The mixing percentage can be adjusted at any time during mixing
operations (Release for Gas Mixing = 1). Should a fault occur, the fuel system will default to the gas
selected at start (based on Fuel Gas Selection contact status).

This percentage will be maintained throughout the load profile of the engine, provided there is sufficient
capacity of the second fuel to maintain the load setpoint. Should there be insufficient fuel to maintain the KW
setpoint, a Low Pressure Alarm will occur and the unit will transfer back to the base fuel as dictated by the
position of the Fuel Gas Selection contact.

2.00 Electrical equipment
Totally enclosed floor mounted sheet steel cubicle with front door wired to terminals. Ready to operate, with
cable entry at bottom. Naturally ventilated.

Protection: IP 42 external, NEMA 12
IP 20 internal (protection against direct contact with live parts)

Design according to EN 61439-2 / IEC 61439-2 and ISO 8528-4.
Ambient temperature 41 - 104 °F (5 - 40 °C), 70 % Relative humidity

Standard painting: Panel: RAL 7035
Pedestal: RAL 7020

2.02 Grid monitoring device
Standard without static Grid - 60Hz alternator

Function:
For immediate disconnection of the generator from the grid in case of grid failures.

Consisting of:
 High/low voltage monitoring
 High/low frequency monitoring
 Specially adjustable independent time for voltage and frequency monitoring

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 Vector jump monitoring or df/dt monitoring for immediate disconnection of the generator from the grid for
example at short interruptions
 Indication of all reference dimensions for normal operation and at the case of disturbance over LCD and
LED
 Adjusting authority through password protection against adjusting of strangers

Scope of supply:
Digital grid protection relay with storage of defect data, indication of reference dimensio ns as well as
monitoring by itself.

Grid protection values:
Parameter Parameter limit Max time delay[s] Comments
59-61Hz Do work normal
f<[ANSI 81U] 59Hz 0,5 Load reduction with 10%/HZ
below 59Hz!
f<<[ANSI 81U] 58.5Hz 0,1
f>[ANSI 81O] 61,5Hz 0,1 Load reduction with 30%/HZ
above 61Hz!
U<[ANSI 27] 90% 1 Load reduction with 1%P
/%U below 95%
U<<[ANSI 27] 80% 0,2 Load reduction with 1%P
/%U below 95%
U>[ANSI 59] 110% 30 Load reduction with 1%P
/%U above 105%
U>>[ANSI 59] 115% 0,2 Load reduction with 1%
P/%U above 105%
Df/dt [ANSI 81R]
Or
Vector shift
[ANSI 78]
2Hz/s, 5 Periods
Or
8° -3pol

Cos phi range:
0,8ind (overexcited)
- 1

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2.12 Gas warning device
Function:
The gas warning device continuously monitors the radiated air in the engine room and warns against gases
which are injurious to persons’ health and against explosive gas concentrations.
The measuring head (catalytic sensor) is attached on the covering or nearby the ground, dependent upon the
gas source.

Scope of supply:
 Alarm unit voltage: 24VDC
 2 Gas sensor(s)

2.13 Smoke warning device
Function:
The smoke warning device in combination with the optical smoke detector (installed in the control room) and
the thermal smoke detector (installed in the engine room) provide extensive early warning signal.

Design:
The device has an optical display for alarm and operation.
The smoke warning device is installed in a plastic housing.

Scope of supply:
 Alarm unit voltage: 24 V
2 Smoke detector(s)

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3.70 Control Strategy and Options
Control Strategy -

Grid Parallel with KW Control – Real Power Load Control of the Generator set will be either via a 4-20mA
input from the customer representing a unit KW load setpoint or a KW load setpoint entered on the Diane
XT3 screen. Upon breaker closure, the unit will ramp to the setpoint at a maximum rate of
(Rated Unit KW) / 180 seconds.

Grid Parallel with PF Control – Reactive Power Load Control of the Generator set will be either via a 4-20mA
input from the customer representing a unit Power Factory setpoint or a Power Factor setpoint entered on the
Diane XT4 screen. Upon breaker closure, the unit will maintain the setpoint.

Grid Parallel with Import/Export Control - Load Control via an Import/Export KW level entered on the Diane
XT4 screen. Required will be a customer 4-20mA signal representing the Site KW (Imported and/or Exported
Power) that is to be controlled. Upon breaker closure, the unit will ramp to a load that will drive the KW value
represented by the 4-20mA input signal to the level entered on Customer Import/Export Setpoint entered in
the Diane XT4 screen. Once at the setpoint, the unit will raise and lower load to maintain this value. If the
generator load required to maintain this setpoint drops below the minimum load level of the generator set, the
unit 52G circuit breaker will be opened.

Grid Parallel with Fuel Gas Supply Pressur e Control - Load Control via Fuel Gas pressure level entered on
the Diane XT4 screen. Required will be a customer 4-20mA signal representing the Fuel Gas Supply
Pressure to the engine that is to be controlled. Upon breaker closure while running against t he utility, the unit
will ramp to a load that will maintain the supply pressure at or above the value represented by the setpoint
entered in the Diane XT4 screen. Should the setpoint be reached, no further load will be added so as to not
drive the pressure lower. If the pressure begins to drop, the unit will offload to maintain the setpoint. If the
pressure increases, the engine load will increase. Should the generator load required to maintain this
setpoint drop below the minimum load level of the generator set, the unit 52G circuit breaker will be opened.

Island Mode Operations with Blackout Starting – Island Operations with Black start capability will allow the
engine to start and run without utility being present. The engine will be able to start t he engine on battery
power, close the generator breaker against a dead bus, and operate independently of a utility power source.
The customer must ensure that there is sufficient fuel gas and pre-chamber gas at pressure in the event of a
Type 6 engine so configured. The engine will start without the normal confirmation of engine block
temperature or operation of a circulating AC water pump. It will be required of the operators that once the
engine is connected to the generator bus, power to the engine auxiliaries be restored. Load Management is
expected to be limited by the operators to the limits of the engine, as per GE Jenbacher TI 2108 -0031. This
system will work in conjunction with a GE Jenbacher Master Synchronizing Control (see appropriate Spec
Section) if so equipped, or a customer Master Synchronizing Panel as per 1.11.31.

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Per Unit Customer Enclosure Controls - Diane XT4 System will be provided with the following additional
features to operate a customer enclosure

- Audible and Visual Alarm Indications - Hardware and software to drive a customer provided horn
and strobe. Power for these devices is provided from the control system and is 24VDC

- Discrete Input for Air Filter Differential Pressure – Additional Discrete Input and associated software
for control

Per Unit Balance of Plant Controls – Hot Water Loop Panel Controls and Software to include:

- Hot Water Pump (Panel Control Parts and SW Only) - The option will add specific contact output and
feedback input to/from an MCC for the Hot Water Pump. This will include relays and software.

- Hot Water Return Temperature Control (Panel Parts and SW Only) - This feature will provide all
necessary controls to operate a 3 Way temperature control valve. The customer will provide a
PT100 as a feedback signal and the Diane will provide a 4-20mA Analog Output to a customer
provided valve. Control and Display Software are also provided.

- Emergency Hot Water Temperature Control (Panel Parts and SW Only) - This feature will provide all
necessary controls to operate a 3 Way temperature control valve. The customer will provide a
PT100 as a feedback signal and the Diane will provide a 4-20mA Analog Output to a customer
provided valve. Control and Display Software are also provided.

- Emergency Hot Water Pump Control (Panel Parts and SW Only) - The option will add specific contact
output and feedback input to/from an MCC for the Emergency Cooling System Pump. This will
include relays and software.

Per Unit Balance of Plant Controls – Intercooler Loop Panel Controls and Software to include:

- IC Temperature Control (Panel Parts and SW Only) - This feature will provide all necessary controls
to operate a 3 Way temperature control valve in the IC Loop if Not Required by Site Conditions. The
Diane will provide a 4-20mA Analog Output to a customer provided valve and will utilize mixture
temperature as a feedback input. Control and Display Software are also provided.

- Intercooler Pump Control (Panel Control Parts and SW Only) - The option will add specific contact
output and feedback input to/from an MCC for the Intercooler Water Pump. This will include relays
and software.

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Additional Control Signals for Display -

- Additional Analog Inputs for Display (4-20mA) – 5x

- Additional Analog Inputs for Display (PT100) – 5x

- Additional Analog Inputs for Display (Type K T/C) – 5x

Additional Options

- M1 Air Conditioner Unit

3.71 Vibration Sensor
A structural Vibration Sensor will be installed on the package base frame to detect excessive vibrations. A
signal we will sent to the control panel to indicate an alarm condition.

3.72 Seismic Protection
The main base will be supplied with pre-drilled holes to accommodate customer furnished bolts to act as
retaining elements in the event of an earthquake. The customer foundation mounted bolts cannot come into
contact with the unit base frame, as these bolts are for retention only, not mounting.

Details will be provided at first drawing submittal.

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4.00 Delivery, installation and commissioning
4.01 Carriage
According to contract.

4.02 Unloading
Unloading, moving of equipment to point of installation, mounting and adjustment of delivered equipment on
intended foundations is not included in GE Jenbacher scope of supply.

4.03 Assembly and installation
Assembly and installation of all GE Jenbacher -components is not included in GE Jenbacher scope of supply.

4.04 Storage
The customer is responsible for secure and appropriate storage of all delivered equipment.

4.05 Start-up and commissioning
Start-up and commissioning with the GE Jenbacher start -up and commissioning checklist is not included.
Plants with island operation require internet connection.

4.06 Trial run
After start-up and commissioning, the plant will be tested in an 8-hour trial run. The operating personnel will
be introduced simultaneously to basic operating procedures.
Is not included in GE Jenbacher scope of supply.

4.07 Emission measurement (exhaust gas analyser)
Emission measurement by GE Jenbacher personnel, to verify that the guaranteed toxic agent emissions have
been achieved (costs for measurement by an independent agency will be an extra charge).

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5.01 Limits of delivery
Electrical
 Module:
 At terminals of module interface panel
 At terminals of generator terminal box
(screwed glands to be provided locally)
 Module control panel:
At terminal strips
 Auxiliaries:
At terminals of equipment which is supplied separately

Warm water
 At inlet and outlet flanges on module
 At inlet and outlet flanges of the exhaust gas heat recovery system

Low temperature water
At inlet and outlet flanges at module

Exhaust gas
 At the exhaust gas exit of the engine
 At inlet and outlet flanges of the exhaust gas heat recovery system

Combustion air
The air filters are set mounted

Fuel gas
 At inlet and outlet flanges of gas train
 At inlet flange of gas pipework on module
 At outlet flange of the pre-chamber gas train
 At inlet flange of pre-chamber gas pipework on module
 At connection for boost pressure compensation on module
 At connection for boost pressure compensation on gas pressure regulator of the pre -chamber gas train

Lube oil
At lube oil connections on module

Draining connections and pressure relief
At module

Condensate
At condensate drain on exhaust gas heat exchanger

Insulation
Insulation of heat exchangers and pipe work is not included in our scope of supply and must be provided
locally.

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First filling
The first filling of the plant, (lube oil, engine jacket water, anti-freeze, anti-corrosive agent, battery acid) is not
included in our scope of supply.

The composition and quality of the used consumables are to be strictly monitored in accordance with the
"Technical Instructions" of GE JENBACHER.

Suitable bellows and flexible connections must be provided locally for all connections.
Cables from the module must be flexible.

5.02 Factory tests and inspections
The individual module components shall undergo the following tests an d inspections:

5.02.01 Engine tests
Carried out as combined Engine- and Module test according to DIN ISO 3046 at GE Jenbacher test bench.
The following tests are made at 100%, 75% and 50% load, and the results are reported in a test certificate:
 Engine output
 Fuel consumption
 Jacket water temperatures
 Lube oil pressure
 Lube oil temperatures
 Boost pressure
 Exhaust gas temperatures, for each cylinder

5.02.02 Generator tests
Carried out on the premises of the generator supplier.

5.02.03 Module tests
The engine will be tested with natural gas (methane number 94). The performance data achieved at the test
bench may therefore vary from the data as defined in the technical specification due to differences in fuel gas
quality.
Carried out as combined Engine- and Module test commonly with module control panel at GE Jenbacher test
bench, according to ISO 8528, DIN 6280. The following tests are made and the results are reported in a test
certificate:
Visual inspection of scope of supply per specifications.
 Functional tests per technical specification of control system.
 Starting in manual and automatic mode of operation
 Power control in manual and automatic mode of operation
 Function of all safety systems on module
 Measurements at 100%, 75% and 50% load:
 Frequency
 Voltage
 Current
 Generator output

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 Power factor
 Fuel consumption
 Lube oil pressure
 Jacket water temperature
 Boost pressure
 Mixture temperature
 Exhaust emission (NOx)

The module test for operating frequenzy 50 Hz and 6,3-6,6kV / 10,5kV-11kV will be carried out with the
original generator, except it is not possible because of the delivery date. Then a test generator will be used
for the module test.
To prove characteristics of the above components, which are not tested on the test bench by GE
JENBACHER, the manufacturers’ certificate will be provided.

5.03 Documentation
Preliminary documentation 60 days after receipt of a technically and commercially clarified order:
 Module drawing 1)
 Technical diagram 1)
 Drawing of control panel 3)
 List of electrical interfaces 2)
 Technical specification of control system 2)
 Technical drawing auxiliaries (if included in GE Jenbacher-limit of delivery) 1)

At delivery:
 Wiring diagrams 3)
 Cable list 3)

At start-up and commissioning (or on clients request):
 Operating and maintenance manual 4)
 Spare parts manual 4)
 Operation report log 4)

This page intentionally left blank.
Technical Memorandum Best Available Control Technology Determination for Cogen Engines 3 and 4

B
Use of contents on this sheet is subject to the limitations specified at the beginning of this document.
BACT Determination for Cogen Engines 3 and 4 TM - FINAL.docx
Attachment B: BACT Database Search Results

Technical Memorandum Best Available Control Technology Determination for Cogen Engines 3 and 4

B
Use of contents on this sheet is subject to the limitations specified at the beginning of this document.
BACT Determination for Cogen Engines 3 and 4 TM - FINAL.docx

This page intentionally left blank.

Attachment B
Facility 1 Facility 2 Facility 3 Facility 4 Facility 5 Facility 6 Facility 7 Facility 8 Facility 9 Facility 10 Facility 11 Facility 12 Facility 13 Facility 14 Facility 15 Facility 16 Facility 17 Facility 18
Air District Maine DEP Vermont DEC Indiana DEM Michigan DEQ Illinois EPA Florida DEP Michigan DEQ San Diego County APCD Oregon DEQ Oregon DEQ Vermont DEC Michigan DEQ Michigan DEQ Michigan DEQ Indiana DEM Ohio EPA Santa Barbara County APCD Ohio EPA
County, State Penobscot, ME Orleans, VT White, IN Macomb, MI Ogle, IL Sarasota, FL Lennon, MI San Diego, CA Gilliam, OR Gilliam, OR Washington, VT Shiawassee, M Shiawassee, M Shiawassee, M Hendricks, IN Loraine, OH Santa Barbara, CA Mahoning, OH
Facility Type Juniper Ridge Landfill Coventry Municipal Solid Waste Facility Liberty Landfill, Inc.
Waste Management, Inc Pine Tree Acres
Landfill Hoosier Energy Sarasota Landfill Gas-to-Energy Venice Park Recycling & Disposal Facility
City of San Diego, Public Utilities
Department Landfill
Columbia Ridge Landfill and Recycling
Center
Columbia Ridge Landfill and Recycling
Center Moretown Landfill Gas to Energy Facility Venice Park Landfill Venice Park Landfill Venice Park Landfill Twin Bridges Recycling and Disposal Facility Loraine County LFG Power Station City of Santa Maria Landfill
Carbon Limestone Landfill Gas Power
Station
Date of ATC
Date of PTO 3/30/2016 3/4/2016 10/22/2015 2/13/2015 12/23/2013 12/18/2013 12/11/2013 9/25/2013 6/21/2013 6/21/2013 7/12/2012 5/8/2012 5/8/2012 5/8/2012 3/5/2012 9/14/2011 8/25/2011 7/5/2011
Process Name Engines #1, #2, #3 Stationary Internal Combustion Engin Landfill Gas-Fired Engine Generator ICE Engines Engines Four landfill gas-to-energy engines 4 CAT engines using landfill gas ICE Landfill Gas Fired Engine Caterpillar 3516 Engine Caterpillar 3520C Engine Landfill gas to energy engines (2)Caterpillar 3516 Generator Engine Caterpillar 3512 Generator Engine Landfill Gas Generator Engine Caterpillar 3520 Generator Engines (2)Reciprocating Internal Combustion Engine Internal Combustion Engine Caterpillar engines (2)
Fuel Type Landfill Gas Landfill Gas Landfill Gas Landfill Gas Treated Landfill Gas Landfill Gas Landfill Gas Landfill Gas Landfill Gas Landfill Gas Landfill Gas Landfill Gas Landfill Gas Landfill Gas Landfill Gas Landfill Gas Landfill Gas Landfill Gas
Throughput 16.5 MMBTU/HR 2535 SCFM 1.6 MW (2233 BHP) 541 SCFM 2.6 MW 554 SCFM (2242 BHP) 1600 KW 2233 BHP 1400 MMdscf/yr 2328 MMdscf/yr 1600 KW 800 KW (1148 HP) 615 KW (861 HP) 1600 KW (2233 HP) 1.6 MW (2233 HP) 2233 HP 1.426 MW (1966 HP) 2233 HP
Notes
Polluntants
NOX
Technology Air/Fuel Ratio Controllers Good combustion practices
Efficient combustion design and air-fuel
controllers Engine Design Electronic AFRC Electronic AFRC Electronic AFRC Lean burn technology Lean burn with AFRC Lean burn technology
Limit 0.6 g/bhp-hr
2.97 lb/hr 0.6 g/bhp-hr 0.6 g/hp-hr
0.6 g/bhp-hr
3 lb/hr 0.5 g/bhp-hr 1.45 g/bhp-hr
183.8 lb/mmdscf
0.6 g/hp-hr
2.954 lb/hr 2 g/bhp-hr 2 g/bhp-hr 0.6 g/bhp-hr
2.46 lb/hr
10.78 tons/yr
0.5 g/bhp-hr
38 ppmvd @ 15% 02 6 min
5.9 lb/hr both engines together
25.84 tons/yr both engines together
3 g/bhp-hr
CO
Technology Service/Cleaning Good combustion practices Proper combustion in engines Engine design and maintenance Electronic AFRC Electronic AFRC Electronic AFRC Good combustion practices Lean burn technology Lean burn with AFRC Lean burn technology
Limit 3.5 g/bhp-hr
17.3 lb/hr
3.5 g/bhp-hr
17.3 lb/hr 3.3 g/bhp-hr 2.5 g/hp-hr
3.5 g/bhp-hr
17.3 lb/hr
3.3 g/bhp-hr
16.3 lb/h
2.5 g/bhp-hr
285.9 lb/mmdscf
3.6 g/hp-hr
17.72 lb/hr
2.75 g/bhp-hr 3.1 g/bhp-hr 3.03 g/bhp-hr 3.3 g/bhp-hr 3.3 g/hp-h
13.53 lb/hr
59.26 tons/yr
2.75 g/bhp-hr
308 ppmvd @ 15% 02 6 min
1.64 lb/hr both engines together
7.18 tons/yr both engines together
1 g/bhp-hr
VOC
Technology Engine Design Lean burn with AFRC
Limit 0.71 g/hp-hr 0.63 g/bhp-hr 20 PPM @ 15% 02 5.4 lb/mmdscf
20 ppm @ 3% O2
23.5 lb/mmdscf
28.82 lb/hr
125.79 tons/yr 86 ppmvd @ 15% 02 6 min 28.82 lb/hr125.79 tons/yr
PM2.5 total PM total PM total PM
Technology Coalescing Filters Good combustion practices Proper O&M Proper O&M Proper O&M
Limit 1.2 lb/hr 23.3 lb/mmcf, CH4 dry 0.1 g/hp-hr
0.1 g/hp-hr
0.253 lb/hr
0.492 lb/hr
0.1 g/hp-hr 0.2 g/bhp-hr 0.2 g/bhp-hr 0.2 g/bhp-hr
PM10
Technology Coalescing Filters
Limit 1.2 lb/hr
0.49 lb/hr
2.15 tons/yr
0.1 g/bhp-hr
0.98 lb/hr both engines together
4.3 tons/yr both engines together
0.1 g/bhp-hr
SO2
Technology
Limit 3.51 lb/hr 300 ppm
49.91 lb/mmdscf
0.28 lb/hr
1.23 tons/yr
0.56 lb/hr both engines together
2.46 tons/yr both engines togethe
Hydrochloric Acid
Technology
Limit 0.36 lb/hr
1.58 tons/yr
0.3 lb/hr both engines together
1.32 tons/yr both engines togethe
Visible Emissions
Technology
Limit 10% opacity as a 6 min avg 10% opacity as a 6 min avg
Formaldehyde
Technology
Limit
Hydrogen Sulfide
Technology 300 ppm 98% DRE
0.53 lb/mmdscf
Limit
(1) - Tentatively identified compound
U - non-detect, value shown is the reporting limit.
76
J - estimated value, above the method detection limit, but below the reporting limit.
Table B-1. BACT Determination for Engines
USEPA RACT/BACT/LAER Clearinghouse for Category 17.140 - Internal Combustion Engines - Large (>500 HP) - Landfill/Digester/Bio-Gas
Use of contents on this sheet is subject to the limitations specified in this document
Tables for BACT doc.xlsx
Attachment B
Facility 1 Facility 2 Facility 3 Facility 4 Facility 5 Facility 6 Facility 7 Facility 8 Facility 9 Facility 10 Facility 11
Air District Maine DEP Vermont DEC Indiana DEM Michigan DEQ Illinois EPA Florida DEP Michigan DEQ San Diego County APCD Oregon DEQ Oregon DEQ Vermont DEC
County, State Penobscot, ME Orleans, VT White, IN Macomb, MI Ogle, IL Sarasota, FL Lennon, MI San Diego, CA Gilliam, OR Gilliam, OR Washington, VT
Facility Type Juniper Ridge Landfill Coventry Municipal Solid Waste Facility Liberty Landfill, Inc.
Waste Management, Inc Pine Tree Acres
Landfill Hoosier Energy Sarasota Landfill Gas-to-Energy Venice Park Recycling & Disposal Facility
City of San Diego, Public Utilities
Department Landfill
Columbia Ridge Landfill and Recycling
Center
Columbia Ridge Landfill and Recycling
Center Moretown Landfill Gas to Energy Facility
Date of ATC
Date of PTO 3/30/2016 3/4/2016 10/22/2015 2/13/2015 12/23/2013 12/18/2013 12/11/2013 9/25/2013 6/21/2013 6/21/2013 7/12/2012
Process Name Engines #1, #2, #3 Stationary Internal Combustion Engin Landfill Gas-Fired Engine Generator ICE Engines Engines Four landfill gas-to-energy engines 4 CAT engines using landfill gas ICE Landfill Gas Fired Engine Caterpillar 3516 Engine Caterpillar 3520C Engine Landfill gas to energy engines (2)
Fuel Type Landfill Gas Landfill Gas Landfill Gas Landfill Gas Treated Landfill Gas Landfill Gas Landfill Gas Landfill Gas Landfill Gas Landfill Gas Landfill Gas
Throughput 16.5 MMBTU/HR 2535 SCFM 1.6 MW (2233 BHP) 541 SCFM 2.6 MW 554 SCFM (2242 BHP) 1600 KW 2233 BHP 1400 MMdscf/yr 2328 MMdscf/yr 1600 KW
Notes
Polluntants
NOX
Technology Air/Fuel Ratio Controllers Good combustion practices
Efficient combustion design and air-fuel
controllers Engine Design
Limit 0.6 g/bhp-hr
2.97 lb/hr 0.6 g/bhp-hr 0.6 g/hp-hr
0.6 g/bhp-hr
3 lb/hr 0.5 g/bhp-hr 1.45 g/bhp-hr
183.8 lb/mmdscf
0.6 g/hp-hr
2.954 lb/hr
CO
Technology Service/Cleaning Good combustion practices Proper combustion in engines Engine design and maintenance
Limit 3.5 g/bhp-hr
17.3 lb/hr
3.5 g/bhp-hr
17.3 lb/hr 3.3 g/bhp-hr 2.5 g/hp-hr
3.5 g/bhp-hr
17.3 lb/hr
3.3 g/bhp-hr
16.3 lb/h
2.5 g/bhp-hr
285.9 lb/mmdscf
3.6 g/hp-hr
17.72 lb/hr
2.75 g/bhp-hr
VOC
Technology Engine Design
Limit 0.71 g/hp-hr 0.63 g/bhp-hr 20 PPM @ 15% 02 5.4 lb/mmdscf
20 ppm @ 3% O2
23.5 lb/mmdscf
PM2.5 total PM total PM total PM
Technology Coalescing Filters Good combustion practices
Limit 1.2 lb/hr 23.3 lb/mmcf, CH4 dry 0.1 g/hp-hr
0.1 g/hp-hr
0.253 lb/hr
0.492 lb/hr
0.1 g/hp-hr
PM10
Technology Coalescing Filters
Limit 1.2 lb/hr
SO2
Technology
Limit 3.51 lb/hr 300 ppm
49.91 lb/mmdscf
Hydrochloric Acid
Technology
Limit
Visible Emissions
Technology
Limit
Formaldehyde
Technology
Limit
Hydrogen Sulfide
Technology 300 ppm 98% DRE
0.53 lb/mmdscf
Limit
(1) - Tentatively identified compound
U - non-detect, value shown is the reporting limit.
76
J - estimated value, above the method detection limit, but below the reporting limit.
Table B-1. BACT Determination for Engines
USEPA RACT/BACT/LAER Clearinghouse for Category 17.140 - Internal Combustion Engines - Large (>500 HP) - Landfill/Digester/Bio-Gas
Facility 19 Facility 20
Michigan DEQ Michigan DEQ
Wayne, MI Ottawa, MI
Carleton Farms Landfill Ottawa Generating Station
6/29/2011 6/17/2011
Landfill gas fired generator engines (2)Landfill gas fire generator engine
Landfill Gas Landfill Gas
260,880 mmBtu/yr combined for both
engines. Each engine greater than 500 HP 264.38 MMscf/yr (2233 HP)
Good combustion practices with AFRC Good combustion practices with AFRC
0.6 g/bhp-hr each engine 1 g/bhp-hr
Good combustion practices with AFRC Good combustion practices with AFRC
2.2 g/ghp-hr each engine 3.3 g/ghp-hr
Good combustion practices with AFRC
0.15 g/bhp-hr
Good combustion practices with AFRC
0.23 g/bhp-hr each engine
Good combustion practices with AFRC
1.25 lb/hr each engine
Use of contents on this sheet is subject to the limitations specified in this document
Tables for BACT doc.xlsx
Attachment B
Table B-2. BACT Determination for Engines
California Statewide Clearinghouse for Internal Combustion Engines: Landfill or Digester Gas Fired
Facility 1 Facility 2 Facility 3
Air District South Coast Santa Barbara County APCD Santa Barbara County APCD
County, State Orange, CA Santa Barbara, CA Santa Barbara, CA
Facility Type Orange County Sanitation District City of Santa Maria Landfill
City of Santa Maria Wastewater Treatment
Plant
Date of ATC 4/7/2010
Date of BACT Determination 4/4/2017
Date of PTO 8/26/2011
Process Name IC Engine Internal Combustion Engine V-12 gas-fired ICE
Fuel Type Digester Gas Landfill Gas Digester Gas
Throughput 3471 HP 1.426 MW (1966 HP) 510 BHP
Notes Cooper Bessmer MAN
Polluntants
NOX
Technology Oxidation Catalyst, SCR Lean burn with AFRC Air to Fuel Ratio, Regulation Compliance
Limit 11 ppmvd at 15% O2 38 ppmvd @ 15% O2 6 min 15 ppmvd at 15% O2
CO
Technology Oxidation Catalyst, SCR Lean burn with AFRC Air to Fuel Ratio, Regulation Compliance
Limit 250 ppmvd at 15% O2 Lean burn with AFRC 333 ppmvd at 15% O2
VOC
Technology Oxidation Catalyst, SCR Lean burn with AFRC
Limit 30 ppmvd at 15% O2 86 ppmvd @ 15% O2 6 min
PM2.5
Technology
Limit
PM10
Technology
Limit
SO2
Technology
Limit
Hydrochloric Acid
Technology
Limit
Visible Emissions
Technology
Limit
Formaldehyde
Technology
Limit
Hydrogen Sulfide
Technology
Limit
ROG
Technology
Limit
(1) - Tentatively identified compound
U - non-detect, value shown is the reporting limit.
J - estimated value, above the method detection limit, but below the reporting limit.
Use of contents on this sheet is subject to the limitations specified in this document
Tables for BACT doc.xlsx
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Technical Memorandum Best Available Control Technology Determination for Cogen Engines 3 and 4

C
Use of contents on this sheet is subject to the limitations specified at the beginning of this document.
BACT Determination for Cogen Engines 3 and 4 TM - FINAL.docx
Attachment C: Additional Controls Retrofit Cost Estimate

Technical Memorandum Best Available Control Technology Determination for Cogen Engines 3 and 4

C
Use of contents on this sheet is subject to the limitations specified at the beginning of this document.
BACT Determination for Cogen Engines 3 and 4 TM - FINAL.docx

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Central Valley Engine Exhaust SCR Retrofit Conceptual Cost Jim Schettler
2/1/2021
Equipment Item Size Cost, each $Remarks
Oxidization catalyst + SCR system For each engine 140,000 vendors quotes
Urea solution atomizing air compressor For this size SCR 6,000 complete
Urea solution atomizing air piping 60' per engine 1,440 approx.
Urea solution storage tank, 600 gallons HDPE 4,500 vendors quotes
Urea solution storage tank, fill and vent piping 3"3,450 HDPE
Urea solution fill pump as needed 7,500 gear pump
Replacing 20" SST piping with 24" SST 46' each engine 31,280 sch 10S
High temp exhaust piping insulation, 24" dia 2" thick, 50'7,200 approx.
24" SST piping supports lump sum 3,754
Expansion joints for 24" SST pipe 3 per engines 13,500 SST bellows
Urea solution piping, 1/2" SST 65' per engine 1,560
subtotal $220,184
SCR sensors & electric controls wiring and controls 17,615 8%
Electrical wiring, motor starters, conduit, and misc.35,229 16%
subtotal $273,028
Equipment installation, per "RS Means Guide"at 35%$95,560 estimating guide
Structural steel modifications to 2nd deck approx.65,000 retrofit
Structural steel modifications to 3rd deck approx.28,000 retrofit
Structural modifications to roof approx.23,400 retrofit
Structural mods to building wall for 24" EE dia approx.31,560 retrofit
subtotal $516,547
Engineering costs at 12%61,986 typical, retrofit
Contingency at 15%77,482
Total for each engine-generator $656,000 approximately
Table 1. Estimated Costs
As requested, here is a brief conceptualized cost estimate to add oxidation catalysts and SCR systems to the new 1812-kW Central
Valley Jenbacher engine-generators. The costs below are per engine.
Currently each 1812-kW Jenbacher engines is now installed in the Power Gen Building that was originally built in 1984 and was designed
for housing five 625-kW engine generators. Over the years the original rich-burn Waukesha engines were converted to lean-burn engines
and upgraded, or replaced with 1300-kW lean-burn engine-generators. More recently the original engines were replaced with current
technology lean-burn Jenbacher engines (engines 1 & 2) that were located with the spaces vacated by removing the original machines.
When the needed engine exhaust heat recovery heat exchangers and silencers were added, on the now larger diameter 20" diameter
exhaust piping, there was little available physical space remaining. Additionally the replacement lean-burn engines (engines 3 & 4), just
like all large IC engines, have limitations on their allowed exhaust backpressure, now totaling 20-inches water column (inches WC), per
their manufacturer.
As before, the new Jenbacher engine generators (engines 1 & 2) and their support exhaust equipment are located within the existing
building, for noise containment and climate control. Based on the reconfigured 1812-kW engine-generators, we now have two serious
limitations on adding more exhaust equipment such as the proposed oxidation catalysts and the SCR related equipment.
1. The longest available section of straight bare exhaust piping is now about 9 feet long. Oxidation catalyst, the SCR mixing section
and their SCR catalyst are much longer, totaling 15 feet per one candidate supplier's quote, and 16 feet long per another quote.
2. Even with the now larger size 20" diameter engine exhaust piping, when totaling all the backpressure imposed by the exhaust
piping and the needed exhaust heat recovery equipment, the remaining allowable backpressure is only about 3" WC, out of the total
allowable 20" WC. Quotations from 2 experienced oxidation catalysts and SCR suppliers state that their exhaust treatment
equipment will need ether 8" WC or 10" WC backpressure, or much more pressure than available. This suggests that larger
diameter 24" dia EE will likely be needed, in lieu of 20" dia.
The estimated cost of the oxidation catalyst and SCR equipment, plus needed building modifications and equipment is shown below in
Table 1:
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Reasonably Available Control Technology Analysis for NOx

B
1_RACT Analysis
Attachment B: 2023 BACT - Emergency Engines
Technical Memorandum

Limitations:
This document was prepared solely for Central Valley Water Reclamation Facility (CVWRF) in accordance with professional standards at the time the
services were performed and in accordance with the contract between CVWRF and Brown and Caldwell dated January 3, 2023. This document is
governed by the specific scope of work authorized by CVWRF; it is not intended to be relied upon by any other party except for regulatory authorities
contemplated by the scope of work. We have relied on information or instructions provided by CVWRF and other parties and, unless otherwise
expressly indicated, have made no independent investigation as to the validity, completeness, or accuracy of such information.
.202 Cousteau Place, Suite 175
Davis, CA 95618

T: 530.747.0650

Prepared for: Central Valley Water Reclamation Facility
Project Title: Emergency Diesel Engine Generators Serving Blower Building
Project No.: 159388
Technical Memorandum
Subject: BACT Analysis for Emergency Engine Generators 9, 10, and 11
Date: June 26, 2023
To: Bryan Mansell, Chief Engineer
From: Jason Wiser
Copy to: File

Prepared by:
Jennifer Border, Principal Engineer

Reviewed by:
Don Trueblood, Chief Scientist

Best Available Control Technology Analysis for Emergency Engine Generators 9, 10, and 11
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BACT Emerg Engines 9, 10, 11.docx
Table of Contents
Section 1: Background..............................................................................................................................................1
1.1 Site History and Permitting Timeline..................................................................................................................1
1.2 Attainment Status................................................................................................................................................1
1.3 Standby Emergency Diesel Engine Generators.................................................................................................2
1.3.1 Engine Emissions and Controls..........................................................................................................2
Section 2: Best Available Control Technology Analysis...........................................................................................3
2.1 Pollutants for Which BACT is Required..............................................................................................................4
2.2 Control Technologies...........................................................................................................................................4
Section 3: Conclusion................................................................................................................................................5
Attachment A: Emergency Engine Data....................................................................................................................A
Attachment B: EPA RBLC Search Results ................................................................................................................B
List of Tables
Table 1. Engine Data .................................................................................................................................................2
Table 2. RBLC BACT Methods of Control..................................................................................................................4
Best Available Control Technology Analysis for Emergency Engine Generators 9, 10, and 11
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BACT Emerg Engines 9, 10, 11.docx
Section 1: Background
The Central Valley Water Reclamation Facility (CVWRF) is located at 800 West Central Valley Road in Salt
Lake City, Salt Lake County, Utah. CVWRF treats wastewater using a combination of processes. Every day,
between 50 and 60 million gallons of wastewater are conveyed into the facility for treatment. Those millions
of gallons of water are processed, impurities are separated and treated, and harmful bacteria, protozoa, and
viruses are eliminated so that only clean water is returned to Mill Creek and the Jordan River.
1.1 Site History and Permitting Timeline
CVWRF is currently permitted under Title V Air Permit 3500191001, issued March 16, 2020, through the
State of Utah, Department of Environmental Quality, Division of Air Quality (DAQ). Emissions at the facility are
primarily associated with electric power generation from the operation of prime-use digester gas/natural
gas-fueled engine generators and standby emergency diesel engine generators.
The facility is currently undergoing construction of a Biological Nutrient Removal (BNR) system to reduce
effluent total phosphorus concentrations as required by the Technology Based Phosphorus Effluent Limit
Rule promulgated by the Utah DWQ in 2015. The new standby emergency diesel engine generators
(hereafter referred to as “engines”) will provide emergency power to the blower building which serves the
BNR system. The generators are on-site but are not commissioned; commissioning is expected to take place
in late 2023.
1.2 Attainment Status
CVWRF is located in Salt Lake County, Utah which is currently designated non-attainment for PM2.5, SO2 and
Ozone; the area is also designated as a PM10 maintenance area. Salt Lake County was designated as
marginal non-attainment for Ozone on June 4, 2018. Since the area was not able to attain the ozone
standard within the three-year period allowed by United States Environmental Protection Agency (USEPA),
the area was re-designated as moderate non-attainment for ozone on November 7, 2022.
Best Available Control Technology Analysis for Emergency Engine Generators 9, 10, and 11
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1.3 Standby Emergency Diesel Engine Generators
Table 1 provides information regarding each of the three identical engines.
Table 1. Engine Data
Manufacturer MTU Rolls Royce
Generator Model 641-VL75-M
Engine Model 16V4000G74S
Displacement 76.3 liters
Number of Cylinders 16
Displacement per cylinder 4.77 liters per cylinder
Generator Power (Electrical)2,000 kW
Engine Power (estimated)2,884 BHP`
Engine Emissions Data:
Certification
NOx + NMHC
CO
PM
Tier II
5.38 g/hp-hr
0.45 g/hp-hr
0.04 g/hp-hr
a. Engine horsepower based on the fuel consumption provided in the manufacturer spec sheet at 100% load
and assumptions from footnotes “a” and “e” of AP-42 Table 3.4 1
CO = Carbon Monoxide
kW = kilowatt(s)
g = gram(s)
hp-hr = horse power per hour
NMHC = Non-methane hydrocarbon
NOx = Nitrogen Oxides
PM = Particulate Matter
1.3.1 Engine Emissions and Controls
Since the engines do not drive fire pumps, were manufactured after 2006, and are being installed after July
11, 2005, they are subject to 40 Code of Federal Regulations (CFR) 60, Subpart IIII, Standards of
Performance for New Stationary Engines [40 CFR 60.4200]. Since the engines are designated for
emergency use, the model year is later than 2006, and the displacement is less than 30 liters per cylinder,
they are subject to the emissions standards provided in 40 CFR 60.4202 [40 CFR 60.4205]. Section 4202
of Subpart IIII further requires that engines rated at 50 HP or more must meet the emissions standards in 40
CFR 1039, Appendix I and the smoke standards in 40 CFR 1039.105. [40 CFR 60.4202(a)]. The emissions
standards in 40 CFR 1039, Appendix I for engines over 560 kW are equal to the emissions standards for
Tier 2 engines.
The section regarding smoke standards, 40 CFR 1039.105, states that the smoke opacity standards
provided do not apply to engines certified to a PM emission standard of 0.07 g/kW-hr (0.05 g/hp-hr) or
lower. Since the engines are certified to a PM emission standard of 0.04 g/hp-hr, the smoke opacity
standards do not apply.
Best Available Control Technology Analysis for Emergency Engine Generators 9, 10, and 11
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BACT Emerg Engines 9, 10, 11.docx
CVWRF will be required to comply with the other provisions of Subpart IIII, specifically to:
Operate and maintain the engines according to the manufacturer’s emission-related written instructions;
Change only those emission-related settings that are permitted by the manufacturer;
Install and configure the engine according to the manufacturer’s emission-related specifications;
Limit operation of the engines for non-emergency purposes to a maximum of 100 hours per year (of
which up to 50 hours per year can be for uses not associated with maintenance and testing of the
engines).
The USEPA Certificate of Conformity for the engine family states that the following treatment devices are
integral to the engine (“non-after treatment devices”): electronic control and puff limiter. In addition, the
emissions guarantee provided by the manufacturer exceeds the emissions requirements of 40 CFR 1039,
Appendix I (the emissions standards are less than the Tier 2 emissions limits).
Section 2: Best Available Control Technology Analysis
Following USEPA Guidance, best available control technology (BACT) can be defined as the most stringent of
the following:
The lowest emission rate or most effective emission limitation successfully achieved in practice by the
same type of equipment, operated under similar conditions (rating and capacity), at the same type of
source; or
The lowest emission rate or most effective emission control device determined to be technologically
feasible and cost effective for the equipment being installed; or
The requirements of a State or Federal Performance Standard Regulation.
A BACT analysis is performed on a case-by-case basis and must consider emission rates and/or control
technologies that have been achieved on similar equipment or that are technologically feasible and cost
effective. These requirements have led to development of a standard procedure for case-by-case “top down”
BACT analyses.
Step 1: Identify pollutants for which BACT is required. Utah Department of Environmental Quality (DEQ)
regulations require BACT for all criteria pollutants.
Step 2: Identify emission rates and/or control technologies. Once the pollutants for which the BACT
analysis is required are identified, candidate emission rates and/or control technologies must be
identified.
Step 3: Evaluate technological feasibility of the emission rates and/or control technologies identified in
Step 2. Any emission rates and/or control technologies that are not technologically feasible should be
eliminated at this step.
Step 4: Rank remaining emission rates and/or control technologies by effectiveness. This ranking
should consider, as appropriate, control efficiency, resulting emission rates, energy impacts (fuel use,
etc.), and environmental impacts (secondary air emissions, hazardous waste production, impacts to
other media, etc.).
Step 5: Evaluate cost effectiveness of the most stringent emission rates and/or most effective controls.
Step 6: Select BACT.
Best Available Control Technology Analysis for Emergency Engine Generators 9, 10, and 11
4
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BACT Emerg Engines 9, 10, 11.docx
2.1 Pollutants for Which BACT is Required
This BACT analysis considered emissions of NOx, CO, VOC, PM10, PM2.5, and SO2.
2.2 Control Technologies
Existing sources of information were used to identify emission controls that have been used for similar
projects. The Utah DEQ’s website contains several source-specific BACT analyses that were submitted by
facilities which are major sources of PM2.5 and PM2.5 precursors regarding various types of facilities.
Several of these documents contain an analysis of BACT measures for PM2.5 control from emergency
engines. BC reviewed these analyses and did not find any that provided achieved-in-practice controls that
exceed the PM-related controls already proposed for the engines.
In addition, in response to the area around the facility having been recently designated non-attainment for
ozone, the Utah DEQ website contains area source rules which apply to several specific source categories;
none of the rules apply directly or indirectly to internal combustion engines.
BC conducted an initial BACT determinations search of the following database:
USEPA Reasonable Available Control Technology (RACT)/BACT/Lowest Achievable Emission Rate
Clearinghouse (RBLC) – Category 17.110 – Internal Combustion Engines – Large (>500 hp) – Fuel Oil
(kerosene, aviation, and diesel) with a keyword search for “emergency”
The results from the RBLC initially provided over 6,000 potential determinations. However, the results were
further refined through filtering the information as follows:
Engines fired on fuel other than diesel were removed
Engines driving fire pumps were removed
Smaller engines (roughly under 1,000 hp) were removed
Pollutants were limited to criteria pollutants only and omitted carbon dioxide, hydrogen sulfide, and
visible emissions
The refined RBLC results provided 18 BACT determinations. The remaining control technologies cited are
listed in the Table 2 below.
Table 2. RBLC BACT Methods of Control
Pollutant Methods of Control
Particulate Matter
Minimize hours of operation
Tier II Engine
Good combustion practices
SOx Low sulfur fuel (15 ppm sulfur content)
VOC Minimize hours of operation
Tier II Engine
CO Minimize hours of operation
Tier II Engine
NOx 3.95 g/HP-hr – 4.46 g/HP-hra
a. BC requested verification from the agency which submitted the determination for the NOx
emission limit (PA 0291) and received a response from the Pennsylvania Department of
Environmental Protection stating that the source had never been constructed. Therefore,
this emissions limit was not demonstrated as achieved in practice and was not brought
forward for consideration as BACT.
Best Available Control Technology Analysis for Emergency Engine Generators 9, 10, and 11
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BACT Emerg Engines 9, 10, 11.docx
As noted in the footnote for the NOx emission standard in Table 2 above, according to an email from the
Pennsylvania Department of Environmental Protection, the facility subject to the NOx emission limit was
never constructed and the limit was not achieved in practice. Therefore, this BACT determination was not
brought forward.
The remaining Methods of Control cited in the results from the RBLC search will be incorporated by CVWRF
in the operation of the emergency engines.
Section 3: Conclusion
In conclusion, CVWRF purchased MTU emergency engines 9, 10, and 11 and has installed them at the
facility. The engines are not currently operational as the facility which they will serve has not been
constructed yet.
The engines are considered to meet current BACT requirements for the size and type of operation with the
following provisions:
The engines are certified Tier II.
The engines will be operated and maintained according to the manufacturer's emission-related written
instructions;
Only those emission-related settings that are permitted by the manufacturer will be changed;
The engines will be installed and configured according to the manufacturer’s emission-related
specifications;
Operation of the engines for non-emergency purposes will be limited to a maximum of 100 hours per
year (of which up to 50 hours per year can be for uses not associated with maintenance and testing of
the engines).
Only ultra-low sulfur diesel fuel will be used in the engines.
The above provision are considered to satisfy the requirement that good combustion practices are utilized
during the operation of the engines.
Best Available Control Technology Analysis for Emergency Engine Generators 9, 10, and 11
A
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BACT Emerg Engines 9, 10, 11.docx
Attachment A: Emergency Engine Data
Central Valley Water
Reclamation Facility
South Salt Lake, UT
(3) 2000kW Diesel Generators
JULY 2021
REV-2
Submitted by:
Nick Paolo
Smith Power Products,
Inc.
303-810-1085
[e-mail] SU
B
M
I
T
T
A
L
L
Date: September 14, 2020
Reference: SPP2702.4 CVWRF 3 Salt Lake City - 2000kW QTY 3 4160V
We are pleased to offer the following quote for the above project:
The proposal is per one-line drawing and specifications with clarifications in the notes section of the bill of
materials listed after the quote: please reference previous quote 2702.1
QUANTITY EQUIPMENT DESCRIPTION PRICE EACH TOTAL PRICE
3 MTU 2000kW Generator Set
M/N DS2000
Diesel Fuel
Derate: 2000kW @ 4300 Feet, 104°F
4160V Volt, 3 Phase, 60 HZ, 1800 RPM
Genset OPU Dry Assembly Weight: lbs.
Included Included
3 Generator Enclosure Weather Proof Level 2
85 dBA at 23’
Included Included
3 NGR’s Included Included
*Crane/rigging not included. Fuel not included.
Cat walks not included. If required, we can
provide an adder.
Equipment Description:
Generator:
Application Emergency Standby (3D) 1,
Frequency 60 Hz 1,
Generator Voltage 4160 V 1,
Phase 3 Phase 1,
Unit Specification Standard Unit 1,
Engine Model 16V4000G74S (24volts) 1,
Exhaust Emissions (EPA) EPA Tier 2 1,
Radiator Design Temperature 43°C 1,
Temp Rise 130° 1,
Power Output 2000 kW 1,
Full Load Amps 346 1,
Generator Frame and Wire Qty LSA 641-VL75-M (6 Wire) 1,
Generator Wire Configuration Wye 1,
Custom Generator Enclosure Sound 85dB(A) @ 23ft 1,
Fuel Tank UL142 24hr tank 1,
Control panel With Control Panel 1,
Circuit Breaker Options Exterior mounted 1,
Breaker Wire Color Scheme Standard Breaker Wire Color Scheme 1,
Paralleling Paralleling without MTU Components 1,
Central Valley Water Reclation Facility SEPT2020 REV0 Page 29 of 146
3
3
3 NGR’s
y
Generator Enclosure
MTU 2000kW Generator Set
M/N DS2000
2000kW @ 4300 Feet,104°F
4160 V
2000 kW
y
Sound 85dB(A) @ 23ft
UL142 24hr tank
()@
MTU 16V4000 DS2000 45 °C
Diesel Generator Set
2,000 kWe/60 Hz/Standby/380 - 13,800V
Voltage (L-L)380V † ‡416V † ‡440V † ‡480V † ‡600V ‡
Phase33333
PF 0.8 0.8 0.8 0.8 0.8
Hz 60 60 60 60 60
kW 2,000 2,000 2,000 2,000 2,000
kVA 2,500 2,500 2,500 2,500 2,500
Amps 3,798 3,470 3,280 3,007 2,406
skVA@30%
voltage dip 6,899 6,030 6,745 4,914 4,575
Generator model*841-M70-M 841-M70-M 841-M70-M 641-VL90-M 641-VL85-M
Q|œ¬
ҋ³|130 °C/40 °C 130 °C/40 °C 130 °C/40 °C 130 °C/40 °C 130 °C/40 °C
¢|t֋¢6 LEAD WYE 6 LEAD WYE 6 LEAD WYE 6 LEAD WYE 6 LEAD WYE
Voltage (L-L)4,160V 12,470V 13,200V 13,800V
Phase3333
PF 0.8 0.8 0.8 0.8
Hz 60 60 60 60
kW 2,000 2,000 2,000 2,000
kVA 2,500 2,500 2,500 2,500
Amps 347 116 109 105
skVA@30%
voltage dip 4,303 3,243 3,633 3,971
Generator model*641-VL75-M 4P6.6-2600-M 4P6.6-2600-M 4P6.6-2600-M
Q|œ¬
ҋ³|130 °C/40 °C 130 °C/40 °C 130 °C/40 °C 130 °C/40 °C
¢|t֋¢6 LEAD WYE 6 LEAD WYE 6 LEAD WYE 6 LEAD WYE

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Central Valley Water Reclation Facility SEPT2020 REV0 Page 50 of 146
MTU 16V4000 DS2000 45 °C
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Central Valley Water Reclation Facility SEPT2020 REV0 Page 53 of 146
UNITED STATES ENVIRONMENTAL PROTECTION AGENCY
2020 MODEL YEAR
CERTIFICATE OF CONFORMITY
WITH THE CLEAN AIR ACT
OFFICE OF TRANSPORTATION
AND AIR QUALITY
ANN ARBOR, MICHIGAN 48105
Certificate Issued To: MTU America, Inc.
(U.S. Manufacturer or Importer)
Certificate Number: LMDDL95.4GTZ-007
Effective Date:
01/29/2020
Expiration Date:
12/31/2020
_________________________
Byron J. Bunker, Division Director
Compliance Division
Issue Date:
01/29/2020
Revision Date:
N/A
Model Year: 2020
Manufacturer Type: Original Engine Manufacturer
Engine Family: LMDDL95.4GTZ
Mobile/Stationary Indicator: Stationary
Emissions Power Category: 560<kW<=2237
Fuel Type: Diesel
After Treatment Devices: No After Treatment Devices Installed
Non-after Treatment Devices: Electronic Control, Smoke Puff Limiter
Pursuant to Section 111 and Section 213 of the Clean Air Act (42 U.S.C. sections 7411 and 7547) and 40 CFR Part 60, and subject to the terms and conditions prescribed in those provisions, this certificate of
conformity is hereby issued with respect to the test engines which have been found to conform to applicable requirements and which represent the following engines, by engine family, more fully described in
the documentation required by 40 CFR Part 60 and produced in the stated model year.
This certificate of conformity covers only those new compression-ignition engines which conform in all material respects to the design specifications that applied to those engines described in the
documentation required by 40 CFR Part 60 and which are produced during the model year stated on this certificate of the said manufacturer, as defined in 40 CFR Part 60.
It is a term of this certificate that the manufacturer shall consent to all inspections described in 40 CFR 1068 and authorized in a warrant or court order. Failure to comply with the requirements of such a
warrant or court order may lead to revocation or suspension of this certificate for reasons specified in 40 CFR Part 60. It is also a term of this certificate that this certificate may be revoked or suspended or
rendered void ab initio for other reasons specified in 40 CFR Part 60.
This certificate does not cover engines sold, offered for sale, or introduced, or delivered for introduction, into commerce in the U.S. prior to the effective date of the certificate.
The actual engine power may lie outside the limits of the Emissions Power Category shown above. See the certificate application for details.
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Issued to: MTU America Inc
100 Power Dr
Mankato MN 56001-4790

This certificate confirms that
representative samples of
ENGINE GENERATORS
Stationary engine generator assemblies, Diesel Fueled, for
indoor use, Models 12V4000, 16V4000, 20V4000 followed
by D, followed by S, followed by 1250 thru 3250.

Have been investigated by UL in accordance with the
Standard(s) indicated on this Certificate.

Standard(s) for Safety: UL 2200-Engine Generators
CAN/CSA C22.2 No. 100-14-Motors and Generators
Additional Information: See the UL Online Certifications Directory at
https://iq.ulprospector.com for additional information.

This Certificate of Compliance does not provide authorization to apply the UL Mark. Only the UL Follow-Up
Services Procedure provides authorization to apply the UL Mark.

Only those products bearing the UL Mark should be considered as being UL Certified and covered under UL’s
Follow-Up Services.

Look for the UL Certification Mark on the product.

Central Valley Water Reclation Facility SEPT2020 REV0 Page 43 of 146

Accredited Body: DQS GmbH, August-Schanz-Straße 21, 60433 Frankfurt am Main, Germany

CERTIFICATE
This is to certify that

MTU America Inc.

100 Power Drive
Mankato, MN 56001
United States of America
has implemented and maintains a Quality Management System.
Scope:
Development, production, sales and service of decentralized energy systems.
Through an audit, documented in a report, it was verified that the management system
fulfills the requirements of the following standard:

ISO 9001 : 2015

Certificate registration no.
Excerpt from certificate registration no.
Valid from
Valid until
Date of certification
500767 QM15
353331 QM15
2018-08-15
2021-08-14
2018-08-15
DQS GmbH

Stefan Heinloth
Managing Director

Central Valley Water Reclation Facility SEPT2020 REV0 Page 44 of 146
Best Available Control Technology Analysis for Emergency Engine Generators 9, 10, and 11
B
Use of contents on this sheet is subject to the limitations specified at the beginning of this document.
BACT Emerg Engines 9, 10, 11.docx
Attachment B: EPA RBLC Search Results
USEPA RBLC Output
Page 1 of 2
Exported on June 15, 2023
Filtered on Fuel (Diesel)
Excludes:
fire pumps
smaller engines
RBLCID Facility Name
Corporate Or
Company Name
Facility
County
Facility
State
EPA
Region Other Agency Contact Info Permit Num SIC Code NAICS Code
Complete
Application
Date
Permit
Issuance
Date
Date Determination
Last Updated
Permit
Type Process Name Primary Fuel Throughput Tput Unit Pollutant Test Method
Control Method
Description
Emission
Limit
Emission Limit
1 Unit
Case-By-Case
Basis
TX-0728
PEONY CHEMICAL
MANUFACTURING
FACILITY BASF BRAZORIA TX 6
David Infortunio
512-239-1247
<[e-mail]
v>118239, N200 2813 325311 2/11/2015 4/1/2015 1/31/2020 B
Emergency
Diesel
Generator Diesel 1500 hp
Carbon
Monoxide Unspecified
Minimized hours
of operations Tier
II engine 0.0126 G/HP HR
OTHER CASE-
BY-CASE
MA-0039
SALEM HARBOR
STATION
REDEVELOPMENT
FOOTPRINT POWER
SALEM HARBOR
DEVELOPMENT LP ESSEX MA 1
Cosmo Buttaro
MassDEP Northeast Regional
Office
205B Lowell Street
Wilmington, MA 01887
[phone]
[e-mail] NE-12-022 4911 221112 9/9/2013 1/30/2014 5/5/2016 A
Emergency
Engine/Generat
or ULSD 7.4 MMBTU/H
Carbon
Monoxide Unspecified 2.6 GM/BHP-H
OTHER CASE-
BY-CASE
PA-0291
HICKORY RUN ENERGY
STATION
HICKORY RUN
ENERGY LLC LAWRENCE PA 3
JOHN F. GUTH
NORTHWEST REGION AIR
PROGRAM MANAGER
230 Chestnut Street
Meadville, PA 16335-3481
814-332-6940 37-337A 4911 221112 12/20/2012 4/23/2013 3/2/2020 A
EMERGENCY
GENERATOR
Ultra Low
sulfur
Distillate 7.8 MMBTU/H
Carbon
Monoxide Unspecified 5.79 LB/H
OTHER CASE-
BY-CASE
*PA-0313
FIRST QUALITY TISSUE
LOCK HAVEN PLT
FIRST QUALITY
TISSUE, LLC CLINTON PA 3 18-00030C 2676 322291 4/14/2015 7/27/2017 3/26/2019 B
Emergency
Generator Diesel 2500 bhp
Carbon
Monoxide Unspecified 3.5 G
PA-0291
HICKORY RUN ENERGY
STATION
HICKORY RUN
ENERGY LLC LAWRENCE PA 3
JOHN F. GUTH
NORTHWEST REGION AIR
PROGRAM MANAGER
230 Chestnut Street
Meadville, PA 16335-3481
814-332-6940 37-337A 4911 221112 12/20/2012 4/23/2013 3/2/2020 A
EMERGENCY
GENERATOR
Ultra Low
sulfur
Distillate 7.8 MMBTU/H
Nitrogen
Oxides (NOx)Unspecified 9.89 LB/H
OTHER CASE-
BY-CASE
TX-0728
PEONY CHEMICAL
MANUFACTURING
FACILITY BASF BRAZORIA TX 6
David Infortunio
512-239-1247
<[e-mail]
v>118239, N200 2813 325311 2/11/2015 4/1/2015 1/31/2020 B
Emergency
Diesel
Generator Diesel 1500 hp
Particulate
matter,
filterable 10µ
(FPM10)Unspecified
Minimized hours
of operations Tier
II engine 0.15 LB/H
OTHER CASE-
BY-CASE
TX-0728
PEONY CHEMICAL
MANUFACTURING
FACILITY BASF BRAZORIA TX 6
David Infortunio
512-239-1247
<[e-mail]
v>118239, N200 2813 325311 2/11/2015 4/1/2015 1/31/2020 B
Emergency
Diesel
Generator Diesel 1500 hp
Particulate
matter,
filterable 2.5µ
(FPM2.5)Unspecified
Minimized hours
of operations Tier
II engine 0.15 LB/H
OTHER CASE-
BY-CASE
MI-0447
LBWL--ERICKSON
STATION
LANSING BOARD OF
WATER AND LIGHT EATON MI 5
Please contact the permit
engineer
Melissa Byrnes
517-648-6339
[e-mail] 74-18A 4911 221112 9/22/2020 1/7/2021 9/10/2021 D
EUEMGD--
emergency
engine diesel fuel 4474.2 KW
Particulate
matter,
filterable
(FPM)Unspecified
Good combustion
practices, burn
ultra-low diesel
fuel, and will be
NSPS compliant.0.2 G/KW-H
OTHER CASE-
BY-CASE
TX-0728
PEONY CHEMICAL
MANUFACTURING
FACILITY BASF BRAZORIA TX 6
David Infortunio
512-239-1247
<[e-mail]
v>118239, N200 2813 325311 2/11/2015 4/1/2015 1/31/2020 B
Emergency
Diesel
Generator Diesel 1500 hp
Particulate
matter,
filterable
(FPM)Unspecified
Minimized hours
of operations Tier
II engine 0.15 LB/H
OTHER CASE-
BY-CASE
PA-0291
HICKORY RUN ENERGY
STATION
HICKORY RUN
ENERGY LLC LAWRENCE PA 3
JOHN F. GUTH
NORTHWEST REGION AIR
PROGRAM MANAGER
230 Chestnut Street
Meadville, PA 16335-3481
814-332-6940 37-337A 4911 221112 12/20/2012 4/23/2013 3/2/2020 A
EMERGENCY
GENERATOR
Ultra Low
sulfur
Distillate 7.8 MMBTU/H
Particulate
matter, total
(TPM)Unspecified 0.02 TPY
OTHER CASE-
BY-CASE
USEPA RBLC Output
Page 2 of 2
*PA-0313
FIRST QUALITY TISSUE
LOCK HAVEN PLT
FIRST QUALITY
TISSUE, LLC CLINTON PA 3 18-00030C 2676 322291 4/14/2015 7/27/2017 3/26/2019 B
Emergency
Generator Diesel 2500 bhp
Particulate
matter, total
(TPM)Unspecified 0.2 G
TX-0728
PEONY CHEMICAL
MANUFACTURING
FACILITY BASF BRAZORIA TX 6
David Infortunio
512-239-1247
<[e-mail]
v>118239, N200 2813 325311 2/11/2015 4/1/2015 1/31/2020 B
Emergency
Diesel
Generator Diesel 1500 hp
Sulfur Dioxide
(SO2)Unspecified
Low sulfur fuel 15
ppmw 0.61 LB/H
OTHER CASE-
BY-CASE
MA-0039
SALEM HARBOR
STATION
REDEVELOPMENT
FOOTPRINT POWER
SALEM HARBOR
DEVELOPMENT LP ESSEX MA 1
Cosmo Buttaro
MassDEP Northeast Regional
Office
205B Lowell Street
Wilmington, MA 01887
[phone]
[e-mail] NE-12-022 4911 221112 9/9/2013 1/30/2014 5/5/2016 A
Emergency
Engine/Generat
or ULSD 7.4 MMBTU/H
Sulfur Dioxide
(SO2)Unspecified 0.011 LB/H
OTHER CASE-
BY-CASE
OH-0352
OREGON CLEAN ENERGY
CENTER ARCADIS, US, INC.LUCAS OH 5 P0110840 4931 221112 4/3/2013 6/18/2013 5/4/2016 A
Emergency
generator diesel 2250 KW
Sulfur Dioxide
(SO2)
EPA/OAR Mthd
6C 0.03 LB/H N/A
PA-0291
HICKORY RUN ENERGY
STATION
HICKORY RUN
ENERGY LLC LAWRENCE PA 3
JOHN F. GUTH
NORTHWEST REGION AIR
PROGRAM MANAGER
230 Chestnut Street
Meadville, PA 16335-3481
814-332-6940 37-337A 4911 221112 12/20/2012 4/23/2013 3/2/2020 A
EMERGENCY
GENERATOR
Ultra Low
sulfur
Distillate 7.8 MMBTU/H
Sulfur Oxides
(SOx)Unspecified 0.01 LB/H
OTHER CASE-
BY-CASE
TX-0728
PEONY CHEMICAL
MANUFACTURING
FACILITY BASF BRAZORIA TX 6
David Infortunio
512-239-1247
<[e-mail]
v>118239, N200 2813 325311 2/11/2015 4/1/2015 1/31/2020 B
Emergency
Diesel
Generator Diesel 1500 hp
Volatile
Organic
Compounds
(VOC)Unspecified
Minimized hours
of operations Tier
II engine 0.7 LB/H
OTHER CASE-
BY-CASE
PA-0291
HICKORY RUN ENERGY
STATION
HICKORY RUN
ENERGY LLC LAWRENCE PA 3
JOHN F. GUTH
NORTHWEST REGION AIR
PROGRAM MANAGER
230 Chestnut Street
Meadville, PA 16335-3481
814-332-6940 37-337A 4911 221112 12/20/2012 4/23/2013 3/2/2020 A
EMERGENCY
GENERATOR
Ultra Low
sulfur
Distillate 7.8 MMBTU/H
Volatile
Organic
Compounds
(VOC)Unspecified 0.7 LB/H
OTHER CASE-
BY-CASE
*PA-0313
FIRST QUALITY TISSUE
LOCK HAVEN PLT
FIRST QUALITY
TISSUE, LLC CLINTON PA 3 18-00030C 2676 322291 4/14/2015 7/27/2017 3/26/2019 B
Emergency
Generator Diesel 2500 bhp
Volatile
Organic
Compounds
(VOC)Unspecified 3.5 G
RBLCID Facility Name
Corporate Or
Company Name
Facility
County
Facility
State
EPA
Region Other Agency Contact Info Permit Num SIC Code NAICS Code
Complete
Application
Date
Permit
Issuance
Date
Date Determination
Last Updated
Permit
Type Process Name Primary Fuel Throughput Tput Unit Pollutant Test Method
Control Method
Description
Emission
Limit
Emission Limit
1 Unit
Case-By-Case
Basis
Reasonably Available Control Technology Analysis for NOx

C
1_RACT Analysis

Attachment C: Flare Replacement Cost Estimate

Construction Cost
$1,042,698 recent proposal for an enclosed flare to be located in Washington
560 scfm - proposed gas flowrate to be handled by flare
68 scfm - current gas flow to flare at CVWRF
$294,273 Estimated construction cost for flare to handle current gas flow^
^ using the "Rule of six tenths" for cost estimation
NOx Emissions from flare 0.52 tons/year
NOx Emissions from enclosed flare 0.46 tons/year
NOx reduction 0.06 tons/year
Capital Cost $294,273
Life of Enclosed Flare 20 years
8.50%Prime Rate (10/17/2023)
Present Value Control Cost:$31,096
Annual Maintenance Cost:$3,007
Lifetime Maintenance Costs $60,145
Annualized Cost of Control:$568,390 per ton NOx removed
Emissions Reduction
0.068 lb NOx/mmbtu open flare emissions factor (AP-42, Table 13.5-1)
0.06 lb NOx/mmbtu enclosed flare emissions factor (manufacturer guarantees)
12%NOx reduction
Enclosed Flare Operating Cost 11/7/2023 9:31 Jim Schettler
Energy Cost Used (input values, typical)
Natural Gas $3.50 per million Btu
Electricity $0.086 per kWhr, average
Flare Energy Use per John Zink rep, Bob Erdman [phone]
Natural gas not required for the pilot light, nor the flare itself
Electric Power Usage
Blower 10 HP 8.29 kW 100 Hr/yr (testing)assumed
828.56 kWhr/year
$71.26 per year
Control Panel (heater)watts 125 Varec flare Catalog
condensation control, typical 2,000 hours per year assumed
250 kWhr/yr
Heat tracer watts 800 estimate flame arrester and flame check
Heat tracer watts 500 estimate drip trap
Heat tracer watts 200 estimate PRV actuator
kW total 1.5
hours per year 500 freeze protection assumed
kWhr/yr 750
Electric heating 1000 kWhr/year
Electric heating $86.00
total per year, electric usage cost $157 for motors, freeze protection, condensation control
Replacement Equipment Item Costs
Thermocouples every other year $1,000 see above approximate replacement
PLC every 5 years $3,000 see above
Typical 10 year cost
Thermocouples replace 5 $5,000 per Bob Erdman
PLCs replace 2 $6,000 per Bob Erdman
Typical 10 year cost, total $11,000
Source Testing Cost
typical test cost $2500 per source test per Bob Erdman
first year $2,500 initial source test
first year $2,500 added testing and adjustments
2nd year $2,500 yearly source test
3rd year $0 source test every other year, after 2 years
4th year $2,500 source test
5th year $0 source test every other year, after 2 years
6th year $2,500 source test
7th year $0 test every other year
8th year $2,500 source test
9th year $0 test every other year
10th year $2,500 source test
10 year total $17,500 per a source test every other year
Total operating cost per year, average $3,007
Reasonably Available Control Technology Analysis for NOx

D
1_RACT Analysis
Attachment D: Boiler Retrofit Emissions Reduction
Heat Input Boiler = 6.05 MMBtu/hr

HHV Natural Gas = 1020 Btu/SCF
x
NOx Emission Factor = 100 lb/MMSCF
=
Uncontrolled NOx Emissions = 0.593 lb/hr
Heat Input Boiler = 6.05 MMBtu/hr
x
Fd1 =8710 dscf/MMBtu
=
Exhaust Flowrate = 52,696 SCFH
x
MW NOx = 46.0055 lb/lbmol
x
NOx limit = 30 ppm

1E+06

MV = 385 ft3/lb-mol (standard molar volume)
=
Controlled NOx emissions = 0.189 lb/hr
Difference = 0.404 lb/hr
1.77 ton NOx/yr removed
Cost of Controls = 80,000$
45,184$ per ton NOx removed
Notes:
1 for natural gas (per Table 19-2, EPA Method 19)
BOILER #1
Heat Input Boiler = 6.28 MMBtu/hr

HHV Natural Gas = 1020 Btu/SCF
x
NOx Emission Factor = 100 lb/MMSCF
=
Uncontrolled NOx Emissions = 0.616 lb/hr
Heat Input Boiler = 6.28 MMBtu/hr
x
Fd1 =8710 dscf/MMBtu
=
Exhaust Flowrate = 54,699 SCFH
x
MW NOx = 46.0055 lb/lbmol
x
NOx limit = 30 ppm

1E+06

MV = 385 ft3/lb-mol (standard molar volume)
=
Controlled NOx emissions = 0.196 lb/hr
Difference = 0.420 lb/hr
1.84 ton NOx/yr removed
Cost of Controls = 80,000$
43,529$ per ton NOx removed
Notes:
1 for natural gas (per Table 19-2, EPA Method 19)
BOILER #1
Reasonably Available Control Technology Analysis for NOx

E
1_RACT Analysis

Attachment E: Cost Escalation

SCR Economic Feasibility
EPA’s "Alternative Control Techniques" Document (EPA-453/R-93-032) published in July 1993
Provides a cost effectiveness threshold for reduction of NOx from engines using SCR
890.00$ per ton in 1991 dollars
4889 Engineering News Record (ENR) Construction Cost Index (CCI) for 1991
13498 ENR CCI for October 2023 (20 Cities Average)
2,457$ per ton cost-effectiveness threshold escalated to 2023 dollars
Low NOx Burner Economic Feasibility
4,300$ per ton NOx reduction in 1992 dollars
5059 Engineering News Record (ENR) Construction Cost Index (CCI) for 1992
13498 ENR CCI for October 2023 (20 Cities Average)
11,473$ per ton cost-effectiveness threshold escalated to 2023 dollars
Table 2-7 of EPA's "Alternative Control Techniques Document -- NOx Emissions from Industrial /
Commercial / Institutional (lCI) Boilers" (EPA-453/R-94-022)

DAQE-AN104140015-21

{{$d1 }}

Phillip Heck
Central Valley Water Reclamation Fac.
800 West Central Valley Road
Salt Lake City, UT 84119-3379
[e-mail]

Dear Dr. Heck:

Re: Approval Order:
Modification to Approval Order DAQE-AN104140014-19 to Install New GE Jenbacher Engines
and Remove Existing Waukesha Engine
Project Number: N104140015

The attached Approval Order (AO) is issued pursuant to the Notice of Intent (NOI) received on December
4, 2020. Central Valley Water Reclamation Fac. must comply with the requirements of this AO, all
applicable state requirements (R307), and Federal Standards.

The project engineer for this action is Ms. Catherine Wyffels, who can be contacted at [phone]
or [e-mail]. Future correspondence on this AO should include the engineer's name as well as
the DAQE number shown on the upper right-hand corner of this letter. No public comments were
received on this action.

Sincerely,

{{$s }}

Bryce C. Bird
Director

BCB:CW:sb

cc: Salt Lake Valley Health Department
Dan Fagnant, EPA Region 8

195 North 1950 West • Salt Lake City, UT
Mailing Address: P.O. Box 144820 • Salt Lake City, UT 84114-4820
Telephone [phone] • Fax [phone] • T.D.D. [phone]
www.deq.utah.gov
Printed on 100% recycled paper
State of Utah

SPENCER J. COX
Governor

DEIDRE HENDERSON
Lieutenant Governor

Department of
Environmental Quality

Kimberly D. Shelley
Executive Director

DIVISION OF AIR QUALITY
Bryce C. Bird
Director

July 2, 2021
STATE OF UTAH
Department of Environmental Quality
Division of Air Quality

{{#s=Sig_es_:signer1:signature}}
{{#d1=date1_es_:signer1:date:format(date, "mmmm d, yyyy")}}
{{#d2=date1_es_:signer1:date:format(date, "mmmm d, yyyy"):align(center)}}

APPROVAL ORDER
DAQE-AN104140015-21
Modification to Approval Order DAQE-AN104140014-19 to Install
New GE Jenbacher Engines and Remove Existing Waukesha Engine

Prepared By
Ms. Catherine Wyffels, Engineer
[phone]
[e-mail]

Issued to
Central Valley Water Reclamation Fac. - Wastewater Treatment Plant

Issued On
{{$d2 }}

Issued By

{{$s }}

Bryce C. Bird
Director
Division of Air Quality

July 2, 2021
TABLE OF CONTENTS

TITLE/SIGNATURE PAGE ....................................................................................................... 1
GENERAL INFORMATION ...................................................................................................... 3
CONTACT/LOCATION INFORMATION ............................................................................... 3
SOURCE INFORMATION ........................................................................................................ 3
General Description ................................................................................................................ 3
NSR Classification .................................................................................................................. 3
Source Classification .............................................................................................................. 3
Applicable Federal Standards ................................................................................................. 4
Project Description.................................................................................................................. 4
SUMMARY OF EMISSIONS .................................................................................................... 4
SECTION I: GENERAL PROVISIONS .................................................................................... 5
SECTION II: PERMITTED EQUIPMENT .............................................................................. 5
SECTION II: SPECIAL PROVISIONS ..................................................................................... 7
PERMIT HISTORY ................................................................................................................... 11
ACRONYMS ............................................................................................................................... 12

DAQE-AN104140015-21
Page 3

GENERAL INFORMATION

CONTACT/LOCATION INFORMATION

Owner Name Source Name
Central Valley Water Reclamation Fac. Central Valley Water Reclamation Fac.-
Wastewater Treatment Plant

Mailing Address Physical Address
800 West Central Valley Road 800 West Central Valley Road
Salt Lake City, UT 841193379 Salt Lake City, UT 84119-3379

Source Contact UTM Coordinates
Name Bryan Mansell 422600 m Easting
Phone [phone] 4506500 m Northing
Email [e-mail] Datum NAD27
UTM Zone 12
SIC code 4952 (Sewerage Systems)

SOURCE INFORMATION
General Description
Central Valley Water Reclamation Facility (CVWRF) employs primary sedimentation tanks, trickling
filters, aeration tanks, secondary sedimentation tanks and ultraviolet light disinfection. The treated water
is then discharged into Mill Creek. CVWRF also treats the waste materials removed from the water using
anaerobic digesters which reduces the solids by converting them to water, methane gas and a residual
called bio-solids. The water is pressed out of the bio-solids and returned to the liquid portion of the plant
for treatment. The bio-solids are taken and applied to the ground for beneficial agricultural use or
composting. The methane gas is used to fuel engine generators to power the plant. Equipment at the site
consists of digester gas/natural gas-fired engines, emergency generator engines, digester gas flares, small
boilers, and waste oil heaters.

NSR Classification
Minor Modification at Major Source

Source Classification
Located in Northern Wasatch Front O3 NAA, Salt Lake City UT PM2.5 NAA, Salt Lake County SO2
NAA
Salt Lake County
Airs Source Size: A

DAQE-AN104140015-21
Page 4

Applicable Federal Standards
NSPS (Part 60), A: General Provisions
NSPS (Part 60), IIII: Standards of Performance for Stationary Compression Ignition Internal
Combustion Engines
NSPS (Part 60), JJJJ: Standards of Performance for Stationary Spark Ignition Internal
Combustion Engines
MACT (Part 63), A: General Provisions
MACT (Part 63), ZZZZ: National Emissions Standards for Hazardous Air Pollutants for
Stationary Reciprocating Internal Combustion Engines
Title V (Part 70) Major Source

Project Description
CVWRF has requested approval to install and operate GE Jenbacher (JMS) Engines #3 and #4 and to
remove Waukesha Engines #2, #3, and #4. Waukesha Engine #5 will be removed from the AO once JMS
Engine #3 is installed and operational.

There are no changes in emissions from this modification because emissions from the JMS engines were
incorporated in AO DAQE-AN104140014-19 and used as a basis for the NOx limit in II.B.2.b.

SUMMARY OF EMISSIONS

The emissions listed below are an estimate of the total potential emissions from the source. Some
rounding of emissions is possible.

Criteria Pollutant Change (TPY) Total (TPY)
Ammonia 0 0.17
CO2 Equivalent 0 50209.31
Carbon Monoxide 0 250.46
Nitrogen Oxides 0 63.82
Particulate Matter - PM10 0 3.48
Particulate Matter - PM2.5 0 2.51
Sulfur Oxides 0 0.22
Volatile Organic Compounds 0 34.55

Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr)
Acetaldehyde (CAS #75070) 0 5140
Acrolein (CAS #107028) 0 3160
Benzene (Including Benzene From Gasoline) (CAS #71432) 0 280
Formaldehyde (CAS #50000) 0 32500
Generic HAPs (CAS #GHAPS) 0 1140
Hexane (CAS #110543) 0 880
Methanol (CAS #67561) 0 1540
Change (TPY) Total (TPY)
Total HAPs 0 22.32

DAQE-AN104140015-21
Page 5

SECTION I: GENERAL PROVISIONS

I.1 All definitions, terms, abbreviations, and references used in this AO conform to those used in
the UAC R307 and 40 CFR. Unless noted otherwise, references cited in these AO conditions
refer to those rules. [R307-101]

I.2 The limits set forth in this AO shall not be exceeded without prior approval. [R307-401]

I.3 Modifications to the equipment or processes approved by this AO that could affect the
emissions covered by this AO must be reviewed and approved. [R307-401-1]

I.4 All records referenced in this AO or in other applicable rules, which are required to be kept by
the owner/operator, shall be made available to the Director or Director's representative upon
request, and the records shall include the five-year period prior to the date of the request.
Unless otherwise specified in this AO or in other applicable state and federal rules, records
shall be kept for a minimum of five (5) years. [R307-401-8]

I.5 At all times, including periods of startup, shutdown, and malfunction, owners and operators
shall, to the extent practicable, maintain and operate any equipment approved under this AO,
including associated air pollution control equipment, in a manner consistent with good air
pollution control practice for minimizing emissions. Determination of whether acceptable
operating and maintenance procedures are being used will be based on information available to
the Director which may include, but is not limited to, monitoring results, opacity observations,
review of operating and maintenance procedures, and inspection of the source. All
maintenance performed on equipment authorized by this AO shall be recorded. [R307-401-4]

I.6 The owner/operator shall comply with UAC R307-107. General Requirements: Breakdowns.
[R307-107]

I.7 The owner/operator shall comply with UAC R307-150 Series. Emission Inventories.
[R307-150]

I.8 The owner/operator shall submit documentation of the status of construction or modification of
the JMS Engines #3 and #4 to the Director within 18 months from the date of this AO. This
AO may become invalid if construction is not commenced within 18 months from the date of
this AO, if construction is discontinued for 18 months or more, or if construction extends
beyond the anticipated schedule. To ensure proper credit when notifying the Director, send the
documentation to the Director, attn.: NSR Section. [R307-401-18]

SECTION II: PERMITTED EQUIPMENT

II.A THE APPROVED EQUIPMENT

II.A.1 CVWRF
Source Wide

II.A.2 Waukesha Engines #5
Waukesha Model 8L-AT27GL generator engine
Rating: 1,340 kW
Fuel Type: Natural Gas/Digester Gas
NSPS Applicability: None
MACT Applicability: 40 CFR 63 Subpart ZZZZ

DAQE-AN104140015-21
Page 6

II.A.3 JMS Engines #1 & #2
Two (2) GE Jenbacher Model JMS 612-F28F02 generator engines
Rating: 2,509 hp (each)
Fuel Type: Natural Gas/Digester Gas
NSPS Applicability: 40 CFR 60 Subpart JJJJ
MACT Applicability: 40 CFR 63 Subpart ZZZZ

II.A.4 JMS Engines #3 & #4
Two (2) GE Jenbacher Model JMS 612-F28F02 generator engines
Rating: 2,509 hp (each)
Fuel Type: Natural Gas/Digester Gas
NSPS Applicability: 40 CFR 60 Subpart JJJJ
MACT Applicability: 40 CFR 63 Subpart ZZZZ

II.A.5 H2S Removal Vessel
H2S removal vessel upstream of the engines used to treat digester gas.

II.A.6 Emergency Generator Engines #2 & #3
Rating: 896 hp each
Quantity: Two (2)
Fuel: Diesel
NSPS Applicability: None
MACT Applicability: 40 CFR 63 Subpart ZZZZ

II.A.7 Emergency Generator Engines #4
Rating: 349 hp
Quantity: One (1)
Fuel: Diesel
NSPS Applicability: None
MACT Applicability: 40 CFR 63 Subpart ZZZZ

II.A.8 Emergency Generator Engines #5 and #6
Rating: 800 hp each
Quantity: Two (2)
Fuel: Diesel
Manufacture Date: 2016
NSPS Applicability: 40 CFR 60 Subpart IIII
MACT Applicability: 40 CFR 63 Subpart ZZZZ

II.A.9 Emergency Generator Engines #7 and #8
Rating: 1,341 hp each
Quantity: Two (2)
Fuel: Diesel
Manufacture Date: 2015
NSPS Applicability: 40 CFR 60 Subpart IIII
MACT Applicability: 40 CFR 63 Subpart ZZZZ

II.A.10 Paint Booth
Water-wash paint booth

II.A.11 Three (3) Waste Oil Heaters
Rating: 0.28, 0.33, and 0.35 MMBtu/hr each
Fuel: Used Oil

II.A.12 Two (2) Digester Gas Flares
Fuel Type: Digester Gas

DAQE-AN104140015-21
Page 7

II.A.13 Boiler #1
Rating: 6.05 MMBtu/hr
Fuel: Natural Gas
NSPS Applicability: None
MACT Applicability: None

II.A.14 Boiler #2
Rating: 6.28 MMBtu/hr
Fuel: Natural Gas
NSPS Applicability: None
MACT Applicability: None

SECTION II: SPECIAL PROVISIONS

II.B REQUIREMENTS AND LIMITATIONS

II.B.1 Site Wide Requirements
II.B.1.a Visible emissions from the following emission points shall not exceed the following values:

A. Digester Gas/Natural Gas Engines - 10% opacity

B. Diesel Generators - 20% opacity

C. Boilers - 10% opacity

D. Fugitive Emissions - 15% opacity

E. Digester Gas Flare - 10% opacity

F. Spray Booth Exhaust - 10% opacity.

[R307-401-8]

II.B.1.a.1 Opacity observations of emissions from all engines, boilers, fugitive emissions, and the spray
booth exhaust shall be conducted according to 40 CFR 60, Appendix A, Method 9; opacity
observations of emissions from the digester gas flares shall be conducted according to 40 CFR
60, Appendix A, Method 22. [R307-401-8]

II.B.2 Waukesha Digester Gas/Natural Gas Engines Requirements
II.B.2.a The owner/operator shall use only natural gas and/or digester gas as fuel in all Waukesha and
JMS generator engines. [R307-401-8]

II.B.2.b The owner/operator shall limit emissions from all Waukesha and JMS generator engines to 53
tons of NOx per rolling 12-month period. [R307-401-8]

II.B.2.b.1 The owner/operator shall determine compliance with a rolling 12-month total by calculating a
new 12-month total using data from the previous 12 months. Monthly calculations shall be made
no later than 20 days after the end of each calendar month. The owner/operator shall
demonstrate compliance with the rolling 12-month limit by using the following equation for each
engine and the appropriate conversion factors:

NOx = [Emission rate of engine] x [Hours of operation of engine].

[R307-401-8]

DAQE-AN104140015-21
Page 8

II.B.2.b.2 Records of hours of operation shall be kept for all periods when the engines are in operation.
Continuous recording is required. Records shall be kept on a daily basis. [R307-401-8]

II.B.2.b.3 The owner/operator shall use the most recent stack test data as the emission rates for the rolling
12-month total calculations.

Emission rates for the JMS engines shall be measured as required in II.B.3.a. The most recent
stack test data shall be used to determine compliance with the rolling 12-month NOx limit. For
the period between installation and the initial stack test, the NOx emission limit in II.B.3.a shall
be used.

A stack test of the Waukesha engine shall be conducted on an annual basis for as long as the
engine remains in operation. Testing shall be performed in accordance with the requirements in
II.B.3.a.2 through II.B.3.a.5 and II.B.3.a.8 through II.B.3.a.11 of this AO. The source may be
tested at any time if directed by the Director.

[R307-401-8]

II.B.3 JMS Digester Gas/Natural Gas Engines Requirements
II.B.3.a Emissions to the atmosphere from each of the natural gas/digester gas fired engines shall not
exceed the following rates:

Source: Digester Gas/Natural Gas Engines (Each Stack)

Pollutant Limit (g/bhp-hr)
NOx 0.55
CO 2.50
VOCs (NMHC) 0.3.

[R307-401-8]

DAQE-AN104140015-21
Page 9

II.B.3.a.1 Frequency

Emission Point Pollutant Status Test Frequency

JMS Engine #1 NOx * +
CO * +
VOC * +

JMS Engine #2 NOx * +
CO * +
VOC * +

JMS Engine #3 NOx ** +
CO ** +
VOC ** +

JMS Engine #4 NOx ** +
CO ** +
VOC ** +

* Initial compliance testing was required and completed.

** Initial compliance testing is required. The initial test date shall be performed as soon as
possible and in no case later than 180 days after the startup of a new emission source, an existing
source without an AO, or the granting of an AO to an existing emission source that has not had
an initial compliance test performed. If an existing source is modified, a compliance test is
required on the modified emission point that has an emission rate limit.

+ Test every three (3) years. The Director may require testing at any time.

[R307-401-8]

II.B.3.a.2 Notification

The Director shall be notified at least 30 days prior to conducting any required emission testing.
A source test protocol shall be submitted to DAQ when the testing notification is submitted to
the Director. The source test protocol shall be approved by the Director prior to performing the
test(s). The source test protocol shall outline the proposed test methodologies, stack(s) to be
tested, and procedures to be used. A pretest conference shall be held, if directed by the Director.

[R307-401-8]

II.B.3.a.3 Sample Location

The sampling location shall be designed to conform to the requirements of 40 CFR 60, Appendix
A, Method 1, or other methods as approved by EPA and acceptable to the Director. An
Occupational Safety and Health Administration (OSHA) or Mine Safety and Health
Administration (MSHA) approved access shall be provided to the test location.

[R307-401-8]

DAQE-AN104140015-21
Page 10

II.B.3.a.4 Volumetric Flow Rate Test Methods

40 CFR 60, Appendix A, Method 2 or other EPA approved testing methods acceptable to the
Director.

[R307-401-8]

II.B.3.a.5 NOx Test Methods

40 CFR 60, Appendix A, Method 7, 7A, 7B, 7C, 7D, 7E or other EPA approved testing methods
acceptable to the Director.

[R307-401-8]

II.B.3.a.6 CO Test Methods

40 CFR 60, Appendix A, Method 10, or other EPA approved testing methods acceptable to the
Director.

[R307-401-8]

II.B.3.a.7 VOC Test Method

40 CFR 60, Appendix A, Method 18, or other approved testing methods acceptable to the
Director.

[R307-401-8]

II.B.3.a.8 Calculations

To determine mass emission rates (lb./hr., etc.) the pollutant concentration as determined by the
appropriate methods above shall be multiplied by the volumetric flow rate and any necessary
conversion factors determined by the Director, to give the results in the specified units of the
emission limitation.

[R307-401-8]

II.B.3.a.9 New Source Operation

For a new source/emission point, the production rate during all compliance testing shall be no
less than 90% of the production rate listed in this AO. If the maximum AO allowable production
rate has not been achieved at the time of the test, the following procedure shall be followed:

1) Testing shall be at no less than 90% of the production rate achieved to date.

2) If the test is passed, the new maximum allowable production rate shall be
110% of the tested achieved rate, but not more than the maximum allowable
production rate. This new allowable maximum production rate shall remain
in effect until successfully tested at a higher rate.

3) The owner/operator shall request a higher production rate when necessary.
Testing at no less than 90% of the higher rate shall be conducted. A new
maximum production rate (110% of the new rate) will then be allowed if the
test is successful. This process may be repeated until the maximum AO
production rate is achieved.

[R307-401-8]

DAQE-AN104140015-21
Page 11

II.B.3.a.10 Existing Source Operation

For an existing source/emission point, the production rate during all compliance testing shall be
no less than 90% of the maximum production achieved in the previous three (3) years.

[R307-401-8]

II.B.3.a.11 The results of stack testing shall be submitted to the Director within 60 days of completion of the
testing. Reports shall clearly identify results as compared to permit limits and indicate
compliance status. [R307-401-8]

II.B.4 Emergency Generator Engines Requirements

II.B.4.a Each emergency generator engine shall not exceed 100 hours of operation for testing and
maintenance per rolling 12-month period. The 100 hours of operation for testing and
maintenance purposes may include up to 50 hours per calendar year for operation in
nonemergency situations as provided in 40 CFR 60.4211(f). [R307-401-8]

II.B.4.a.1 Compliance with the limit of the hours of operation shall be determined by installation of an hour
meter on the emergency generator engine. Records documenting the operation of the emergency
generator engine shall be kept in a log and shall include the following:

A. The date the emergency generator engine was used;

B. The duration of operation each day in hours; and

C. The reason for the emergency generator engine usage.

[R307-401-8]

II.B.4.a.2 To determine compliance with the rolling 12-month total, the owner/operator shall calculate a
new 12-month total by the twentieth day of each month using data from the previous 12 months.
[R307-401-8]

II.B.4.a.3 Records of hours of operation shall be determined by installing a non-resettable hour meter for
the emergency generator engine. [40 CFR 63 Subpart ZZZZ]

II.B.5 Fuel Requirements
II.B.5.a The owner/operator shall only use diesel fuel (fuel oil #1, #2 or diesel fuel oil additives) in the
emergency generator engines. All diesel burned shall meet the definition of ultra-low sulfur
diesel (ULSD), and contain no more than 15 ppm sulfur. [R307-401-8]

II.B.5.a.1 To demonstrate compliance with the diesel fuel requirements for any diesel fuel purchased, the
owner/operator shall keep and maintain fuel purchase invoices. The fuel purchase invoices shall
indicate that the diesel fuel meets the ULSD requirements, or the owner/operator shall obtain
certification of sulfur content from the fuel supplier. [R307-401-8]

PERMIT HISTORY

This Approval Order shall supersede (if a modification) or will be based on the following documents:

Incorporates Additional Information dated February 23, 2021
Is Derived From NOI dated December 4, 2020
Supersedes DAQE-AN104140014-19 dated August 6, 2019

DAQE-AN104140015-21
Page 12

ACRONYMS

The following lists commonly used acronyms and associated translations as they apply to this document:

40 CFR Title 40 of the Code of Federal Regulations
AO Approval Order
BACT Best Available Control Technology
CAA Clean Air Act
CAAA Clean Air Act Amendments
CDS Classification Data System (used by Environmental Protection Agency to classify
sources by size/type)
CEM Continuous emissions monitor
CEMS Continuous emissions monitoring system
CFR Code of Federal Regulations
CMS Continuous monitoring system
CO Carbon monoxide
CO2 Carbon Dioxide
CO2e Carbon Dioxide Equivalent - Title 40 of the Code of Federal Regulations Part 98,
Subpart A, Table A-1
COM Continuous opacity monitor
DAQ/UDAQ Division of Air Quality
DAQE This is a document tracking code for internal Division of Air Quality use
EPA Environmental Protection Agency
FDCP Fugitive dust control plan
GHG Greenhouse Gas(es) - Title 40 of the Code of Federal Regulations 52.21 (b)(49)(i)
GWP Global Warming Potential - Title 40 of the Code of Federal Regulations Part 86.1818-
12(a)
HAP or HAPs Hazardous air pollutant(s)
ITA Intent to Approve
LB/YR Pounds per year
MACT Maximum Achievable Control Technology
MMBTU Million British Thermal Units
NAA Nonattainment Area
NAAQS National Ambient Air Quality Standards
NESHAP National Emission Standards for Hazardous Air Pollutants
NOI Notice of Intent
NOx Oxides of nitrogen
NSPS New Source Performance Standard
NSR New Source Review
PM10 Particulate matter less than 10 microns in size
PM2.5 Particulate matter less than 2.5 microns in size
PSD Prevention of Significant Deterioration
PTE Potential to Emit
R307 Rules Series 307
R307-401 Rules Series 307 - Section 401
SO2 Sulfur dioxide
Title IV Title IV of the Clean Air Act
Title V Title V of the Clean Air Act
TPY Tons per year
UAC Utah Administrative Code
VOC Volatile organic compounds

Appendix K

Compliance Plan, Schedule, and
Certification

Central Valley Water Reclamation Facility
800 West Central Valley Road, Salt Lake City, UT 84119-3379  [phone]  [phone]
COMPLIANCE PLAN
Central Valley Water Reclamation Facility
Permit No. 3500191001

Title V Permit Date: March 16, 2020

Date of Last Revision: September 9, 2021*

*Subsections below are numbered according to the current Title V permit updated September 9,
2021. Two subsections that were removed as part of that update are numbered below according
to the previous version of the permit which applied from March 1 2021 to September 9, 2021.
Subsections are noted accordingly.

Page 2 of 24

Term Description of Permit Provision
Method used
to determine
compliance
status
Compliance Status Other info relevant to compliance status,
including references to any and all
deviations; reason for “undetermined”
status; any excursions or exceedances (for
CAM provisions only); etc.
Continuous Intermittent Undetermined
Section I General Provisions
I.B Was the source operated in
compliance with the operating
permit?
Recordkeeping X

I.C.3 Did the permittee furnish
information requested by the
Executive Secretary?
Recordkeeping X

I.G.1 Did the permittee pay the annual
emission fee? Recordkeeping X

I.G.2 Was the fee paid on time?
Recordkeeping X

I.K Were all application forms, reports
and certifications submitted
pursuant to the permit properly
certified by a responsible official?
Recordkeeping X

I.L.1 Did the permittee submit this
compliance certification complete &
on time?
Recordkeeping X

I.L.2 Did the permittee also send all
compliance certifications to EPA? Recordkeeping X

I.S.1.a Did the permittee properly retain all
records required by the permit? Recordkeeping X

I.S.1.b Did the permittee include all
applicable information in records of
monitoring required by the permit?
Recordkeeping X

I.S.2.a Did the permittee submit monitoring
reports every six months, or more
frequently if specified in Section II,
and were all instances of deviation
Recordkeeping X

Page 3 of 24

Term Description of Permit Provision
Method used
to determine
compliance
status
Compliance Status Other info relevant to compliance status,
including references to any and all
deviations; reason for “undetermined”
status; any excursions or exceedances (for
CAM provisions only); etc.
Continuous Intermittent Undetermined
from permit requirements clearly
identified in the monitoring reports?
I.S.2.b Were all reports submitted pursuant
to I.S.2.a certified by a responsible
official?
Recordkeeping X

I.S.2.c Did the permittee promptly notify
the Executive Secretary of all
deviations from permit
requirements?
Recordkeeping X

I.U Did the permittee submit the
inventory required by R307-150 in
accordance with the requirements of
that rule? (This covers R307-150, 155
and 158 if listed in permit)
Recordkeeping X

Section II Special Provisions
II.B.1 Source-wide Provisions
II.B.1.a Did the permittee ensure that sulfur
content of any fuel burned was not
greater than 0.85 lb/MMBtu?
Recordkeeping X

II.B.1.a.2 Did the permittee properly maintain
records of each delivery of fuel oil,
including supplier name and
statement from supplier regarding
sulfur content?
Recordkeeping X

II.B.1.b Was all equipment under this permit
maintained and operated, to the
extent practicable, in a manner
consistent with good air pollution
control practice for minimizing
emissions?
Recordkeeping X

Page 4 of 24

Term Description of Permit Provision
Method used
to determine
compliance
status
Compliance Status Other info relevant to compliance status,
including references to any and all
deviations; reason for “undetermined”
status; any excursions or exceedances (for
CAM provisions only); etc.
Continuous Intermittent Undetermined
II.B.1.b.2 Did permittee properly document
activities performed to assure
proper operation and maintenance?
Recordkeeping X

II.B.2 New Digester Gas Engines
II.B.2.a Did permittee comply with visible
emissions opacity limit of 10%?
Opacity
observation
reports
X

II.B.2.a.1 Did permittee perform quarterly
opacity observations for each unit by
an individual trained on the
observation procedures of 40 CFR
60, Appendix A, Method 9?
Recordkeeping,
Opacity
observation
reports
X

II.B.2.a.1 Did permittee perform opacity
determination for each unit by a
certified observer within 24 hours of
the initial observation in all cases
where visible emissions other than
water vapor were observed?
Recordkeeping,
Opacity
observation
reports
X
CVWRF has elected to keep several
personnel certified in Method 9 and
perform opacity determination quarterly
by certified observer, regardless of
whether emissions are observed.
II.B.2.a.1 Were opacity determinations
performed in accordance with 40
CFR 60, Appendix A, Method 9?
Recordkeeping,
Opacity
observation
reports
X

II.B.2.a.2 Did permittee keep a log of opacity
observations for each quarter that
included location, description, and
either the date of observation or
note that the unit was not operated
in the quarter?
Opacity
observation
reports
X

II.B.2.a.2 Did permittee keep a log of opacity
determinations in all cases where
visible emissions other than water
vapor were observed that included
location, description, date/time of
Recordkeeping,
Opacity
observation
reports
X

Page 5 of 24

Term Description of Permit Provision
Method used
to determine
compliance
status
Compliance Status Other info relevant to compliance status,
including references to any and all
deviations; reason for “undetermined”
status; any excursions or exceedances (for
CAM provisions only); etc.
Continuous Intermittent Undetermined
determination, percent opacity, and
all other information required by
Method 9?
II.B.2.a.2 Did the permittee maintain the
required records in accordance with
General Provisions?
Recordkeeping X

II.B.2.b Did the permittee operate and
maintain each engine that achieves
emission standards as required in 40
CFR 60.4233?
Recordkeeping,
Stack test
reports
X

II.B.2.b Were air-to-fuel ratio controllers
maintained and operated
appropriately in order to ensure
proper operation of the engine and
control device and to minimize
emissions at all times?
Recordkeeping X
No emission after-treatment control
devices.
II.B.2.b Was each engine maintained and
operated, to the extent practicable,
in a manner consistent with good air
pollution control practice for
minimizing emissions?
Recordkeeping,
Stack test
reports
X
Follow manufacturer recommendations
II.B.2.b In the operation and maintenance of
each engine, did the permittee
comply with the applicable general
provisions in 40 CFR 60.1 thru 60.19
as identified in Table 3 of 40 CFR
Part 60, Subpart JJJJ?
Recordkeeping X

II.B.2.b.2 Did the permittee keep a
maintenance plan and records of
conducted maintenance?
Recordkeeping,
Manufacturer
requirements
X

II.B.2.b.2 Did the permittee keep
documentation that each engine is
certified to meet the emission
Recordkeeping X
Engines are not certified.

Page 6 of 24

Term Description of Permit Provision
Method used
to determine
compliance
status
Compliance Status Other info relevant to compliance status,
including references to any and all
deviations; reason for “undetermined”
status; any excursions or exceedances (for
CAM provisions only); etc.
Continuous Intermittent Undetermined
standards as well as applicable
information required in 40 CFR parts
90, 1048, 1054, and 1060?
II.B.2.b.2 Did the permittee keep
documentation that each engine
meets the emission standards?
Recordkeeping,
Stack test
reports
X

II.B.2.c.1 Did the permittee conduct
performance testing to demonstrate
compliance with emission standards,
including initial performance test
within 90 days of startup, and
subsequent testing every 8,760 hour
or 3 years, whichever is sooner?
Recordkeeping,
Stack test
reports
X

II.B.2.c.1 Did the permittee conduct
performance testing as specified in
40 CFR 60.4244 and in accordance
with permit requirements for sample
location, volumetric flow rate test
methods, NOx test methods, CO test
methods, VOC test methods, and
calculations?
Recordkeeping,
Stack test
reports
X

II.B.2.c.1 Was the production rate during
compliance testing at least 90% of
the production rate listed in the AO?
Recordkeeping,
Stack test
reports
X

II.B.2.c.1 Was the production rate during
compliance testing at least 90% of
the production rate achieved to
date?
Recordkeeping,
Stack test
reports
X

II.B.2.c.1 Was the production rate during
compliance testing at least 90% of
the maximum production rate
achieved in the previous 3 years?
Recordkeeping,
Stack test
reports
X

Page 7 of 24

Term Description of Permit Provision
Method used
to determine
compliance
status
Compliance Status Other info relevant to compliance status,
including references to any and all
deviations; reason for “undetermined”
status; any excursions or exceedances (for
CAM provisions only); etc.
Continuous Intermittent Undetermined
II.B.2.c.3 Was the Director notified and a
source test protocol submitted with
the required information (including
name of owner/operator, source
address, engine information,
emissions control equipment, and
fuel) at least 30 days prior to
conducting any required emission
testing?
Recordkeeping,
Stack test
protocol and
cover letters,
DAQ
confirmations,
X

II.B.2.c.3 Did the source test protocol outline
the test methodologies, stacks being
tested, and test procedures?
Recordkeeping,
Stack test
protocol
X

II.B.2.c.3 Was the source test protocol
approved by the Director prior to
performing the testing?
Recordkeeping,
DAQ
confirmations
X

II.B.2.c.3 Were the results of each
performance test submitted to the
Director within 60 days of test
completion?
Recordkeeping,
Stack test
report and
certification
letters
X

II.B.2.d.1 Did the permittee limit emissions
from all JMS engines to 53 tons of
NOx per rolling 12-month period?
Recordkeeping,
Stack test
reports
X
Applies after Sept 9, 2021. Added as part
of revision.
II.B.2.d.1 Did the permittee determine
compliance with a rolling 12-month
total by calculating a new 12-month
total using data from the previous 12
months?
Recordkeeping X

II.B.2.d.1 Did the permittee make the
calculations within 20 days after the
end of each calendar month?
Recordkeeping X

Page 8 of 24

Term Description of Permit Provision
Method used
to determine
compliance
status
Compliance Status Other info relevant to compliance status,
including references to any and all
deviations; reason for “undetermined”
status; any excursions or exceedances (for
CAM provisions only); etc.
Continuous Intermittent Undetermined
II.B.2.d.1 Did the permittee demonstrate
compliance with the 12-month limit
using the most recent stack test data
(or emission limits prior to first stack
test), the equation provided in the
permit, and appropriate conversion
factors?
Recordkeeping X

II.B.2.d.2 Did the permittee keep records of
hours of operation for all periods
when the engines were in
operation?
Recordkeeping X

II.B.2.d.2 Did the permittee keep and maintain
records on a daily basis as outlined
in the General Provisions?
Recordkeeping X

II.B.3 Old Digester Engines Section on Old Digester Engines is not included in current Title V permit (updated September 9, 2021)
II.B.3.a Did permittee comply with visible
emissions opacity limit of 10%?
Opacity
observation
reports
X
Not applicable. Engines permanently
removed prior to this period.
II.B.3.a.1 Did permittee perform quarterly
opacity observations for each unit by
an individual trained on the
observation procedures of 40 CFR
60, Appendix A, Method 9?
Recordkeeping,
Opacity
observation
reports
X
See comment to II.B.3.a above.
II.B.3.a.1 Did permittee perform opacity
determination for each unit by a
certified observer within 24 hours of
the initial observation in all cases
where visible emissions other than
water vapor were observed?
Recordkeeping,
Opacity
observation
reports
X
See comment to II.B.3.a above.
II.B.3.a.1 Were opacity determinations
performed in accordance with 40
CFR 60, Appendix A, Method 9?
Recordkeeping,
Opacity X
See comment to II.B.3.a above.

Page 9 of 24

Term Description of Permit Provision
Method used
to determine
compliance
status
Compliance Status Other info relevant to compliance status,
including references to any and all
deviations; reason for “undetermined”
status; any excursions or exceedances (for
CAM provisions only); etc.
Continuous Intermittent Undetermined
observation
reports
II.B.3.a.2 Did permittee keep a log of opacity
observations for each quarter that
included location, description, and
either the date of observation or
note that the unit was not operated
in the quarter?
Opacity
observation
reports
X
See comment to II.B.3.a above.
II.B.3.a.2 Did permittee keep a log of opacity
determinations in all cases where
visible emissions other than water
vapor were observed that included
location, description, date/time of
determination, percent opacity, and
all other information required by
Method 9?
Recordkeeping,
Opacity
observation
reports
X
See comment to II.B.3.a above.
II.B.3.a.2 Did the permittee maintain the
required records in accordance with
General Provisions?
Recordkeeping X
See comment to II.B.3.a above.
II.B.3.b Did the permittee limit emissions
from all Waukesha generator
engines to 53 tons of NOx per rolling
12-month period?
Recordkeeping X
See comment to II.B.3.a above.
II.B.3.b.1 Did the permittee determine
compliance with a rolling 12-month
total by calculating a new 12-month
total using data from the previous 12
months?
Recordkeeping X
See comment to II.B.3.a above.
II.B.3.b.1 Did the permittee make the
calculations within 20 days after the
end of each calendar month?
Recordkeeping X
See comment to II.B.3.a above.

Page 10 of 24

Term Description of Permit Provision
Method used
to determine
compliance
status
Compliance Status Other info relevant to compliance status,
including references to any and all
deviations; reason for “undetermined”
status; any excursions or exceedances (for
CAM provisions only); etc.
Continuous Intermittent Undetermined
II.B.3.b.1 Did the permittee demonstrate
compliance with the 12-month limit
using the most recent stack test
data, the equation provided in the
permit, and appropriate conversion
factors?
Recordkeeping X
See comment to II.B.3.a above.
II.B.3.b.1 Did the permittee conduct stack
testing on an annual basis for these
engines?
Recordkeeping,
Deviation
report
X
See comment to II.B.3.a above.
II.B.3.b.1 Did the permittee conduct
performance testing as specified in
40 CFR 60.4244 and in accordance
with permit requirements for sample
location, volumetric flow rate test
methods, NOx test methods, and
calculations?
Recordkeeping,
Deviation
report
X
See comment to II.B.3.a above.
II.B.3.b.1 Was the production rate during
compliance testing at least 90% of
the maximum production rate
achieved in the previous 3 years?
Recordkeeping,
Deviation
report
X
See comment to II.B.3.a above.
II.B.3.b.2 Did the permittee keep records of
hours of operation for all periods
when the engines were in
operation?
Recordkeeping X
See comment to II.B.3.a above.
II.B.3.b.2 Did the permittee keep and maintain
records on a daily basis as outlined
in the General Provisions?
Recordkeeping X
See comment to II.B.3.a above.
II.B.3.b.3 Was the Director notified and a
source test protocol submitted with
the required information at least 30
days prior to conducting any
required emission testing?
Recordkeeping,
Deviation
report
X
See comment to II.B.3.a above.

Page 11 of 24

Term Description of Permit Provision
Method used
to determine
compliance
status
Compliance Status Other info relevant to compliance status,
including references to any and all
deviations; reason for “undetermined”
status; any excursions or exceedances (for
CAM provisions only); etc.
Continuous Intermittent Undetermined
II.B.3.b.3 Did the source test protocol outline
the test methodologies, stacks being
tested, and test procedures?
Recordkeeping,
Stack test
reports
X
See comment to II.B.3.a above.
II.B.3.b.3 Was the source test protocol
approved by the Director prior to
performing the testing?
Recordkeeping,
Stack test
reports
X
See comment to II.B.3.a above.
II.B.3.c Did the permittee perform
maintenance as required by the
permit with regard to changing oil
and filter, inspecting spark plugs,
and inspection/replacement of
hoses and belts?
Recordkeeping X
See comment to II.B.3.a above.
II.B.3.c Did the permittee operate and
maintain the engine and after-
treatment control device according
to manufacturer’s emissions-related
written instructions or develop their
own maintenance plan which
provides to the extent practicable
for the maintenance and operation
of the engine in a manner consistent
with good air pollution control
practice for minimizing emissions?
Recordkeeping X
See comment to II.B.3.a above.
II.B.3.c Did the permittee continuously
comply with operating and
maintaining the engine according to
the manufacturer's emission-related
operation and maintenance
instructions or develop and follow
their own maintenance plan which
provides to the extent practicable
for the maintenance and operation
of the engine in a manner consistent
Recordkeeping X
See comment to II.B.3.a above.

Page 12 of 24

Term Description of Permit Provision
Method used
to determine
compliance
status
Compliance Status Other info relevant to compliance status,
including references to any and all
deviations; reason for “undetermined”
status; any excursions or exceedances (for
CAM provisions only); etc.
Continuous Intermittent Undetermined
with good air pollution control
practice for minimizing emissions?
II.B.3.c Did the permittee comply with the
applicable general provisions in 40
CFR 63.1-15 as identified in Table 8
of 40 CFR 63 Subpart ZZZZ?
Recordkeeping X
See comment to II.B.3.a above.
II.B.3.c.1 Did the permittee comply with the
applicable general provisions
regarding monitoring in 40 CFR 63.1-
15 as identified in Table 8 of 40 CFR
63 Subpart ZZZZ?
Recordkeeping X
See comment to II.B.3.a above.
II.B.3.c.2 Did the permittee maintain
operation and maintenance records
in accordance with the General
Provisions?
Recordkeeping X
See comment to II.B.3.a above.
II.B.3.c.2 Did records comply with 40 CFR
63.6655(a)? Recordkeeping X
See comment to II.B.3.a above.
II.B.3.c.2 Did the permittee comply with the
applicable general provisions
regarding recordkeeping in 40 CFR
63.1-15 as identified in Table 8 of 40
CFR 63 Subpart ZZZZ?
Recordkeeping X
See comment to II.B.3.a above.
II.B.3.c.3 Did the permittee comply with the
applicable general provisions
regarding reporting in 40 CFR 63.1-
15 as identified in Table 8 of 40 CFR
63 Subpart ZZZZ?
Recordkeeping X
See comment to II.B.3.a above.
II.B.3.c.3 Did the permittee report each
instance in which it did not meet the
applicable requirements in Table 8 of
40 CFR 63 Subpart ZZZZ?
Recordkeeping X
See comment to II.B.3.a above.
II.B.3 Diesel Fired Emergency Generators Section was II.B.4 in previous version of Title V permit (prior to September 9, 2021 update)

Page 13 of 24

Term Description of Permit Provision
Method used
to determine
compliance
status
Compliance Status Other info relevant to compliance status,
including references to any and all
deviations; reason for “undetermined”
status; any excursions or exceedances (for
CAM provisions only); etc.
Continuous Intermittent Undetermined
II.B.3.a Did permittee comply with visible
emissions opacity limit of 20%?
Opacity
observation
reports
X

II.B.3.a.1 Did permittee perform quarterly
opacity observations for each unit by
an individual trained on the
observation procedures of 40 CFR
60, Appendix A, Method 9?
Recordkeeping,
Opacity
observation
reports
X

II.B.3.a.1 Did permittee perform opacity
determination for each unit by a
certified observer within 24 hours of
the initial observation in all cases
where visible emissions other than
water vapor were observed?
Recordkeeping,
Opacity
observation
reports
X
CVWRF has elected to keep several
personnel certified in Method 9 and
perform opacity determination quarterly
by certified observer, regardless of
whether emissions are observed.
II.B.3.a.1 Were opacity determinations
performed in accordance with 40
CFR 60, Appendix A, Method 9?
Recordkeeping,
Opacity
observation
reports
X

II.B.3.a.2 Did permittee keep a log of opacity
observations for each quarter that
included location, description, and
either the date of observation or
note that the unit was not operated
in the quarter?
Opacity
observation
reports
X

II.B.3.a.2 Did permittee keep a log of opacity
determinations in all cases where
visible emissions other than water
vapor were observed that included
location, description, date/time of
determination, percent opacity, and
all other information required by
Method 9?
Recordkeeping,
Opacity
observation
reports
X
.

Page 14 of 24

Term Description of Permit Provision
Method used
to determine
compliance
status
Compliance Status Other info relevant to compliance status,
including references to any and all
deviations; reason for “undetermined”
status; any excursions or exceedances (for
CAM provisions only); etc.
Continuous Intermittent Undetermined
II.B.3.a.2 Did the permittee maintain the
required records in accordance with
General Provisions?
Recordkeeping X

II.B.4 Existing Emergency CI Engines Section was II.B.5 in previous version of Title V permit (prior to September 9, 2021 update)
II.B.4.a Did the permittee operate and
maintain each engine in a manner
consistent with safety and good air
pollution control practices for
minimizing emissions?
Recordkeeping X

II.B.4.a.2 Did the permittee document as well
as keep and maintain records listed
in the permit (including
notifications/reports, malfunction
information, performance testing,
maintenance, and corrective
actions), as applicable?
Recordkeeping X

II.B.4.b Did the permittee limit operation of
each engine other than emergency
operation, maintenance and testing,
operation in non-emergency
situations to 50 hours per year?
Recordkeeping X

II.B.4.b Did the permittee limit operation of
each engine for maintenance checks,
and readiness testing to 100 hours
per calendar year?
Recordkeeping X

II.B.4.b Did permittee change oil and filter
every 500 hours of operation or
annually, whichever comes first?
Recordkeeping X
Serviced every year
II.B.4.b Did permittee inspect air cleaner
every 1,000 hours of operation or
annually, whichever comes first?
Recordkeeping X
Serviced every year
II.B.4.b Did permittee inspect all hoses and
belts every 500 hours of operation Recordkeeping X

Page 15 of 24

Term Description of Permit Provision
Method used
to determine
compliance
status
Compliance Status Other info relevant to compliance status,
including references to any and all
deviations; reason for “undetermined”
status; any excursions or exceedances (for
CAM provisions only); etc.
Continuous Intermittent Undetermined
or annually, whichever comes first,
and replace as necessary?
II.B.4.b Did the permittee limit startup time
to only that needed for safe loading
of the engine, not exceeding 30
minutes, and minimize time engine
spent in idle?
Recordkeeping X

II.B.4.b Did the permittee comply with the
applicable general provisions in 40
CFR 63.1-15 as identified in Table 8
of 40 CFR 63 Subpart ZZZZ?
Recordkeeping X

II.B.4.b Did the permittee limit operation of
each engine for testing and
maintenance to 100 hours per rolling
12-month period (including up to 50
hours per calendar year for
operation in non-emergency
situations)?
Recordkeeping X

II.B.4.b.1 Is a non-resettable hour meter
installed on each engine? Recordkeeping X
II.B.4.b.1 Did the permittee operate and
maintain the engine and after-
treatment control device according
to manufacturer’s emissions-related
written instructions or develop the
their own maintenance plan which
provides to the extent practicable
for the maintenance and operation
of the engine in a manner consistent
with good air pollution control
practice for minimizing emissions?
Recordkeeping X
No emission after-treatment control
devices.

Page 16 of 24

Term Description of Permit Provision
Method used
to determine
compliance
status
Compliance Status Other info relevant to compliance status,
including references to any and all
deviations; reason for “undetermined”
status; any excursions or exceedances (for
CAM provisions only); etc.
Continuous Intermittent Undetermined
II.B.4.b.2 Did the permittee keep records
described in 40 CFR 63.6655(a)(1)-(5)
as applicable?
Recordkeeping X

II.B.4.b.2 Did the permittee keep records of
annual hours of operation, including
how many hours are spent for non-
emergency operation and demand
response if applicable?
Recordkeeping X

II.B.4.b.2 If engines were operated beyond
100 hours per year for maintenance
and testing, did the permittee
maintain records indicating that
Federal, State, or local standards
require maintenance and testing
beyond 100 hours per year?
Recordkeeping X

II.B.4.b.2 Did the permittee calculate a new
12-month total by the 20th day after
the end of each month?
Recordkeeping X

II.B.4.b.2 Did the permittee keep a log of
records documenting the operation
of each engine including the date of
operation, hours of duration, and
reason for usage?
Recordkeeping X

II.B.4.b.2 Did the permittee keep records that
demonstrate continuous compliance
with each applicable operating
limitation including, but not limited
to, the manufacturer's emission-
related operation and maintenance
instructions or the permittee-
developed maintenance plan?
Recordkeeping X

II.B.4.b.2 Did the permittee keep records of
the maintenance conducted to Recordkeeping X No emission after-treatment control
devices.

Page 17 of 24

Term Description of Permit Provision
Method used
to determine
compliance
status
Compliance Status Other info relevant to compliance status,
including references to any and all
deviations; reason for “undetermined”
status; any excursions or exceedances (for
CAM provisions only); etc.
Continuous Intermittent Undetermined
demonstrate that the permittee
operated and maintained the
affected emission engine and after-
treatment control device (if any)
according to their own maintenance
plan?
II.B.4.b.2 Did the permittee comply with
applicable general provisions
regarding recordkeeping in 40 CFR
63.1-15 as identified in Table 8 of 40
CFR 63 Subpart ZZZZ?
Recordkeeping X

II.B.4.b.2 Did the permittee maintain
operation and maintenance records
in accordance with the General
Provisions?
Recordkeeping X

II.B.4.b.3 Did the permittee report any failure
to perform the management
practice on the schedule required
under which the risk was deemed
unacceptable?
Recordkeeping X

II.B.4.b.3 Did the permittee comply with the
applicable general provisions
regarding reporting in 40 CFR 63.1-
15 as identified in Table 8 of 40 CFR
63 Subpart ZZZZ?
Recordkeeping X

II.B.4.b.3 Did the permittee report each
instance in which it did not meet the
applicable requirements in Table 8 of
40 CFR 63 Subpart ZZZZ?
Recordkeeping X

II.B.4.c Did the permittee only use ultra-low
sulfur diesel fuel in the engines? Recordkeeping X
II.B.4.c.2 Did the permittee keep and maintain
fuel purchase invoices? Recordkeeping X

Page 18 of 24

Term Description of Permit Provision
Method used
to determine
compliance
status
Compliance Status Other info relevant to compliance status,
including references to any and all
deviations; reason for “undetermined”
status; any excursions or exceedances (for
CAM provisions only); etc.
Continuous Intermittent Undetermined
II.B.4.c.2 Did fuel invoices indicate that fuel
meets ULSD requirements or did the
permittee obtain certification of
sulfur content from fuel supplier?
Recordkeeping,
Invoices X

II.B.4.c.2 Did the permittee maintain the
required records in accordance with
General Provisions?
Recordkeeping X

II.B.5 New Emergency CI Engines Section was II.B.6 in previous version of Title V permit (prior to September 9, 2021 update)
II.B.5.a Was each engine generator installed
and configured according to the
manufacturer's emission-related
specifications, except as permitted
by 40 CFR 60.4211(g)?
Recordkeeping X
Engines are package installation. No
significant installation requirements
pertaining to engine or emissions.
Engines were commissioned by the
supplier.
II.B.5.a Was each engine certified to, and
compliant with, the emission
standards assigned under 40 CFR
60.4202(a)(2)?
Recordkeeping X

II.B.5.a Did the permittee comply with
applicable general provisions in 40
CFR 60.1-19 as identified in Table 8
of 40CFR 60 Subpart IIII?
Recordkeeping X

II.B.5.a.2 Did the permittee maintain records
of engine certifications indicating
compliance with the above
referenced standards?
Recordkeeping X

II.B.5.a.2 Did the permittee maintain records
of engine certifications indicating
compliance with manufacturer's
specifications for engine installation
and configuration?
Recordkeeping X
Engines are package installation. No
significant installation requirements
pertaining to engine or emissions.
Engines were commissioned by the
supplier.
II.B.5.a.2 Did the permittee maintain the
applicable records in accordance
with General Provisions?
Recordkeeping X

Page 19 of 24

Term Description of Permit Provision
Method used
to determine
compliance
status
Compliance Status Other info relevant to compliance status,
including references to any and all
deviations; reason for “undetermined”
status; any excursions or exceedances (for
CAM provisions only); etc.
Continuous Intermittent Undetermined
II.B.5.b Did the permittee operate and
maintain the engine and after-
treatment control device according
to manufacturer’s emissions-related
written instructions?
Recordkeeping X
No emission after-treatment control
devices.
II.B.5.b Did the permittee comply with
applicable general provisions in 40
CFR part 89, as they apply?
Recordkeeping X

II.B.5.b.2 Did the permittee maintain records
demonstrating proper operation and
maintenance of each engine in
accordance with General Provisions?
Recordkeeping X

II.B.5.c Did each engine generator use diesel
fuel that meets the requirements of
40 CFR 90.510(b) for non-road diesel
fuel?
Recordkeeping X

II.B.5.c.1 Did the permittee either determine
fuel sulfur content expressed as
wt%, inspect the fuel sulfur content
expressed as wt%, or inspect
documentation provided by the
vendor that directly or indirectly
demonstrates compliance with this
provision?
Recordkeeping,
Invoices X

II.B.5.c.2 Did the permittee keep and maintain
fuel purchase invoices? Recordkeeping X
II.B.5.c.2 Did the permittee maintain the
required records in accordance with
General Provisions?
Recordkeeping X

II.B.5.d Did the permittee limit operation of
each engine other than emergency
operation, maintenance and testing,
emergency demand response, and
Recordkeeping X

Page 20 of 24

Term Description of Permit Provision
Method used
to determine
compliance
status
Compliance Status Other info relevant to compliance status,
including references to any and all
deviations; reason for “undetermined”
status; any excursions or exceedances (for
CAM provisions only); etc.
Continuous Intermittent Undetermined
operation in non-emergency
situations to 50 hours per year?
II.B.5.d Did the permittee limit operation of
each engine for testing and
maintenance to 100 hours per
calendar year?
Recordkeeping X

II.B.5.d Did the permittee limit operation of
each engine for testing and
maintenance to 100 hours per rolling
12-month period (including up to 50
hours per calendar year for
operation in non-emergency
situations)?
Recordkeeping X

II.B.5.d Was a non-resettable hour meter
installed on each engine prior to
startup?
Recordkeeping X

II.B.5.d.2 Were usage records for each engine
kept on a monthly basis which
distinguished between maintenance-
related hours and emergency use-
related hours?
Recordkeeping X

II.B.5.d.2 Was compliance with the 100 hour,
rolling 12-month limit determined by
installation of an hour meter, or by
recording hours of operation in an
operations log?
Recordkeeping X

II.B.5.d.2 Did the permittee calculate a new
12-month total by the 20th day after
the end of each month?
Recordkeeping X

II.B.5.d.2 Did the permittee keep a log of
records documenting the operation
of each engine including the date of
Recordkeeping X

Page 21 of 24

Term Description of Permit Provision
Method used
to determine
compliance
status
Compliance Status Other info relevant to compliance status,
including references to any and all
deviations; reason for “undetermined”
status; any excursions or exceedances (for
CAM provisions only); etc.
Continuous Intermittent Undetermined
operation, hours of duration, and
reason for usage?
II.B.6 Digester Gas Flares Section was II.B.7 in previous version of Title V permit (prior to September 9, 2021 update)
II.B.6.a Did permittee comply with visible
emissions opacity limit of 10%?
Opacity
observation
reports
X

II.B.6.a.1 Did permittee perform quarterly
opacity observations of each unit by
an individual trained on the
observation procedures of 40 CFR
60, Appendix A, Method 9?
Recordkeeping,
Opacity
observation
reports
X

II.B.6.a.1 Did permittee perform opacity
determination for each unit by a
certified observer within 24 hours of
the initial observation in all cases
where visible emissions other than
water vapor were observed?
Recordkeeping,
Opacity
observation
reports
X
CVWRF has elected to keep several
personnel certified in Method 9 and
perform opacity determination quarterly
by certified observer, regardless of
whether emissions are observed.
II.B.6.a.1 Were opacity determinations
performed in accordance with 40
CFR 60, Appendix A, Method 9?
Recordkeeping,
Opacity
observation
reports
X

II.B.6.a.2 Did permittee keep a log of opacity
observations for each quarter that
included location, description, and
either the date of observation or
note that the unit was not operated
in the quarter?
Opacity
observation
reports
X

II.B.6.a.2 Did permittee keep a log of opacity
determinations in all cases where
visible emissions other than water
vapor were observed that included
location, description, date/time of
determination, percent opacity, and
Recordkeeping,
Opacity
observation
reports
X

Page 22 of 24

Term Description of Permit Provision
Method used
to determine
compliance
status
Compliance Status Other info relevant to compliance status,
including references to any and all
deviations; reason for “undetermined”
status; any excursions or exceedances (for
CAM provisions only); etc.
Continuous Intermittent Undetermined
all other information required by
Method 9?
II.B.6.a.2 Did the permittee maintain the
required records in accordance with
General Provisions?
Recordkeeping X

II.B.7 Boilers Section was II.B.8 in previous version of Title V permit (prior to September 9, 2021 update)
II.B.7.a Did permittee comply with visible
emissions opacity limit of 10%?
Opacity
observation
reports
X

II.B.7.a.1 Did permittee perform quarterly
opacity observations of each unit by
an individual trained on the
observation procedures of 40 CFR
60, Appendix A, Method 9?
Recordkeeping,
Opacity
observation
reports
X

II.B.7.a.1 Did permittee perform opacity
determination for each unit by a
certified observer within 24 hours of
the initial observation in all cases
where visible emissions other than
water vapor were observed?
Recordkeeping,
Opacity
observation
reports
X
CVWRF has elected to keep several
personnel certified in Method 9 and
perform opacity determination quarterly
by certified observer, regardless of
whether emissions are observed.
II.B.7.a.1 Were opacity determinations
performed in accordance with 40
CFR 60, Appendix A, Method 9?
Opacity
observation
reports
X

II.B.7.a.2 Did permittee keep a log of opacity
observations for each quarter that
included location, description, and
either the date of observation or
note that the unit was not operated
in the quarter?
Recordkeeping,
Opacity
observation
reports
X

II.B.7.a.2 Did permittee keep a log of opacity
determinations in all cases where
visible emissions other than water
vapor were observed that included
Opacity
observation
reports
X

Page 23 of 24

Term Description of Permit Provision
Method used
to determine
compliance
status
Compliance Status Other info relevant to compliance status,
including references to any and all
deviations; reason for “undetermined”
status; any excursions or exceedances (for
CAM provisions only); etc.
Continuous Intermittent Undetermined
location, description, date/time of
determination, percent opacity, and
all other information required by
Method 9?
II.B.7.a.2 Did the permittee maintain the
required records in accordance with
General Provisions?
Recordkeeping X

II.B.9 Paint Booth Section on Paint Booth is not included in current Title V permit (updated September 9, 2021)
II.B.9.a Did permittee comply with visible
emissions opacity limit of 10%? Recordkeeping X Paint Booth was never operated during
period.
II.B.9.a.1 Did permittee perform quarterly
opacity observations of each unit by
an individual trained on the
observation procedures of 40 CFR
60, Appendix A, Method 9?
Recordkeeping X
See comment to II.B.9.a above.
II.B.9.a.1 Did permittee perform opacity
determination for each unit by a
certified observer within 24 hours of
the initial observation in all cases
where visible emissions other than
water vapor were observed?
Recordkeeping X
See comment to II.B.9.a above.
II.B.9.a.1 Were opacity determinations
performed in accordance with 40
CFR 60, Appendix A, Method 9?
Recordkeeping X
See comment to II.B.9.a above.
II.B.9.a.2 Did permittee keep a log of opacity
observations for each quarter that
included location, description, and
either the date of observation or
note that the unit was not operated
in the quarter?
Recordkeeping X
See comment to II.B.9.a above.
II.B.9.a.2 Did permittee keep a log of opacity
determinations in all cases where
visible emissions other than water
Recordkeeping X
See comment to II.B.9.a above.

Page 24 of 24

Term Description of Permit Provision
Method used
to determine
compliance
status
Compliance Status Other info relevant to compliance status,
including references to any and all
deviations; reason for “undetermined”
status; any excursions or exceedances (for
CAM provisions only); etc.
Continuous Intermittent Undetermined
vapor were observed that included
location, description, date/time of
determination, percent opacity, and
all other information required by
Method 9?
II.B.9.a.2 Did the permittee maintain the
required records in accordance with
General Provisions?
Recordkeeping X
See comment to II.B.9.a above.
Reviewer Comments
Did the permittee comply with the
requirements of AO DAQE-
AN104140015-21?
Recordkeeping X
Requirements of the AO were
incorporated into the Title V provisions.

Compliance Schedule

ACTION FREQUENCY DEADLINE (IF APPLICABLE) PERSON RESPONSIBLE APPLICABLE PERMIT TERMS
MAINTAIN RECORDS Daily N/A Chief Engineer and
Cogen Supervisor
I.S.1
ENSURE USE OF ULTRA-LOW SULFUR FUEL Daily N/A Plant Superintendent II.B.1.a, II.B.4.c, II.B.5.c,
MAINTAIN RECORDS OF FUEL DELIVERIES Daily N/A Plant Superintendent II.B.1.a.2, II.B.4.c.2, II.B.5.c.2,
MINIMIZE EMISSIONS FROM ALL POINT SOURCE
EQUIPMENT THRU GOOD O&M PRACTICES
Daily N/A Cogen Supervisor II.B.1.b.1, II.B.2.b, II.B.4.a,
II.B.4.b, II.B.5.b
DOCUMENT OPERATION AND MAINTENANCE
ACTIVITIES
Daily N/A Cogen Supervisor II.B.1.b.2, II.B.2.b.2, II.B.4.a,2,
II.B.4.b.2, II.B.5.b.2
KEEP RECORD OF EMERGENCY ENGINE HOURS Daily N/A Cogen Supervisor II.B.4.b.2
KEEP RECORDS OF EMERGENCY ENGINE
CERTIFICATIONS
Daily N/A Cogen Supervisor II.B.5.a.2
OPERATE ENGINES IN ACCORDANCE WITH
MANUFACTURER RECOMMENDATIONS
Daily N/A Cogen Supervisor II.B.5.b
CALCULATE AND RECORD 12M ROLLING TOTAL
JMS ENGINES NOX EMISSIONS TO ENSURE
COMPLIANCE WITH EMISSIONS LIMIT
Monthly By 20th Chief Engineer II.B.2.d
CALCULATE AND RECORD 12M ROLLING TOTAL
EMERGENCY ENGINE HOURS TO ENSURE
COMPLIANCE WITH HOUR LIMITS
Monthly By 20th Chief Engineer II.B.4.b.2, II.B.5.d.2
CALCULATE AND RECORD CALENDAR YEAR TOTAL
EMERGENCY ENGINE HOURS TO ENSURE
COMPLIANCE WITH HOUR LIMITS
Monthly By 20th Chief Engineer II.B.4.b.2, II.B.5.d.2
PERFORM VISIBLE EMISSIONS OBSERVATIONS TO
ENSURE COMPLIANCE WITH OPACITY LIMITS
Quarterly End of Calendar Quarter Cogen Supervisor II.B.2.a, II.B.3.a, II.B.6.a, II.B.7.a
KEEP LOG OF OPACITY OBSERVATIONS Quarterly End of Calendar Quarter Chief Engineer II.B.2.a.2, II.B.3.a.2, II.B.6.a.2,
II.B.7.a.2
SUBMIT MONITORING REPORT Semi-annual As stated in Title V Permit Chief Engineer I.K, I.S.3.a,
PAY ANNUAL EMISSIONS FEE Annual Oct 1st Chief Engineer I.G
SUBMIT COMPLIANCE CERTIFICATION Annual As stated in Title V Permit Chief Engineer I.K, I.L, I.S.2, I.S.3
SUBMIT EMISSIONS INVENTORY Annual April 15th Chief Engineer I.U
PERFORM MAINTENANCE OF EMERGENCY
ENGINES
500 hours or
Annually (shorter)
Before frequency is exceeded Cogen Supervisor II.B.4.b
PERFORM STACK TESTING JMS ENGINES TO
ENSURE COMPLIANCE WITH EMISSIONS LIMITS
8760 hours or 3
years (shorter)
Before frequency is exceeded Chief Engineer and
Cogen Supervisor
II.B.2.c
SUBMIT STACK TEST PROTOCOL AND RESULTS 8760 hours or 3
years (shorter)
Before frequency is exceeded Chief Engineer II.B.2.c.3
SUBMIT TITLE V PERMIT RENEWAL APPLICATION 5 years As stated in Title V Permit Chief Engineer I.D
PROVIDE REQUESTED INFORMATION TO DAQ/EPA Upon requested N/A Chief Engineer I.C.3
COMPLY WITH INSPECTIONS Upon requested N/A Chief Engineer and
Cogen Supervisor
I.J