OXIDES OF SULFUR ANNUAL EMISSION REPORT

Company Name Tesoro West CoastSite Name Salt Lake City RefineryCompany ID - 1987Site ID - 10335NOTE: Be aware that this report uses different methods of calculating emissions than are required for the 2006 Emissions Inventory.

1 1998 1234/3283 01 10200701 No 4 

2

2006 (using 1998 method of calculation) 1234/3283 01 10200701 No 4 

3

2006 (if method of calculation is different from 1998) 1234/3283 01 10200701 No 4 

This form is to be used by sources that have emitted 100 tons or more of SOx in any calendar year after 1999, and that are not subject to aci

(40CFR Part 75). Row 1 in the following table(s) contains historical inventory data for the listed component. Row 2 is used to calculate the 20was used in the historical data. The inputs required are in green font. To insert the new data you type over the top of the old data. Row 3 (shathe method of calculation from 1998 to 2006 (i.g. emission factors, % of sulfur, heating value, controls, breakdowns, estimation methods). If thdoes not work with the equation provided in row 3, the calculation should be provided in the row 4. Rows 3 and 4 should have the same calcu

Year DAQ ID

Pt Source

ID SCC Description of Process

NSPS 

(Yes/No)

Associated 

Stack ID

crude unit furnace pcrude unit furnace pcrude unit furnace p

Year DAQ ID

Pt Source

ID SCC

4

2006 Calculations

Description of Process

NSPS 

(Yes/No)

Associated 

Stack ID
1 1998 1235/3284 2 10200701 No 5 

2

2006 (using 1998 method of calculation) 1235/3284 2 10200701 No 5 

3

2006 (if method of calculation is different from 1998) 1235/3284 2 10200701 No 5 

2

2006 (using 1998 method of calculation) 1235/3284 2 10200701 No 5 

3

2006 (if method of calculation is different from 1998) 1235/3284 2 10200701 No 5 

1 1998 1236/3285 3 10200701 No 6 

ultraformer furnace (a,b,c,d,e) pultraformer furnace p

ultraformer furnace (a,b,c,d) p

Year DAQ ID

Pt Source

ID SCC

4

2006 Calculations

Description of Process

NSPS 

(Yes/No)

Associated 

Stack ID

regenerator heater p

Year DAQ ID

Pt Source

ID SCC

Description of Process

NSPS 

(Yes/No)

Associated 

Stack ID

ultraformer furnace pultraformer furnace(e) p

4

2006 Calculations
2

2006 (using 1998 method of calculation) 3285 3 10200701 No 6 

3

2006 (if method of calculation is different from 1998) 3285 3 10200701 No 6 

1 1998 3286 4 10201402 No 7 

2

2006 (using 1998 method of calculation) 3286 4 10201402 No 7 

3

2006 (if method of calculation is different from 1998) 3286 4 10201402 No 7 

2

2006 (using 1998 method of calculation) 3286 3 10201402 No 7 

regenerator heater pregenerator heater p

4

2006 Calculations

Year DAQ ID

Pt Source

ID SCC Description of Process

NSPS 

(Yes/No)

Associated 

Stack ID

p

FCU/CO boiler p

FCU/CO boiler pFCU/CO boiler

4

2006 Calculations

Description of Process

NSPS 

(Yes/No)

Associated 

Stack ID

Year DAQ ID 

Pt Source

ID SCC

Ultraformer Regen Furnace-F15 p
3

2006 (if method of calculation is different from 1998) 3286 3 10201402 No 7 

1 1998 3095 9 30600105 Yes 2056 

2

2006 (using 1998 method of calculation) 3095 9 30600105 Yes 2056 

3

2006 (if method of calculation is different from 1998) 3095 9 30600105 Yes 2056 

1 1998 3286 4 10201402 No 7 

2

2006 (using 1998 method of calculation) 3286 4 10201402 No 7 

Year DAQ ID

Pt Source

ID SCC Description of Process

NSPS 

(Yes/No)

Associated 

Stack ID

sulfur recovery unit asulfur recovery unit asulfur recovery unit a

Year DAQ ID

Pt Source

ID SCC

4

2006 Calculations

Description of Process

NSPS 

(Yes/No)

Associated 

Stack ID

FCU/CO boiler pFCU/CO boiler p

4

2006 Calculations

Ultraformer Regen Furnace-F15 p
3

2006 (if method of calculation is different from 1998) 3286 4 10201402 No 7 

1 1998 3287 5 10200701 No 8 

2

2006 (using 1998 method of calculation) 3287 5 10200701 No 8 

3

2006 (if method of calculation is different from 1998) 3287 5 10200701 No 8 

1 1998 3288 6 30600107 Yes 9 

2

2006 (using 1998 method of calculation) 3288 6 30600107 Yes 9 

FCU/CO boiler p

SCC Description of Process

NSPS 

(Yes/No)

Associated 

Stack ID

4

2006 Calculations

Year DAQ ID

Pt Source

ID

Boiler Plant pBoiler Plant pBoiler Plant p

Year DAQ ID

Pt Source

ID SCC

4

2006 Calculations

Description of Process

NSPS 

(Yes/No)

Associated 

Stack ID

ultraformer compressor nultraformer compressor n
3

2006 (if method of calculation is different from 1998) 3288 6 30600107 Yes 9 

1 1998 3289 7 30600903 Yes 10 

2

2006 (using 1998 method of calculation) 3289 7 30600903 Yes 10 

3

2006 (if method of calculation is different from 1998) 3289 7 30600903 Yes 10 

1 1998 3290 8 30600903 Yes 11 

2

2006 (using 1998 method of calculation) 3290 8 30600903 Yes 11 

ultraformer compressor n

Year DAQ ID

Pt Source

ID SCC

4

2006 Calculations

Description of Process

NSPS 

(Yes/No)

Associated 

Stack ID

south flare psouth flare psouth flare p

Year DAQ ID

Pt Source

ID SCC

4

2006 Calculations

Description of Process

NSPS 

(Yes/No)

Associated 

Stack ID

north flare pnorth flare p
3

2006 (if method of calculation is different from 1998) 3290 8 30600903 Yes 11 

1 1998 4350 5a 30600111 No 1789 

2

2006 (using 1998 method of calculation) 4350 5a 30600111 No 1789 

3

2006 (if method of calculation is different from 1998) 4350 5a 30600111 No 1789 

1 1998 14661 PLT 30600903 No 11 

2

2006 (using 1998 method of calculation) 14661 PLT 30600903 No 11 

north flare p

Year DAQ ID

Pt Source

ID SCC

4

2006 Calculations

Description of Process

NSPS 

(Yes/No)

Associated 

Stack ID

boiler plant Dboiler plant Dboiler plant D

Year DAQ ID

Pt Source

ID SCC

4

2006 Calculations

Description of Process

NSPS 

(Yes/No)

Associated 

Stack ID

Pilots nPilots n
3

2006 (if method of calculation is different from 1998) 14661 PLT 30600903 No 11 

EQUIPMENT NOT RUN IN 1998 THAT EMITS SOx

176646 DDU F680176647 DDU F681176648 Cogen East Turbine176650 Cogen West Turbine

174127/3284 2

174128 5

174129 5

174130 5

174131 6

16396 10, 11

Pilots n

4

2006 Calculations

DDU F680 

DAQ ID

Pt Source

ID Description of Process EF Method

Ultraformer Furance F-1 (e) DDU F681 Cogen East Turbine 

Boiler Plant #4 Boiler Plant #5 Boiler Plant #6 

Cogen West Turbine 

K-1 B Compressor EngineSRU Flare
OXIDES OF SULFUR ANNUAL EMISSION REPORT

Company Name Tesoro West CoastSite Name Salt Lake City Refinery

Units/Yr

mmscf 46.25 H2S ppm 0 0 Explainmmscf 0 H2S ppm 799 btu/cu ft 0.038 Analyzedmmscf 0 H2S ppm 0 0 Analyzed

Units/Yr

%

Ash

Prim

Heating

Value Units

%

Sulfur

How Sulfur Content is 

calculated

eporting requirements 

he same method that 

ulate any changes in 

g the SOx emissions 

06 Emission Inventory.

ughput Generating 

Emissions

Sulfur Plant

Design 

Rate Units

If Throughput is a Fuel 

Sulfur PlantSulfur Plant

ughput Generating 

Emissions

Design 

Rate Units

If Throughput is a Fuel 

Prim

Heating

Value Units

%

Sulfur

How Sulfur Content is 

calculated

%

Ash
mmscf 46.25 H2S ppm 0 0 Explain

mmscf 0 H2S ppm 799 btu/cu ft Analyzedmmscf 0 H2S ppm 0 0

Units/Yr

mmscf 0 H2S ppm 799 btu/cu ft 0.038 Analyzedmmscf 0 H2S ppm 0 0

Units/Yr

mmscf 326000 lbs/hr 0 0 Explain

Sulfur PlantSulfur PlantSulfur Plant

ughput Generating 

Emissions

Design 

Rate Units

If Throughput is a Fuel 

Prim

Sulfur Plant

Heating

Value Units

%

Sulfur

How Sulfur Content is 

calculated

%

Ash

ughput Generating 

Emissions

Design 

Rate Units

If Throughput is a Fuel 

Prim

Heating

Value Units

%

Sulfur

How Sulfur Content is 

calculated

%

Ash

Sulfur PlantSulfur Plant
mmscf 326000 lbs/hr 0 0 Explain

mmscf 326000 lbs/hr 0 0 Explain

Units/Yr

hr/yr 777100 mmbtu 669 btu/cu ft 0.005 Explain 0days/yr 777100 mmbtu 799 btu/cu ft Explain 0

hr/yr 777100 mmbtu 799 btu/cu ft Explain 0

Units/Yr

mmscf 777100 mmbtu 799 btu/cu ft 0.038 Explain 0

Sulfur PlantSulfur Plant

Heating

Value Units

%

Sulfur

How Sulfur Content is 

calculated

%

Ash

Prim

Unspecified 

ughput Generating 

Emissions

Design 

Rate Units

If Throughput is a Fuel

Unspecified Unspecified 

%

Ash

ughput Generating 

Emissions

Design 

Rate Units

If Throughput is a Fuel

Heating

Value Units

%

Sulfur

How Sulfur Content is 

calculated

Prim

Unspecified 
hr/yr 777100 mmbtu 799 btu/cu ft 0.038 Explain

0

Units/Yr

hr/yr 22000 scf/hr

0

0

lbs/day 22000 scf/hr 799 0 0.038lbs/day 22000 scf/hr 799 0 0.038

Units/Yr

hr/yr 777100 mmbtu 669 btu/cu ft 0.005 Explain

0

hr/yr 777100 mmbtu btu/cu ft Explain

0

Heating

Value Units

%

Sulfur

How Sulfur Content is 

calculated

%

Ash

Prim

Sulfur Plant

ughput Generating 

Emissions

Design 

Rate Units

If Throughput is a Fuel

Sulfur PlantSulfur Plant

Heating

Value Units

%

Sulfur

How Sulfur Content is 

calculated

%

Ash

Prim

Unspecified 

ughput Generating 

Emissions

Design 

Rate Units

If Throughput is a Fuel

Unspecified Unspecified 
hr/yr 777100 mmbtu btu/cu ft Explain 0

Units/Yr

mmscf 46.25 H2S ppm 669 btu/cu ft 0.005 Explain 0

mbbls/yr 0 H2S ppm 620 btu/cu ft 0 Analyzed 0mmscf 0 H2S ppm 620 btu/cu ft 0 Analyzed 0

Units/Yr

mmscf 8760 hrs 1000 btu/cu ft 0 Explain 0

mmscf 8760 hrs 950 btu/cu ft 0 Explain 0

Unspecified 

ughput Generating 

Emissions

Design 

Rate Units

If Throughput is a Fuel 

%

Ash

Prim

Sulfur Plant

Heating

Value Units

%

Sulfur

How Sulfur Content is 

calculated

Sulfur PlantSulfur Plant

ughput Generating 

Emissions

Design 

Rate Units

If Throughput is a Fuel 

Prim

Heating

Value Units

%

Sulfur

How Sulfur Content is 

calculated

%

Ash
mmscf 0 hrs 0 btu/cu ft 0 AP-42 EF 0

Units/Yr

mmscf 39939 mmbtu 669 btu/cu ft 0.005 Explain 0

mmscf 39939 mmbtu 620 btu/cu ft 0 Analyzed 0mmscf 39939 mmbtu 620 btu/cu ft 0 Explain 0

Units/Yr

mmscf 39939 mmbtu 669 btu/cu ft 0.005 Explain 0

mmscf 39939 mmbtu 799 btu/cu ft 0.038 Analyzed 0

ughput Generating 

Emissions

Design 

Rate Units

If Throughput is a Fuel 

Prim

Heating

Value Units

%

Sulfur

How Sulfur Content is 

calculated

%

Ash

ughput Generating 

Emissions

Design 

Rate Units

If Throughput is a Fuel 

Prim

Heating

Value Units

%

Sulfur

How Sulfur Content is 

calculated

%

Ash
mmscf 39939 mmbtu 620 btu/cu ft 0 0

Units/Yr

mgal 141921 btu/gal 1.1 Explain 0

mgal 141921 btu/gal 1.1 Explain 0mgal 141921 btu/gal Explain 0

Units/Yr

mmscf 1050 btu/cu ft 0 0mmscf 0 799 btu/cu ft 0.038 0

Heating

Value Units

%

Sulfur

How Sulfur Content is 

calculated

%

Ash

Prim

ughput Generating 

Emissions

Design 

Rate Units

If Throughput is a Fuel

Heating

Value Units

%

Sulfur

How Sulfur Content is 

calculated

%

Ash

Prim

ughput Generating 

Emissions

Design 

Rate Units

If Throughput is a Fuel
0 0 799 btu/cu ft 0.038 0

0.270.432.743.23

0.00

0.00

0.00

0.00

0.000.276.95

2006 Sox 

Tons/year
Secondary Control

45 0 0.00 0 2 mole % H2S in gas. Scf figured usin

45 0 0.00 0 2 mole % H2S in gas. Scf figured usin45 0 0.00 0

Secondary Control

Estimate 

Control 

Efficiency 

(%)

Emissions

(tons/yr)

Emissions 

from 

Breakdown 

(tons/year)

Estimate 

Code

Control 

Code (See 

List)

Name of

Secondary 

Control

Control 

Code (See 

List)

0.006.02

5.4479

Control 

Efficiency 

(%)

Emissions

(tons/yr)

Emissions 

from 

Breakdown 

(tons/year)

Control 

Code (See 

List)

Name of

Secondary 

Control

Control 

Code (See 

List)

Estimate 

Code Estimate 
45 0 0.00 0 2 mole % H2S in gas. Scf figured usin

45 0 0.00 0 2 mole % H2S in gas. Scf figured usin45 0 0.00 0

Secondary Control

45 0 0.00 0 2 mole % H2S in gas. Scf figured usin

45 0 0.00 0

Secondary Control

45 0 0.00 0.0 2 mole % H2S in gas + 0.03 tons Amin

4.200.002.47

Control 

Efficiency 

(%)

Emissions

(tons/yr)

Emissions 

from 

Breakdown 

(tons/year)

Control 

Code (See 

List)

Name of

Secondary 

Control

Control 

Code (See 

List)

Estimate 

Code Estimate 

0.20

Control 

Efficiency 

(%)

Emissions

(tons/yr)

Emissions 

from 

Breakdown 

(tons/year)

Control 

Code (See 

List)

Name of

Secondary 

Control

Control 

Code (See 

List)

Estimate 

Code Estimate 

0.00

0.9549
45 0 0.00 0.0 2 mole % H2S in gas + 0.03 tons Amin

45 0 0.00 0.0 0

Secondary Control

99 0 0.00 0 10 average CEM reading99 0 0.00 0 10 average CEM reading

99 0 0.00 0 10 average CEM reading + SO3 estimat

Secondary Control

99 0 0.00 0 2 Engineering Judgement

0.000.00

Control 

Efficiency 

(%)

Emissions

(tons/yr)

Emissions 

from 

Breakdown 

(tons/year)

Control 

Code (See 

List)

Name of

Secondary 

Control

Control 

Code (See 

List)

Estimate 

Code Estimate 

673.25581.66

Name of

Secondary 

Control

Control 

Code (See 

List)

Estimate 

Code Estimate 

Control 

Efficiency 

(%)

Emissions

(tons/yr)

Emissions 

from 

Breakdown 

(tons/year)

Control 

Code (See 

List)

0.21

641.19
99 0 0.00 0 2 Engineering Judgement

Secondary Control

45 0 95.00 5% 10 average CEM reading + shutdown a45 0 95.00 10 average CEM reading + SRU flaring 45 0 95.00 0.00 0

Secondary Control

99 0 0.00 0 10 average CEM reading99 0 0.00 0 10 average CEM reading

Control 

Efficiency 

(%)

Emissions

(tons/yr)

Emissions 

from 

Breakdown 

(tons/year)

Control 

Code (See 

List)

Name of

Secondary 

Control

Control 

Code (See 

List)

329.50

Estimate 

Code Estimate 

248.84246.38

Control 

Efficiency 

(%)

Emissions

(tons/yr)

Emissions 

from 

Breakdown 

(tons/year)

Control 

Code (See 

List)

Name of

Secondary 

Control

Control 

Code (See 

List)

581.66

Estimate 

Code Estimate 

0.000.00
99 0 0.00 0 0 average CEM reading + SO3 estimat

Secondary Control

45 0 0 0 1 mole % H2S in gas

45 0 0 0 1 mole % H2S in gas45 0 0 0

Secondary Control

0 2 mole % H2S in gas0 2 mole % H2S in gas

0.00

Estimate 

Control 

Efficiency 

(%)

Emissions

(tons/yr)

Control 

Code (See 

List)

Control 

Code (See 

List)

Name of

Secondary 

Control

Emissions 

from 

Breakdown 

(tons/year)

Estimate 

Code

9.840.000.00

Control 

Efficiency 

(%)

Emissions

(tons/yr)

Emissions 

from 

Breakdown 

(tons/year)

Control 

Code (See 

List)

Name of

Secondary 

Control

Control 

Code (See 

List)

Estimate 

Code Estimate 

0.06

0.005
0 0

Secondary Control

0 2 mole % H2S in gas. 

0.13 2 mole % H2S in gas. 

0 0

Secondary Control

0 2 mole % H2S in fuel gas. 

0.36 2 mole % H2S in fuel gas. 

0.00

Control 

Efficiency 

(%)

Emissions

(tons/yr)

Emissions 

from 

Breakdown 

(tons/year)

Control 

Code (See 

List)

Name of

Secondary 

Control

Control 

Code (See 

List)

Estimate 

Code Estimate 

1.060.001.00

Control 

Efficiency 

(%)

Emissions

(tons/yr)

Emissions 

from 

Breakdown 

(tons/year)

Control 

Code (See 

List)

Name of

Secondary 

Control

Control 

Code (See 

List)

Estimate 

Code Estimate 

0.340.78
0 0

Secondary Control

0 5 User calculated based on agency's e0 5 User calculated based on agency's e0 0

Secondary Control

0 8 Table 1.4-1 (10/96)0 8 Table 1.4-1 (10/96)

0.00

Control 

Efficiency 

(%)

Emissions

(tons/yr)

Emissions 

from 

Breakdown 

(tons/year)

Control 

Code (See 

List)

Name of

Secondary 

Control

Control 

Code (See 

List)

183.37

Estimate 

Code Estimate 

0.000.00

Control 

Efficiency 

(%)

Emissions

(tons/yr)

Emissions 

from 

Breakdown 

(tons/year)

Control 

Code (See 

List)

Name of

Secondary 

Control

Control 

Code (See 

List)

0.03

Estimate 

Code Estimate 

0.038
0.00 0 0
8.5 lbs/mmscf Show calculation

6.4 lbs/mmscf Show calculation0.0 lbs/mmscf

Emission 

Factor Units How mole % H2S is calculated

Emission 

Factor Units How mole % H2S is calculated
8.5 lbs/mmscf Show calculation

6.4 lbs/mmscf Show calculation

0 lbs/mmscf Show calculation

6.4 lbs/mmscf Show calculation

0 lbs/mmscf Show calculation

8.5 lbs/mmscf Show calculation

Emission 

Factor Units How mole % H2S is calculated

Emission 

Factor Units How mole % H2S is calculated
0.0 lbs/mmscf Show calculation

0.0 lbs/mmscf Show calculation

132.8 LB/HOUR

3639.0 lb/day3639.0 lb/day

6.4 lbs/mmscf

Emission 

Factor Units

Emission 

Factor Units
6.4 lbs/mmscf

60.1 LB/HOUR

1350.0 lb/day1350.0 lb/day

132.8 LB/HOUR

0.0 LB/HOUR

Emission 

Factor Units

Emission 

Factor Units
0.0 LB/HOUR

8.5 lbs/mmscf Show calculation0.0 lbs/mmscf Show calculation0.0 lbs/mmscf Show calculation8.5 lbs/mmscf Show calculation0.6 lbs/mmscf Show calculation

Emission 

Factor Units How mole % H2S is calculated

Emission 

Factor Units How mole % H2S is calculated
0.0 lbs/mmscf Show calculation

8.5 lbs/mmscf Show calculation6.4 lbs/mmscf Show calculation0.0 lb/mmscf Show calculation8.5 lbs/mmscf Show calculation6.4 lbs/mmscf Show calculation

Emission 

Factor Units How mole % H2S is calculated

Emission 

Factor Units How mole % H2S is calculated
0.0 lbs/mmscf Show calculation

205.0 lbs/1000 gals205.0 lbs/1000 gals

0.0 lbs/1000 gals0.6 lbs/mmscf0.6 lbs/mmscf

Emission 

Factor Units

Emission 

Factor Units
0.0 lbs/mmscf

Component Current Adjusted

1234/3283 5.4479 5.44791235/3284 2.47 2.47

1235/3284 0.9549 0.9549

3285 0.00 0.003286 673.25 641.193286 0.21 0.213095 248.84 246.383286 0.00 0.003287 0.00 0.00

3288 0.005 0.005

3289 1.00 1.003290 0.78 0.784350 0.00 0.00

14661 0.038 0.038

Other 6.95 6.95TOTAL 939.9357 905.4123