OXIDES OF SULFUR ANNUAL EMISSION REPORT

Company Name Sunnyside Cogeneration AssociatesSite Name Sunnyside Cogeneration FacilityCompany ID - 448Site ID - 10096NOTE: Be aware that this report uses different methods of calculating emissions than are required for the 2006 Emissions Inventory.

1 1998 11096 01.0 10200501 No 3236 Processed Coal 

2

2006 (using 1998 method of calculation) 11096 01.0 10200501 No 3236 Processed Coal 

3

2006 (if method of calculation is different from 1998) 11096 01.0 10200501 No 3236 Processed Coal 

1 1998 11097 01.0A 10200501 No 3236 

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 acid rain continuous 

(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 2006 process emiss

was 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 (shaded) is used to sh

the method of calculation from 1998 to 2006 (i.g. emission factors, % of sulfur, heating value, controls, breakdowns, estimation methods). If the current method 

does 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 calculations as contain

Year DAQ ID

Pt Source

ID SCC Description of Process

NSPS 

(Yes/No)

Associated 

Stack ID

Raw Material or Fuel 

used

T

CFBC BOILER/TURBINECFBC BOILER/TURBINECFBC BOILER/TURBINE

SCC Description of Process

NSPS 

(Yes/No)

Associated 

Stack ID

4

2006 Calculations

Raw Material or Fuel 

used

T

Year DAQ ID

Pt Source

ID

CFBC BOILER/TURBINE Diesel #2 (Diesel)
2

2006 (using 1998 method of calculation) 11097/11096 01.0A 10200501 No 3236 

3

2006 (if method of calculation is different from 1998) 11096 01.0A 10200501 No 3236 

1 1998 11098 02.0 10200501 No 3237 Diesel #2 (Diesel) 

2

2006 (using 1998 method of calculation) 11098 02.0 10200501 No 3237 Diesel #2 (Diesel) 

2006 (if method of calculation is different from 1998) 11098 2 10200501 No 3237 Diesel #2 (Diesel) 

1 1998 11098 02.0 10200501 No 3237 

2

2006 (using 1998 method of calculation) 11098/174573 02.0 10200501 No 3237 

CFBC BOILER/TURBINE Diesel #2 (Diesel)

4

2006 Calculations

Raw Material or Fuel 

Year DAQ ID used

Pt Source

ID SCC

CFBC BOILER/TURBINE Diesel #2 (Diesel)

T

DIESEL GENERATOR/WELDERWELDER

Description of Process

NSPS 

(Yes/No)

Associated 

Stack ID

WELDER

4

2006 Calculations

Description of Process

NSPS 

(Yes/No)

Associated 

Stack ID

Raw Material or Fuel 

Year DAQ ID used

Pt Source

ID SCC

T

DIESEL GENERATOR Diesel #2 (Diesel)DIESEL GENERATOR Diesel #2 (Diesel)
2006 (if method of 

calculation is different from 1998) 11098/174573 02.0 10200501 No 3237 

1 1998 174573 02.0 10200501 No 3237 

2

2006 (using 1998 method of calculation) 174573 02.0 10200501 No 3237 

2006 (if method of calculation is different from 1998) 174573 02.0 10200501 No 3237 

1998 Formula(s) for calculating emissions

11096

E=435091 tons of coal/year x 5303 Btu/lb x (1 mmbtu/1000000 Btu) x .41 lb Sox/mmbtu) = 945.99 ton/yr SOx

*11097/11096 (per AP-42 1.3-1) (fuel oil)

EF = 157 x .85 lb/1000 gal  = 133.45

11098 (per AP-42 appendix A-4, A-6, and 3.3-6)

120 gal/year)/42 gal/BBL =2.86 BBLs/year5,900,000 btu/BBL

Description of Process

NSPS 

(Yes/No)

Associated 

Stack ID

Raw Material or Fuel 

Year DAQ ID used

Pt Source

ID SCC

T

DIESEL GENERATOR/WELDER Diesel #2 (Diesel)DIESEL GENERATOR/WELDER Diesel #2 (Diesel)DIESEL GENERATOR/WELDER Diesel #2 (Diesel)

4

2006 Calculations

4

2006 Calculations

DIESEL GENERATOR Diesel #2 (Diesel)
5,900,000 btu/BBL x 2.86 BBL = 16.874 mmBTUs

0.29 lbs/mmBTUs16.874 mmBTUs x .29 lbs/mmBTUs / 2000 lbs/ton = .00245 tons

BTU/lb of coal changed from 6458 in 1996 to 5303 in 1998.2006 Formula(s) for calculating emissions

11096

E=___________tons of coal/year x _________ Btu/lb x (1 mmbtu/1000000 Btu) x .36 lb SOx/mmbtu) = _________

*11097/11096 (per AP-42 1.3-1) (Distillate oil)

EF = ___________ x .30 lb/1000 gal  = _____________

11098 (per AP-42 appendix A-4, A-6, and 3.3-6)

____________ gal/year)/42 gal/BBL =____________ BBLs/year5,900,000 btu/BBL5,900,000 btu/BBL x _____________ BBL = _______________ mmBTUs0.29 lbs/mmBTUs_______________ mmBTUs x .29 lbs/mmBTUs / 2000 lbs/ton = ______________ tons

EQUIPMENT WITH NO SOx IN 1998 

DAQ ID Point Source ID Description of Process EF Method How sulfur content was calculated 
OXIDES OF SULFUR ANNUAL EMISSION REPORT

65 tons/hour 5303 Btu/lb 1.09 Analytical data 52.5 71 

65 tons/hour 5686 Btu/lb 0.84 Analytical data 48.86 71 

65 tons/hour 5686 Btu/lb 0.84 48.86 71 

1400 gal/hour 19460 Btu/lb 0.85 Analytical data 0 71 

Name of

Primary Control

Control 

Code (See 

List)

If Throughput is a Fuel Primary Control

Heating

Value Units

%

Sulfur

How Sulfur 

Content is 

calculated

%

Ash

FBC w/Limestone AdditiveFBC w/Limestone Additive

S

FBC w/Limestone Additive

Design Rate UnitsDesign Rate Units

If Throughput is a Fuel Primary Control

Heating

Value Units

%

Sulfur

How Sulfur 

Content is 

calculated

%

Ash

Name of

Primary Control

Control 

Code (See 

List)

S

FBC w/Limestone Additive
1400 gal/hour 19460 Btu/lb 0.25 Analytical data 0 71 

1400 gal/hour 19460 Btu/lb 0.25 Analytical data 0 71 

13.6 gal/hour 19460 Btu/lb 0.85 Analytical data 0

5 gal/hour 19460 Btu/lb 0.25 Analytical data 013.6 gal/hour 19460 Btu/lb 0

13.6 gal/hour 19460 Btu/lb 0.85 Analytical data 0

13.6 gal/hour 19460 Btu/lb 0.25 Analytical data 0

FBC w/Limestone AdditiveFBC w/Limestone Additive

Design Rate Units 

If Throughput is a Fuel

Heating

Value Units

%

Sulfur

Control 

Code (See 

List)

S

Primary Control

%

Ash

Name of

Primary Control

How Sulfur 

Content is 

calculated

Design Rate Units

If Throughput is a Fuel

Heating

Value Units

%

Sulfur

How Sulfur 

Content is 

calculated

Primary Control

%

Ash

Name of

Primary Control

Control 

Code (See 

List)

S
13.6 gal/hour 19460 Btu/lb 0

13.6 gal/hour 19460 Btu/lb 0.85 Analytical data 0

13.6 gal/hour 19460 Btu/lb 0.3 Analytical data 013.6 gal/hour 19460 Btu/lb 0

COMPONENT CURRENT ADJUSTED

11096 856.248 856.24811096 1.279 1.27911098 0.002 0.002

11098/174573 0.020 0.020174573/11098 0.000 0.000

TOTAL 857.550 857.550

Mobile 1.33 1.33GRAND TOTAL 858.880 858.880

Design Rate Units

If Throughput is a Fuel

Heating

Value Units

%

Sulfur

How Sulfur 

Content is 

calculated

Primary Control

%

Ash

Name of

Primary Control

Control 

Code (See 

List)

S

86 945.988 0 10 CEM 0.41 lb/mmbtu

86 856.248 5.87 10 CEM 0.32 lb/mmbtu

86 856.248 5.87 10 Stack Test 0.32 lb/mmbtu86 24.025 0 3 AP42 1.3 133.45 lb/1000 gal

Control 

Efficiency (%)

Emissions

(tons/yr)

Emissions 

from 

Breakdown 

(tons/year)

Estimate 

Code

Estimate 

Method

Emission 

Factor Units

Emissions 

from 

Breakdown 

(tons/year)

Estimate 

Code

Estimate 

Method

Emission 

Factor

Control 

Efficiency (%)

Emissions

(tons/yr) Units
86 1.279 0 3 AP42 1.3 35.5 lb/1000 gal

86 1.279 0 3 AP42 1.4 35.5 lb/1000 gal

0.002 0 8 AP42 3.3 0.29 lb/mmbtu0.002 0 8 AP42 3.3 0.29 lb/mmbtu 7.13

0.000 0 0.29 lb/mmbtu 7.13

0.004 0 8 AP42 3.3 0.29 lb/mmbtu0.020 0 8 AP42 3.3 0.29 lb/mmbtu

Estimate 

Code

Estimate 

Method

Emission 

Factor Units

Control 

Efficiency (%)

Emissions

(tons/yr)

Emissions 

from 

Breakdown 

(tons/year)

Emission 

Factor Units

Control 

Efficiency (%)

Emissions

(tons/yr)

Emissions 

from 

Breakdown 

(tons/year)

Estimate 

Code

Estimate 

Method

Density 

lbs/gal
0.000 0

0.000 0 8 AP42 3.3 0.29 lb/mmbtu0.000 0 8 AP42 3.3 0.29 lb/mmbtu

0.000 0

Emission 

Factor Units

Control 

Efficiency (%)

Emissions

(tons/yr)

Emissions 

from 

Breakdown 

(tons/year)

Estimate 

Code

Estimate 

Method