ANNUAL SULFUR DIOXIDE EMISSION REPORT

ANNUAL SULFUR DIOXIDE EMISSION REPORT 

Company Name EnCana Oil & Gas (USA) Inc. CompanSite Name Lisbon Plant Site NamCompany ID - 1761Site ID - 10034NOTE: Be aware that this report uses different methods of calculating emissions than are required for the 2006 Emissions Inventory.

Amount Units/Yr

1 1998 5538 4.1 30600904 Yes 3004 388 mmscf 

2

2006 (using 1998 method of calculation) 5538 4.1 30600904 Yes 3004 101.81 mmscf 

3

2006 (if method of calculation is different from 1998) 5538 4.1 30600904 Yes 3004 0 mmscf 

1998 *Convert H2S to SOx

1 MSCF H2S x (Mole H2S/0.3793 MSCF H2S) x 1 mole SO2/1 mole H2S x 64.0628 lb SOx/1 Mole SO2= 168.897 lbs. 

Tons of SOx/yr = (MCF/yr x mole % H2S x 168.9 lbs SOx/2000

H2S average is 1.076

Total inlet gas stream for 1998 = 17171582 MCF/yrTotal inlet sulfur plant gas stream for 1998 = 4,599792 MCF/yr

Average gas chromatograph H2S for inlet plant gas stream = 1.076%

Average gas chromatograph H2S for inlet sulfur plant gas stream = 4.08%Tons of SOx in Plant inlet gas stream = 15888 tons/SOx/yr

Tons of SOx in sulfur plant inlet gas stream = 15849 tons SOx/yr

DIFFERENCE 39 tons SOx/yr

Calculation:

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 

Volume (mmscf) 7.855 7.604 9.148 7.922 8.903 7.787 9.283 8.129 6.653 6.27 14.71 Mole% H2S 0.6832% 0.0000% 0.0000% 0.0124% 0.0000% 0.0000% 0.0000% 0.0920% 0.0000% 0.0105% 0.1813% 0SO2 emissions(tons) 4.53 0.00 0.00 0.08 0.00 0.00 0.00 0.63 0.00 0.06 2.25 Breakdown SO2(tons) 7.1495 

FORMULAS

CONVERSION OF H2S TO SOx1 MSCF H2S * (MOLE H2S/0.3793 MSCF H2S * 1 MOLE SO2/1 MOLE H2S * 64.0628 LB SO2/1 MOLE SO2 = 168.897 LB SO2 168.897 LB SO2

FORMULA FOR CALCULATING TONS/YR SOXTONS SOx/YEAR = (MCF/YEAR * MOLE % H2S * 168.9 LBS SO2)/2000

This form is to be used by sources that have emitted 100 tons or more of SO2 in any calendar year after 1999, and that are not subject to acid rain continuous monitoring reporting requirements 

(40CFR Part 75). Row 1 in the following table(s) contains 1998 historical inventory data for the listed component. Row 2 is used to calculate the 2006 process emissions using the same method that was used in 1998. 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 show and calculate any changes in the method of 

calculation from 1998 to 2006 (i.g. emission factors, % of sulfur, heating value, controls, breakdowns, estimation methods). If the current method of calculating the SO2 emissions does not work with the 

equation provided in row 3, the calculation should be provided in row 4. Rows 3 and 4 should have the same calculations as contained in the 2006 Emission Inventory.

Year DAQ ID

Pt Source

ID SCC Description of Process

NSPS 

(Yes/No)

Associated 

Stack ID

Raw Material or Fuel 

used

Throughput Generating Emissions

Flares Natural Gas

Design Rate Un

Flares Natural Gas

Flares Natural Gas

4

2006 Calculations

Monthly gas volume (mmscf) and mole%H2S from composite samples were used to predict monthly emissions. These emissions were then totaled to determine Operating Year 2006 emissions.SO2 emissions from when H2S gas is routed to the flare during an emergency breakdown of the SEI are now included in the total of SO2 emissions from the flare. 
ANNUAL SULFUR DIOXIDE EMISSION REPORT

ANNUAL SULFUR DIOXIDE EMISSION REPORT

& Gas (USA) Inc.

Secondary Control

0 * 39 2 Mass balance Show calculatio

0 ** 15.605 7.1495 2 Mass balance 168.8974 lbs

Mole % was obmonthly compo

0 0 2 Mass balance

%

Ash

Name of

Primary Control

How Sulfur Content is 

calculated

Estimate 

Method

Emission 

Factor Units How mole % H

Control 

Efficiency 

(%)

Emissions

(tons/yr)

Emissions 

from 

Breakdown 

(tons/yr)

Estimate 

Code

Control 

Code (See 

List)

Name of

Secondary 

Control

Control 

Code 

(See List)

Throughput is a Fuel Primary Control
ANNUAL SULFUR DIOXIDE EMISSION REPORT
ANNUAL SULFUR DIOXIDE EMISSION REPORT
ANNUAL SULFUR DIOXIDE EMISSION REPORT

Amount Units/Yr

1 1998 5539 4.2 30609904 Yes 3005 511 mmscf 

2

2006 (using 1998 method of calculation) 5539 4.2 30609904 Yes 3005 275.65 mmscf 

3

2006 (if method of calculation is different from 1998) 5539 4.2 30609904 Yes 3005 275.65 mmscf EQUIPMENT NOT RUN IN 1998 THAT EMITS SOx

DAQ ID POINT SOURCE ID DESCRIPTION OF PROCESS

2006 SOx 

TONS/YEAR

5524 1.1 Reciprocating Driven IC Engine #1 0.01

5525 1.2 #2 KVG Reciprocating Driven IC 05526 1.3 Reciprocating Driven IC Engine #3 0.015527 1.4 Reciprocating Driven IC Engine #4 0.0135528 1.5 Reciprocating Driven IC Engine #5 0.0035529 2.1 Turbine Driven IC Engines #5, Solar 05530 2.2 Turbine Driven IC Engines #7, Solar 05531 2.3 Turbine Driven IC Engines #1, refrig 05532 2.4 Turbine Driven IC Engines #2, refrig 05533 2.5 Turbine Driven IC Engines #1, gas set 05534 2.6 Turbine Driven IC Engines #2, gas set 05535 3.1 Furances cryo-reg gas heaters 0.0015536 3.2 Furances ht. Med. Htr 0.035537 3.3 Furances Frac. Reg Gas htr 0

170774 8 Waukesha 7042 GSI-E4A 0.026170775 9 Waukesha 7042 GSI-E4B 0.025

TOTAL 0.118

Year DAQ ID

Pt Source

ID SCC

Description of Process 

NSPS 

(Yes/No)

Associated 

Stack ID

Raw Material or Fuel 

used

Incinerator Natural Gas

Throughput Generating Emissions

Design Rate Un

Incinerator Natural Gas

Incinerator Natural Gas

4

2006 Calculations
ANNUAL SULFUR DIOXIDE EMISSION REPORT

Secondary Control

0 45 94 1 CEM tpy

0 45 94 0 1 CEM tpy

0 45 94 0 1 CEM tpy

COMPONENT CURRENT ADJUSTED

5538 15.605 15.6055539 102.07 102.07

Subtotal 117.675 117.675Other 0.118 0.118Total 117.793 117.793

How Sulfur Content is 

calculated

%

Ash

Emission 

Factor Units

Primary Control

Control 

Efficiency 

(%)

Emissions

(tons/yr)

Emissions 

from 

Breakdown 

(tons/yr)

Name of

Primary Control

Control 

Code (See 

List)

Name of

Secondary 

Control

Control 

Code 

(See List)

Sulfur recovery unit 1438.7

Estimate 

Code

Estimate 

Method

Throughput is a Fuel

Sulfur Enrichment & Injection 

(SEI) unit and the Sulfur 

Recovery Unit (SRU). The SRU 

was offline in 2006. 102.07

Sulfur recovery unit 102.07