CITY OF PHILADELPHIA Department of Public Health
Environmental Protection Division Air Management Services



### InterOffice Memo

To: File

From: Kassahun Sellassie

Date: January 9, 2015
Subject: 1997 8-Hour RACT Analysis for Veolia-Energy Efficiency (PA) LLC

Introduction:

The Clean Air Act (CAA) requires that moderate (or worse) ozone nonattainment areas implement reasonably available control technology (RACT) controls on all major sources of Volatile Organic Compounds (VOC) and Nitrogen Oxides (NOx). Philadelphia County is part of the Philadelphia-Wilmington-Atlantic City moderate ozone nonattainment area for the 1997 8-hour ozone NAAQS. This document presents the findings of the reevaluation of NOx RACT for the 1997 8-hour ozone standard for this facility

Company Description:

Veolia Energy Efficiency PA (LLC), which owns and oper ates a steam generating facility at 2600 Christian Street, Philadelphia, PA 19146. The facility has two (2) new 297 .91 MMBTU/hr boilers burning natural gas and No.2 fuel
oil that were installed in 2013.

Applicability for NOx and VOC RACT:

Veolia –Schuylkill Station, Energy Efficiency is a majo r source of NOx due to having potential NOx emissions greater than 100 tons per year, the ma jor source threshold in Philadelphia County that is applicable to NOx RACT for the 1997 8-hour ozone NAAQS. Veolia Energy Efficien cy is also part owner of the adjacent Grays Ferry Cogeneration Partnership (GFCP) which owns and operates an electric generating unit facility at 2600 Christian Street, Philadelphia, PA 19146. GFCP started operating on July 27, 2000. Equipment used at GFCP includes one (1) front wall fired boiler, and one (1) combined cycle combustion turbine (CT). The RACT for GFCP has been evaluated in separate memo. They are not a major source of VOC, due to having potential VOC emissions not greater than 50 tons per year, the major source threshold in Philadelphia County that is applicable to NOx RACT for the 1997 8-hour ozone. Veolia Energy Efficiency is been evaluated for RACT for the first time.

RACT Evaluation:

The two 297.91 MMBTU/hr boilers burn natural gas and #2 o il. Each boiler is currently equipped with ULNB. Each boiler has the following NOx emission limits, Plan Approval # 10277A, dated on Feb13, 2013, each on a rolling 30-day average: 0.01 lbs/MMBTU while burning gas and 0.08 lbs/MMBTU while burning oil. There is an additional NOx limit of 0.036 lbs/MMBTU while burning gas during startup, shutdown. The boilers have a combined NOx emission limit of 52.31 tons per rolling 12-month period.

The following were considered possible additional NOx controls as RACT for the boilers: (1) Selective CatalyticReduction (SCR), (2) Ultra Low-NOx Burners (ULNB) and Overfire Air (ULNB with OFA), (3) Selective NonCatalytic Reduction (SNCR), and (4) Low NOx Burners (LNB).

SCR injects ammonia upstream of a cat alyst. NOx, ammonia (NH3), and oxyg en (O2) react on the surface of the catalyst to form nitrogen (N2) and water (H20). NOx emissions are reduced by around 80% for Boilers #1 and #2.

ULNB with OFA reduce NOx emissions by around 70% for Boilers #1 and #2

SNCR reduce NOx emissions by around 55% for Boilers #1 and #2

LNB are burners designed to create a larger, lower temp erature flame. They woul d reduce NOx emissions by
around 50% for Boilers #1 and #2.

### 12/6/14 The NOx emissions for Boilers #1 and #2 were determined based on the rated capacity of 297.91 MMBTU/hr, 8,760 hours per year, and a 0.0.08 lbs/MMBTU NOx emission limit. The NOx emissions are 104.4 tons per year for
Boilers #1 and #2

The following NOx controls were determined t echnologically feasible for Boilers #1 and #2.

Source Control Tec Baseline NOx
Emissions (tpy) NOx
Reduction (%) NOx
Reduction (tpy) Total
Annualized Cost ($) Cost
Effectiveness ($/Ton)

Boiler # 1and #2 (each) SCR 104.4 80 83.52 710,448 8,506 OFA 104.4 45 46.98 196,775 4,188 SNCR 104.4 55 57.42 539,579 9,397 LNB 104.4 50 52.2 210,359 4,031

All of these control options have been determined economically unreasonable.

Because ULNB is currently installed on each boiler, it has b een determined to be both technically and economically feasible for controlling NOx emissions of Boilers #1 and #2.

ULNB has been determined RACT for each boiler. The plan approval NOx emission limits of 0.01 lbs/MMBTU on a rolling 30-day average while burning gas and 0.08 lbs/MMBTU on a rolling 30-day average while burning oil have been determined RACT. The separate startup and shutdown emission limits are not on a rolling 30-day average, do not affect the rolling 30-day emission limits, and are not being carried into RACT.

Conclusions and Recommendations:

- AMS has determined that the existing controls for Boilers #1 and #2 (ULNB) is NOx RACT for the 1997 8-hour ozone standard for Veolia Energy Efficiency LLC. The emission limitations for Boilers #1 and #2 is 0.08 lbs of NOx/MMBTU on a rolling 30-day average when firing oil and 0.01 lb of NOx/MMBTU on a rolling 30-day average when firing gas. The facility shall monitor and record compliance based on NOx
CEMs for Boilers #1 & #2.

1 / 9 / 1 5

Edward Wiener, Chief of Source Registration Date

### 12/6/14 

## RACT Calculations for Veolia-Energy Efficiency LLC- Boilers #1 and #2

Table 1- Detailed Calculations for SCR on Boilers #1 and #2

SCR, 297.91 MMBTU/hr Each Total capital Cost

Total Capital Investment Cost (TCI) $2,650,722 Based EPA Cost Control Manual of $6000/MMBTU/Hr. Escalate 1997 $ using the Marshall and swift Index (page 2-3)

Capital Recovery $423,585 0.1598 20 yrs @15% CRF=0.1598 1

Annual Operating Costs

Direct Annual Cost 1

Electricity Cost 2 $70,080 100kw @ $0.08/kwh, 8760 hrs/yr

Operator 1 $16,425 0.5hr/shift, 3 shift/day, $30/hr

Supervisor 1 $2,463.75 15% of Operator

Maintenance 1 $19,162.50 0.5hr/shift, 3 shift/day, $35/hr

Material 1 $19,162.50 100% of Maintenance

Ammonia $39,476 Ammonia Cost=(17/30)*2/2moles*1.05*104.4*410*1.
55

Annual Catalyst Replacement
Cost 1 $11,466 Catalyst Cost 1 = $70,000 Sinking Fund Factor = 0.1638 for 10% and 5 years Total Direct Annual Cost $169,337

Indirect Annual Cost
Overhead $11,498 60% of maintenance-OAQPS 1

Administrative Charge 3 $53,014 2% of TCI-OAQPS 1

Property Taxes 3 $26,507 1% of TCI-OAQPS 1

Insurance 3 $26,507 1% of TCI-OAQPS 1

Total Indirect Annual Cost $117,526

Total Annual Operating Costs $710,448

NOx Baseline Emissions (TPY) 104.4 Based on the rated capacity of 297.91MMBTU/hr, 8,760 hours per year,
and a 0.08 lbs/MMBTU NOx emission

### 12/6/14 limit.

NOx Emission Reduction (TPY) 83.52 Based on 80 % of NOx removed

Cost Effectiveness ($/ton NOx removed) $8,506



### Table 2- Detailed Calculations for OFA on Boilers #1 and #2

Total Capital Investment Cost (TCI) $290,108 TCI from original BART proposal from Veolia plus inflation adjustment .

Capital Recovery $46,359 0.1598 20 yrs @15% CRF=0.1598 1

Annual Operating Costs

Direct Annual Cost
Electricity Cost $70,080 100kw @ $0.08/kwh, 8760 hrs/yr (PA DEP RACT State Implemen tation Plan (SIP) revision, Sep, 2006, page 18)
Operator $16,425 0.5hr/shift, 3 shift/day, $30/hr

Supervisor $2,463.75 15% of Operator
Maintenance $19,162.50 0.5hr/shift, 3 shift/day, $35/hr

Material $19,162.50 100% of Maintenance

Total Direct Annual Cost $127,294

Indirect Annual Cost
Overhead $11,498 60% of maintenance-OAQPS 1

Administrative Charge $5,802 2% of TCI-OAQPS 1

Property Taxes $2,901 1% of TCI-OAQPS 1

Insurance $2,901 1% of TCI-OAQPS 1

Total Indirect Annual Cost $23,102

Total Annual Operating Costs $196,775

NOx Emission Reduction (TPY) 46.98

Cost Effectiveness ($/ton NOx removed) $4,188

### 12/6/14 

### Table 3 Detailed Calculations for SNCR on Boilers #1 and #2

SNCR 297.91 each MMBTU/hr each Total capital Cost

Direct Capital Cost $1,558,993 Based EPA Cost Control Manual (($950/mmmbtu/hr)*Qb(MMBTU/hr)*(2375 MMBTU/hr/Qb)^0.557*(0.66 + 0.85 uNOx). Qb= bolier size (mmbtu/hr); n = NOx removal efficiency (page 1-31)

Indirect Capital Cost 311,799 Based on EPA Cost Manual page 2-6

Total Capital Investment Cost (TCI) $1,870,792

Capital Recovery (annual cost) $298,953 0.1598 20 yrs @15% CRF=0.1598 1

Annual Operating Costs

Direct Annual Cost
Electricity Cost $70,080 100kw @ $0.08/kwh, 8760 hrs/yr (PA DEP RACT State Implemen tation Plan (SIP) revision, Sep, 2006, page 18) Operator $16,425 0.5hr/shift, 3 shift/day, $30/hr
Supervisor $2,463.75 15% of Operator
Maintenance $19,162.50 0.5hr/shift, 3 shift/day, $35/hr

Material $19,162.50 100% of Maintenance

Ammonia $39,476 Ammonia Cost=(17/30)*2/2moles*1.05*104.4*410*1.55
Total Direct Annual Cost $166,769

Indirect Annual Cost
Overhead $11,498 60% of maintenance-OAQPS 1

Administrative Charge $31,180 2% of TCI-OAQPS 1

Property Taxes $15,590 1% of TCI-OAQPS 1

Insurance $15,590 1% of TCI-OAQPS 1

Total Indirect Annual Cost $73,857

Total Annual Operating Costs $539,579

NOx Emission Reduction (TPY) 57.42
Cost Effectiveness ($/ton NOx removed) $9,397

### 12/6/14 

### Table 4 Detailed Calculations for LNB on Boilers #1 and #2

Total Capital Investment Cost (TCI) $358,370 TCI from original BART proposal from Veolia plus inflation adjustment. Capital Recovery $57,268 0.1598 20 yrs @15% CRF=0.1598 1

Annual Operating Costs

Direct Annual Cost
Electricity Cost $70,080 100kw @ $0.08/kwh, 8760 hrs/yr (PA DEP RACT State Implemen tation Plan (SIP) revision, Sep, 2006, page 18)
Operator $16,425 0.5hr/shift, 3 shift/day, $30/hr
Supervisor $2,463.75 15% of Operator
Maintenance $19,162.50 0.5hr/shift, 3 shift/day, $35/hr

Material $19,162.50 100% of Maintenance

Total Direct Annual Cost $127,294

Indirect Annual Cost
Overhead $11,498 60% of maintenance-OAQPS 1

Administrative Charge $7,167 2% of TCI-OAQPS 1

Property Taxes $3,584 1% of TCI-OAQPS 1

Insurance $3,584 1% of TCI-OAQPS 1

Total Indirect Annual Cost $25,832

Total Annual Operating Costs $210,359

NOx Emission Reduction (TPY) 52.2

Cost Effectiveness ($/ton NOx removed) $4,031

### 12/6/14 

## References

1. Office of Air Quality Planning and sta ndards (OAQPS), Environmental Protection Agency (EPA) Air Pollution Control Manual, Sixth Edit ion, EPA/452/B-02-001, January
2002.
2. Electricity cost: EPA cost manual, Appendix A-NOx Control Analysis
3. Capital Recovery = Convert from P (present ) to A(Annual amount), A=P(A/P,i%,n),

1 ) 1 ( ) 1 (

  



n n



### i i i CR 

### 15% interest and 20 yrs = A/P= 0.1598; Annual Cost =TCI * CFR

4. Catalyst Cost of SCR: The catalyst life is 5 year s. The annual cost is given by the sinking fund factor (SFF). The SFF is the amount of mone y the facility will need to set aside each year to be able to replace the catalyst at th e end of its life, based on the lifespan of the catalyst and the interest rate.

5. SFF = Convert from F (Future) to A( Annual amount), A=F(A/F,i%,n),



### 1 ) 1 (



 

n 

### i i SFF 10% interest and 5 yrs = A/F=0.1638

Where i= Annual interest Rate (10%); n= catalyst system life (5 years);

Catalyst Annual Cost = SFF x Catalyst Cost

6. Ammonia Cost:
2NH 3 

### + 2NO + 1/2O 2 

### 2N 2 

### + 3H 2 

### O

Annual Ammonia Cost = (17/30 * 2moles of NH 3 /2 moles of NO *1.05 * NOx emission (tpy) *$410/ton yrs x 1.55)

NH 3 = Ammonia, NO = Nitric Oxide; O 2 = Oxygen; H 2 O = Water; 1.05= Ammonia slip and excess ammonia, 55% cost increament)