# ;c AttachmentA ReasonablyAchievable Control Technology (RACT) analysis

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# c REASONABLY ACHIEVABLE CONTROL TECHNOLOGY ANALYSIS 

# PHILAD .LPHI E ERGY S LUTI Philadelphia Energy Solutions Refining and Marketing, LLC. (PES). 

# ReasonablyAchievable Control TechnologyAnalysis for the HeaterFiring RateIncrease

August31, 2012 (Submittal) September 6, 2012 (Completeness Determination) September 2013 (Supplement)

Environmental Resources Management 

# 75 Valley StreamParkway Suite 200 Malvern, Pennsylvania 19355

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# ~**~** REASONABLYACHIEVABLE CONTROL TECHNOLOGYANALYSIS 1 

## 1.0 REASONABLYACHIEVABLE CONTROL TECHNOLOGYANALYSIS 1 

# 1.1 RACTANALYSISREQUIREMENTS 1 

# 1.2 RACTPLANAPPROVAL CHANGES 

## 3 

## 1.2.1 

# Presumptive RACTRevisions 3 1.2.2 

# Modifications to 

# Unit 231-B101 and Unit 865-11H1 3 1.2.3 

# Cessation of Refinery Fuel Oil Firing 4 

# 1.3 RACTCOSTEFFECTIVENESS CALCULATIONS 

## 6 

# 1.4 RAeT ANALYSIS RESULTS 

# 7 2.0 RACTPLANAPPROVALPROPOSED CONDITIONS 

# 8 

# 2.1 RACT CONTROL EQUIPMENTREQUIREMENTS 

# 8 

# 2.2 RACTIMPLEMENTATION SCHEDULE 

# 8 

# 2.3 RACTTESTING REQUIREMENTSAND STACKEMISSION LIMITATIONS 

# 8 

# 2.4 RACTRECORDKEEPINGANDREPORTINGREQUIREMENTS 

## 9 

# List

# ofTables Table 1-1 25 Pa Code §129.92 (b) 

# RACTRequirements Table 1-2 Proposed RACTPlan Approval Conditionsfor Unit 231-BI01 and Unit 865-11H1 Table 1-3 Table 1-4 Table 2-1 Listof Appendix 

# AppendixA

ERM 

# NOx 

# Emissions Reductionsfrom Cessation of Refinery Fuel Oil Firing Summary of RA

# CTPlan Approval Revisions RACTPlan Approval Existing and Proposed Limits RACTCost Effectiveness Analysis i PES RAer ANALYSJS/SEPTEMBER 2013

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# 1.0



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1.1 REASONABLY ACHIEVABLE CONTROL TECHNOLOGYANALYSIS The Sunoco, Inc. (R&M)l Girard PointProcessing Area and PointBreeze Processing Area RACT Plan Approval amended on October 7, 2002 was established for nitrogen oxides (NOx) 

# and volatile organic compounds (VOCs) and limits the firing rate on the heaters to comply with the RACT regulatory requirements codified in 25 Pa Code §129.91 through §129.95. This applicationaddresses changes to certain NOx 

# RACT conditions2• 

# No changes to VOC RACT conditions are requested. With this application, the Refinery proposes to remove the firing rate limits inthe RACT Plan Approvalfor seven targetheaters: 

# • Unit231-BIOI Heater; 

# • Unit 865-11H1 Heater; 

# • Unit 865-11H2 Heater; 

# • Unit21O-H101 Heater; 

# • Unit210-H2OI Heater; 

# • Unit 866-12H1 Heater; and 

# • Unit 868-8HIOI Heater. RACTANALYSffiREQUIREMENTS As described in25 Pa Code §129.92(b), each RACT Analysis mustinclude the requirements listed in Table 1-1 below.

1 

### The Sunoco Philadelphia Refinery is now owned and operated by Philadelphia Energy Solutions

Refining and Marketing, LLC (PES). 2 

### The RACT Plan Approval revisions to the target heater firing rate or emission limits are not

being requested by PES to comply with any requirements ofConsent Decree No. 05-02866 (Fourth Amendment, dated August 17, 2012). ERM 

## 1 PES RAG ANALYSIS/SEPTEMBER 2013

# Table 1-1 25 Pa Code §129.92(b) RAeT

# Requirements 25 Pa Code 

### §129.92(b) Requirement A ranking ofthe available control options for the affected source in descending order ofcontrol effectiveness. 1



### An 

### evaluationofthe technical feasibility ofthe available control options identified based on physical, chemical and engineering principles. A determination oftechnical infeasibility should identify technical difficulties restricting the successful use ofthe control optionon the affected source.

A ranking ofthe technically feasible control options in order ofoverall control effectiveness for NO, emissions. The baseline emissions ofNO, before implementation ofeach control option ("pre-control emissions"). Theestimated emission reduction potential orthe estimated control efficiency ofeach control option. The estimated emissionsafter the application ofeach control option ("post-control emissions"). An 

### evaluationofcost effectiveness of each control option consistent with EPA's cost guidance manuals. The costeffectiveness shall be evaluated in terms ofdollars per ton ofNO, emissions reduction. Discussion • Ultra-low NO,burners (ULNB) and Selective Catalytic

Reduction (SCR)-96% • Selective Catalytic Reduction - 85% • Ultra-low-NO, burners - 66 to 76% • Low-NO, burners and Selective Non-Catalytic Reduction

(SNCR) -70% • Low-NO, burners (LNB) and FIue Gas Recirculation (FGR)

- 55% • Selective Non-Catalytic Reduction - 40% • Unit 865-11HI - The installation ofSCR is notpossible as

there is not adequate plot space available; further, there is not adequate pressure to overcome the SCR pressure drop; therefore, SCR is infeasible. FGR installation would require the installation ofmechanical draftburners, which is a major re-design ofthe unit; therefore FGR is infeasible. • Unit 21O-HI01 - FGR would not physically fit the plot

space; therefore, it

### is infeasible. • Unit 210-H20I - The installation ofSCR is not possible as

there is not adequate plot space available; further, there is not adequate pressure to overcome theSCR pressure drop; therefore, SCR is infeasible. FGR installation would require the installation ofmechanical draft burners, which is a maj()T re-design_ofthe unit; therefore FGR is infeasible. The RACT summary in Appendix A for each target heater ranks the technically feasible controls options by listing them from highest to lowestcontrol effectiveness. The "pre-control emissions" are listed in the "Potential Emissions (fPY)" column for each targetheater in the RACT summary for each heater in Appendix A. 

### The estimated emission reduction potential for each control option for each target heater is listed in the "Potential NO, : Reduced (fPY)" column in the RACT summary for each

heater in Appendix A. 

### These values based on design firing for each heater. The "post-control emissions" are listed in the "Maximum PostControl Emissions @ 

### Design Firing (fPY)" column for each target heater in the RACT summary for each heater in Appendix A. 

### See 

### Appendix A for the RACT Cost Effectiveness Analysis.

1 

### NO,control effectiveness derived from Alternative ControlTechniques Document NO, Emissions

from Process Heaters (Revised) - EPA Emissions Standards Division - EPA-453JR-93-034 

### and Refinery process knowledge.

ERM 

## 2 PES RACT ANALYSlS/SEPTEMBER 2013

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# 1.2

1.2.1

1.2.2 

# RACTPLANAPPROVAL CHANGES PES is requesting changes to the RACT Plan Approval including updates to presumptive RACT sources and updates to previous RACT determinations on selectheaters. For this RACT analysis and future RACT analyses, PES is requesting that the RACT determinations focus on identifying specific NOx 

# control technology requirements and pollutant emission rates (lb/MMBtu) as RACT. Previously the RACT determinations were identified ashourly firing rate limits (MMBtu/hr) and pollutantemission rates. The basis for the RACT analysis, provided here, now relies on design firing for all heaters. A summary ofrequested RACT Plan Approval revisions arefound in Table 1-4 atthe end ofthis section. 

# PresumptiveRACTRevisions Three of the targetheaters, Unit865-11H2, Unit866-12H1, and Unit 868-8H101, previously had firing rate limits less than 50 million British thermal units per hour (MMBtu/hr) and were therefore subject to presumptiveRACT NOx 

# controls established under 25 Pa Code §129.93. Presumptive RACT required the use ofcombustiontuning rather than physical controls. Because these three heaters are seeking annual equivalentfiring rate limits over 50 MMBtu/hr, PES has provided a Case-by-Case RACT analysis inAppendix A for these heaters as a partof this plan approval application along with the other targetheaters. 

# Modifications 

# to Unit231-B101 and Unit 865-11Hl Ultra-low NOx 

# burners (ULNBs) are planned to be installed onUnit 231-B101 and Unit865-11HF PES proposes thatthe RACT Plan Approval be revised to keep the current RACT limits for hourly firing limit (MMBtu/hr) and NOx 

# emission rate (lb/MMBtu) inplace until the installationofthe ULNBs are complete. A new permitcondition should be included inSection 2 of the RACT PlanApproval to only allow the removal ofthehourly firing limits for the Unit 231-B101 and Unit 865-11H1 heaters after the ULNBs have been successfully installed and stack test results show that theheaters meet the specified NOx 

# emission rate (0.03Ib/MMBtu). See the proposed RACT limits inTable 1-2 below.

3 

### As part ofa settlement agreement with the Clean Air Council, PES agreed voluntarily to install

ultra-low NO, burners on Unit 231-8101 Heater and Unit 865-11H1 Heater at the Refinery to further reduce emissions beyond the cuts achieved by the shut-down ofthe Marcus Hook Refinery. ERM 

## 3 PES RAG ANALYSIS/SEPTEMBER 2OJ3

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# Table 1-2



# 1.2.3 Proposed RACTPlanApproval Conditions for Unit 231-B101 and Unit 865-11H1 Heater : Hourly Firing Limit (MMBtujhr) NO. Emission Rate (lb/MMBtu) RACTNOx 

## Control RACT Plan Approval Conditions Pending ULNB Installation

...... _ ...............

# _ .....................•..... 

### Unit 23l-BIOI 91 0.122 (refinery fuel gas) Combustion Tuning

--- ....**~.---.---- .-~** ............... -.. . .....**~-** ............

### -..•........- ..

# -- .. 

### --- ..... 

### ---

Unit 865-l1Hl Unit 23l-BIOI Unit 865-UHl 0.113 (refinerv fuel ..

## 72.2_~__

## gaWO.~ (refinery fuel

## ~_..

## COrnb~s~on**_Tu~g**.. Proposed Conditions after ULNB Installation and Testing 0.03 (refinery fuel gas) 0.03 (refinery fuel gas) Combustion Tuning Combustion Tuning 

# Cessation of RefineryFuel OilFiring As discussed under Section 110(1) of the Clean Air 

# Act, while the changes to the RACT PlanApproval include removal offiring rates of seven heaters, the RACT PlanApproval will still provide reasonable further progress toward ozone attainmentbecause PES is also requestingremoval of the ability for fuel oil firing for five of the sevenheaters. Typically refinery fuel oil firing NO. emission rates arehigher than gaseous fuel-firing NO. emissionrates. Table 1-3 below shows the change in NO. maximum emissions, based on the RACT limits for the targetheaters based on the removal of the ability for fuel oil firing. The currentoil firing NO. emissions rate limits and hourly firing limits (MMBtu/hr) as well as the proposed gaseous fuel-firing NO. emissionrate limits and designfiring (MMBtu/hr) for five of the targetheaters were used to determine the total reductionin maximum NO. emissions associated with the proposed RACT limit changes. This reduction in emissions providesreasonable further progress toward ozone attainment.

ERM 

## 4 PES RACT ANALYSIS/SEPTEMBER 2013

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# C Table 1·3 NOx 

# Emissions Reductions from Cessation of Refinery Fuel OilFiring Existing Oil Firing Gas Firing Hourly Emission Current Design Proposed : Proposed: Change Firing RACf Firing Emission RACf TargetHeater Limit Limit NOx 

## (MMBtuj Limit NOx 

## inNOx 

## (MMBtuj (lbNOJ (TPY) hr) 

## (lbNOJ (TPY) (TPY)**hr~** 

## MMBtu) MMBtul Unit 865-11Hl 72.2 0.400 126.5 87.3 0.030 11.5 -115.0 Unit 865-11H21 49.9 0.113 24.7 64.2 0.113 31.8 7.1 Unit 210-HI0l 183.0 0.400 320.6 192.0 0.089 74.8 -245.8 Unit 21()"H201 242.0 0.400 254.0 0.030 33.4 -390.6**-""~,,---.,--** ..- ..**-.~.-""**......-.-...-**~**__**~ _'~"**  __"'''M'_'_'_'' __''''''''''___ 

### Unit 866-12Hl 1 

### 43.0 0.113 21.3 61.2 0.113 30.3 9.0 

### Total Target Heater NOx

### RACf 

### Reduction (fFY) 

# I -735.3
1 

### Note thatUnit865-11H2 

### and Unit 866-12Hl 

### are currently complying with the presumptive RACf

### limits and do not

have oil firing NO.emission limits. Conservatively, the proposed gas firing NO, emission limitof0.113 

### Ib/MMBtu was assumed asthe oil firing emission limitfor this analysis.

ERM 

## 5 PES RACT ANALYSIS/SEPTEMBER2J)13

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# Table 1-4



# 1.3 

# Summary of RACTPlanApprovalRevisions Section Section 1.A(2) Section 1.A(l1) Section 1.A(15) 

## Revisions Requested 

# I Revise firing duty ofUnit 231-B101 to 104.5 MMBtu/hr. I .. . .. 

### Revise firing duty ofUnit 210-HIOI to 192 MMBtu/hr. Revise firing duty of Unit 210-H201 to 254 MMBtu/hr. Revise the section to remove the firing of refinery fuel oil. Revise firing duty ofUnit 865-11Hl to 87.3 MMBtu/hr. Revise firing duty ofUnit 865-11H2 to 64.2 MMBtu/hr. Revise the section to remove the firing ofrefinery fuel oil.

----.··-·········· .• ··.-t·····························...... -............................. .. ........................................................- ....... - .•••••........... - ........... 

### Section 1.A(16) Revise firing duty of Unit 866-12H1 to 61.2 MMBtu/hr. Revise the section I 

### to remove the firing ofrefinery fuel oil. Section 1.A(19) I 

### Revise firing duty ofUnit 868-8HI01 to 60.0 MMBtu/hr. • ____""""_"_ ••**_~""'**___O>_ 

### Section 1.B(l) Add control technology for Unit 21O-H201 (ultra-low NO, burners).

Section2.A Section 2.B Section 2.C New paragraph

in Section 2 Add description that ultra-low NO, burners are planned to be installed on Unit 231-BI01 and Unit 865-11H1. Installation will be completed after issuance ofplan approval.

. Include combustion tuning as RAG for Unit 865-11H2 and Unit 868-8HIOI. I 

### Removal ofthe heat input caps (MMBtu/hr) for Unit 231-BI01 and Unit I 

### 21O-H201.

Add control technologies for Unit 21O-H101 (low NO, burners) and Unit I 

### 210-H201 (ultra-low NO, burners). New paragraph . Add description that originalRAGlimits apply until the installation of

in Section 3 ultra-low NO, burnerson Unit 231-BI01 and Unit 865-11Hl. Section 4.B Section4.C Add description that NO, RACT emissions limitfor Unit 21O-H201 has been established using CEMS. Removal ofUnit 231-B101 and Unit 865-11Hl Heaters from the table as compliance will be demonstrated through performance testing.

_____..**~"_"~~.mm_··**___ .............,,,"'.._ ....,,__ 

### Section4.C Section4.C Updates to add NO, emission rate for Unit 865-11H2, Unit 866-12Hl, and Unit 868-8H101. Updates to NO,emission rate for Unit 21O-H201 Heater and removing refinery fuel oil firing NO, emission limitations for Unit 210-H101 and Unit 210-H201. 

# RACTCOSTEFFECTIVENESS CALCULATIONS In 

# this application, the costeffectiveness calculations for the RACT analyses were based on the EPA guidance documententitled

# AlternatilJe Control Techniques Document· NOx 

# Emissionsfrom Process Heaters (Revised) - EPA-453/R-93-034. PES also used costinformation from past Refinery ULNB installations on two heaters (Unit 1332 H-400/H-401 Heater and Unit 137 F-3 Heater). These costs - capital and operation and maintenance (O&M) - were scaled up to 2012 dollar amounts using 

# Chemical
ERM 

# 6 PES RACf ANALYSIS/SEPTEMBER 2013

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# c

1.4 

# Engineering costindices. PES has also conducted the analysis atthe currentcostofborrowing capital. As PES is a recently established company under new ownership in a private equity structure, the cost ofborrowingcapital (the minimum return thatinvestors expectfor providing capital to the company) is considered ata higher risk than many established companies. The cost effectiveness analysis reflects the currentcostofcapital for PES, which is 21.83%. 

# RAeT ANALYSISRESULTS The RACT costeffectiveness for the subjectheaters are calculated at approximately $6,700 to $163,000 per ton ofNOx 

# emissions reductions for additionalcontrolsbeyond those considered partofcurrentheater design and operation. The RACT analysis leads to the following conclusions: • The Unit 210-H101 Heater already has LNB installed4; 

# however, the installation ofcurrentgeneration UNLB is notcosteffective. • Unit 210-H201 has NOx 

# control today at a permitlimit of0.03 lb / MMBtu, and nofurther control is deemed to be costeffective as indicated by the RACT analysis. • With the planned installations of ULNBs on Unit231-B101 and Unit 865-11H1, as indicatedby the RACT analysis, no other control technologies are found to be costeffective. • As illustrated in Appendix A, for the remainingheaters, additional retrofit NOx 

# control optionsbeyond combustion tuning arenotcost effective. Therefore, combustion tuningis RACT for these heaters.

4 

### Burners were considered UNLB when installed, butreferred to here as LNB to avoid confusion. ERM 

## 7 PES RACl ANALYSIS/SEPTEMBER 2013

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# ~ 2.0 RACTPLANAPPROVAL PROPOSED CONDITIONS Based on this RACT analysis, including the RACT costeffectiveness analysis completed in Appendix A, PES is proposing RACT for the seven targetheaters as described below. Table 2-1 atthe end of this section shows the existing and proposed RACT PlanApproval limits. 2.1 RACTCONTROL EQUIPMENTREQUIREMENTS Combustion tuning will be RACT for the following heaters: Unit231-BI01 Heater, Unit 865-11Hl Heater, Unit 865-11H2 Heater; Unit210-HI0l Heater; Unit210 H-201 Heater; Unit 866-12Hl Heater; and Unit 868-8HI0l Heater as well as compliance with the RACT NOx 

# emissionrate limitfor eachheater listed inTable 2-1. 2.2 RACTIMPLEMENTATIONSCHEDULE Sources inTable 2-1 below proposingcombustion tuning to comply with RACT requirements of25 PA Code 129.91(f) shall perform quarterly combustion tuning. 2.3 RACTTESTING REQUIREMENTSANDSTACKEMISSION LIMITATIONS After installation of the ULNB on the Unit231-B101 and Unit865-11Hl Heaters, PES shallconducta one-time performance tests for NOx• 

# The results ofthese tests will be submitted to AMS. The final NOx 

# RACT emission limits for the Unit 210-H201 Heater shall be established through the use of the Department-approved Continuous Emission Monitoring System (CEMS) currently installed. Compliance with the limitation listed in Table 2-1 below for Unit210-H201 will be ona 365-day rolling averagebased onhourly averages ofCEM data. Compliance with emission limits for the Unit 210-H101, Unit 865-11H2, Unit 866-12H1, and Unit868-8HI01 Heaters shallbe determined by quarterly stack sampling with a portable NOx 

# analyzer. After one year sampling, PES may petitionAMS for semi-annual monitoring.

ERM 

## 8 PES RACT ANALYSIS/SEPTEMBER 2013

# ~ ..

## 2.4



# c All annualcombustion tuning shall ata minimum meetthe requirements setforth in 25 PA Code 129.93 (b)(2) through (5). Atleast thirty (30) days prior to a performance NOx 

# test, PES shall inform AMS ofthe date and time of the scheduled test. 

# RACTRECORDKEEPINGANDREPORTINGREQUIREMENTS PES shall maintain a file containing all the records and other data that are required to be collected to demonstrate compliance with NOx 

# RACT requirements of 25 PA Code 129.91-129.94. The records shall provide sufficient data and calculations to clearly demonstrate that the requirements of §129.91-129.94 are met. Data orinformationrequired to determine compliance shall be recorded and maintained in a time frame consistentwith the averagingperiod of the requirement. Records shallberetained for a t leasttwo years and shall be made available to the Departmentonrequest.

ERM 

## 9 PES RAcr ANALYSIS/SEPTEMBER 2013

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# (' Table 2-1

ERM 

# (' RACTPlanApprovalExistingandProposedLimits Existing Emission Rate Limit (lb NOJMMBtu) RACT Control Unit Hourly Firing Design Firing Exist!!,g3_ . P!()posed 4 

## Limit (MMBtu/hr) Existing' Proposed (MMBtu/hr) 2 

## Gas Oil Gas Oil Unit 231-B101 91 104.5 0.122 

### ! 0.03 1 

### Tuning j 

### Tuning 5 ) 

### runing Tuning 183 192.0 0.089 0.400 0.089 Tuning Tuning 6 

### Unit 210-H201 242 254.0 0.173 OAOO 

### 0.03 Tuning Tuning 6 

### Unit 866-12Hll 43 61.2 0.113 Tuning Unit 868-8HI01 1 

# I 49.5 60.0 0.113 Tuning ! 1 

### Units are currently subject to PADEP's presumptive RACT and not subject to specific requirements in the RACT Plan Approval. 2 

### Compliance with limitation is 

### based on the daily average heat input. 3 

### Compliance with limitation is 

### based on quarterly stack sampling using a portable NO, analyzer. 4 

### The Refinery is 

### only proposing limits for firing natural gas at the target heaters. The Refinery no longer uses refinery fuel oil as a fuel

for the Unit 865-11 HI, Unit 21O-H101, and Unit 210-H201 heaters and proposes to remove the capability to use refinery fuel oil as a fuel from the RACT Plan Approval. For Unit 210-H201, compliance with the emission rate limit will be through the use of Department-approved CEMS currently installed. For heaters other than Unit 210-H201, compliance with limitation is based on quarterly stack sampling using a portable NO, analyzer. 5 

### PES is proposing that the current RACT Plan Approval conditions remain in place and the hourly firing rate limits can only be

removed after the installation and testing of the ULNBs at Unit 231-BIOI and Unit 865-11H1. 6 

### Control equipment is 

### currently installed; however only combustion tuning is 

### currently required as RACT control for these unitsin

the RACT Plan Approval. The proposed emission rate limits also reflect the presence ofcontrol equipment. 

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# c CITY OF PHILADELPHIA DEPARTMENT OF PUBLIC HEALTH AIR MANAGEMENT SERVICES RACT PLAN APPROVAL Effective Date: August 1, 2000 Amended Date: October 7, 2002 Expiration Date: None 

# r These amendments will update RACT requirements for 

# J£ sources affected in the Heater Firing Rate Increase Plan Approval. Replaces Permit No. None In accordance with provisions ofthe Air Pollution Control Act, the Act ofJanuary 8, 1960, P.L. 2119, as amended, and after due consideration of a Reasonably Available Control Technology (RACT) proposal received under the Pennsylvania Code, Title 25, Chapter 129.91 thru 129.95, ofthe rules and regulations ofthe Pennsylvania Department of Environmental Protection (PADEP), Air Management Services (AMS) amended the RACT Plan Approval ofthe Facility below for the source(s) listed in section 

## 1.A. Emission Sources ofthe attached RACT Plan Approval. Facility: Owner: Location: Mailing Address: SIC Code(s): Plant 

## 10: Facility Contact: Phone: Permit Contact: Phone: Responsible Official: Title: Sunece, InG. (R 

## & 

# fiAl. Sunece, Incl.. 

## Girard Point Processing Area located at 3001 Penrose Ave Point Breeze Processing Area located at 3144 Passyunk Ave 3144 Passyunk Ave., Philadelphia, PA 19145 2911 1501 and 1517

Vincent 

# J. Kelley..4- Refinery ManageFi. Edward Braun, c'hief of Sou-;:ce Registration

# /tblc~**Dat~**

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### RACT PLAN APPROVAL Stlftoee, lae. (R&M1. Page 2 

# C The RACT plan approval is subject to the following conditions: I. The purpose ofthis Plan Approval is to establish Nitrogen Oxides (NOx)Nolatile Organic Compound (YOC) Reasonably Available Control Technology (RACT) for StiReea, IRe. (R&M) ...

### Girard Point Processing Area and Point Breeze Processing Area. This includes the following emission sources and control equipment: A. Emission Sources (I) 

### Process Heaters: Unit 137: FI heater (415 MMBTUlhr) F2 heater (155 MMBTUlhr) F3 heater (60 MMBTUlhr) Process heaters FI and F2 bum refinery fuel gas or refinery fuel oiL Heater F3 bums refinery fuel oil. (2) Process Heater: Unit 231: B-1 0I heater 

## (%.MMBTUlhr) Heater fires refinery fuel gas. (3) Process Heater: Unit 433: H-l heater (243 MMBTUlhr) Heater fires refinery fuel gas. (4) Process Heaters: Unit 1332: H-400 heater (186 MMBTUlhr) H-401 heater (233 MMBTUlhr) H-600 heater (21.3 MMBTUlhr) H-60 I heater (48 MMBTu/hr) H-602 heater (49 MMBTUlhr) H-I heater (45 MMBTUlhr) H-2 heater (60 MMBTUlhr) H-3 heater (43 MMBTUlhr) These heaters bum refmery fuel gas. 

# C (5) Process Heater: Unit 1232: B- I04 heater (70 MMBTUlhr) Heater fires refinery fuel gas.



# c (6) Boiler House #3: Boiler #37 (495 MMBTUlhr) Boiler #38 (495 MMBTUlhr) Boiler #39 (495 MMBTUlhr) Boiler #40 (660 MMBTUlhr) These boilers fire refinery fuel gas or refinery fuel oiL (7) 

### Sludge Incinerator 8832: Unit was 44 MMBTUlhr and burned refinery fuel gas or refinery fuel oiL (8) Sulfur Recovery Unit 532: S02 incinerator was 16 MMBTUlhr. Unit burned refinery fuel gas. (9) 1232 FCCU CO Boiler: CO waste gas combustion unit (580 MMBTUIhr) bums process waste gas, refinery fuel gas and refinery fuel oil. (10) Asphalt Heater: HI (12.8 MMBTUlhr) H2 (12.8 MMBTUlhr) H3 (12.8 MMBTUlhr) H5 (12.8 MMBTUlhr) These heaters burned fire refinery fuel gas. (I I) Crude Unit 210: Section A HTR HIOI (+8iMMBTU/hr) Section B HTR H201**(~MMBTu/hr)** 

### Section C HTR 13H I (135.4 MMBTUihr) These heaters above fire refinery fuel gas aHa 

### refiRe!,), fuel oil.

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### RACT PLAN APPROVAL Stlft6e6, 

## hie. (R&Ml. (12) Hydrocracker Unit 859: HTR I HI (76 MMBTUlhr) Unit fires refinery fuel gas and refinery fuel oil.
(13) Reformer Unit 864: HTR IH2 (70 MMBTUlhr) Unit fires refinery fuel gas and refinery fuel oil. HTR IH3 (21 I MMBTUlhr) Unit fires refinery fuel gas and refinery fuel oiL HTR IH4 (19 MMBTUlhr) Unit fires refinery fuel gas. HTR PH3 (80 MMBTUlhr) HTR PH5 (90 MMBTUlhr) HTR PH I (80 MMBTUlhr) HTR PH2 (45 MMBTUlhr) HTR PH4 (57 MMBTUlhr) HTR PH7 (45.5 MMBTUlhr) HTR PH 11 (74 MMBTUlhr) HTR PHI2 (85.1 MMBTUihr) These heaters fire refrnery fuel gas and refinery fuel oil. (14) Hydrogen Plant 861: HTR 3HIS (123 MMBTWhr) HTR 3HIN (125 MMBTUlhr) These heaters burned refinery fuel gas. (I

### 5) Distillate HDS Unit 865: HTR IIHI (72.2,..MMBTUlhr) HTR IIH2**(~MMBTUlhr)** 

### These heaters fire refinery fuel gas !tAd 

### refinery fuel oil. (16) Gas Oil HDS Unit 866: HTR 12H I(4lMMBTUlhr) Heater fires refinery fuel gas 

### aAa refiAery fuel oil. (17) 22 Boiler House: Boiler 

### #I (169 MMBTUlhr) Boiler #2 ( 169 MMBTUlhr) Boiler #3 (203 MMBTUlhr) Page 3

These three boilers bum only refrnery fuel gas or natural gas and are equipped with Ultra Low NOx Burners. (18) Reformer Unit 860: HTR 2H3 (174.67 MMBTUlhr) Unit fires refinery fuel gas and refinery fuel oil. HTR 2H5 (155 MMBTWhr) Unit fires refinery fuel gas and refinery fuel oil. HTR 2H I (49 MMBTUlhr) Unit fires refinery fuel gas and refinery fuel oil. HTR 2H2 (69.78 MMBTUlhr) Unit fires refinery fuel gas and refrnery fuel oil. HTR 2H4 (99.44 MMBTUlhr) Unit fires refinery fuel gas and refinery fuel oil. HTR 2H6 (36.7 MMBTUlhr) Unit fires refinery fuel gas and refrnery fuel oil. HTR 2H7 (59 MMBTUlhr) Unit fires refinery fuel gas and refinery fuel oiL HTR 2H8 (49.6 MMBTUlhr) Unit fires refinery fuel gas and refinery fuel oiL Boiler 2H9 (165 MMBTUlhr) Unit fires refinery fuel gas or natural gas. (19) 868 FCCU HTR SHIOI**(~MMBTUlhr)** 

### Unit fires refinery fuel gas. (20) 868 FCCU Catalyst Regenerator (21) 867 Sulfur Recovery Unit Incinerator (22) Emergency Flares (23) Cooling towers (24) Fugitive leaks: valves. flanges. compressors. pumps, pipes. 

### B. Control Equipment

# J

### MCT PLAN APPROVAL 

## Sl:IB6ee. lac. (R&Mi Page 4 (I) Ultra-low NOx burner (ULNB) systems are installed on the following sources to control NOx emissions: Unit 433 H-I heater Unit 1::!32 B- 104 heater #3 Boiler House boilers #37. #38. #39. and #40. 

# -E: IUnit 21 0-H201 2. This approval requires and authorizes: A. The installation of the Ultra Low NOx Burners on 433 H-I heater. l::!32 B-104 heater. and #3 Boiler House boilers #37, #38. #39, and #40 to comply with RACT requirements. The installation ofthe burners has been completed. 

# B.**1rtr.~l.l!ml!.lIbustion** 

### tuning to comply with RACT requirements for the following heaters: Unit 137: FI heater, F2 heater, F3 nea-I:'ef--_ Unit 231: B-1 0I heater Unit 1332: H-400 heater, H-40 I heater, H·2 heater**r.-~~--~~~~~--~~~~----~** 

## Add description that ultra-low NOx burners are planned to be installed on Unit 231-

-- '8101 and Unit 865-11H1. Installation will Crude Unit: 2 lOA HTR HlOI, 210B HTR H201, 210C HTR 13HI 

## be completed after issuance of plan Hydrocracker Unit 859: HTR IHI, HTR IH2, HTR IH3 

## approval. Reformer Unit 864: HTR PH3, HTR PH5, HTR PH I, HTR PH2, H"".:.m:l'lI""""t:l'T1T""I:rc:n.,..-;t:rr1T"C0l'fT..,------------I Hydrogen Plant 861: HTR 3HI S, HTR 3HIN Distillate HDS Unit 865: HTR IIH I Reformer Unit 860: HTR 2H3, HTR 2H5, HTR 2H4, HTR 2H2, HTR 2H7 Gas Oil HDS Unit 866:**H~~:,-P** 

### ...**H~J(.::t4**

### ... 3**~M~M~Bu.T:'-I!~Ih'_':'r..L) =-=--:-:-:=--:--:-:--:-=-_...,....,-:-=--:::--:-:-~_:___=_:::___:_:_:=__:_,....,...,_:::_~**  

# < {DIstillate HDS Unit 865: HTR 11 H2 and HDS Unit 868: HTR 8H101 

# c. All fuel burning sources will be capped at the heat input specified in the table below. If**~**

### desires to raise the cap, a RACT evaluation will have to .be performed at that new heat input. The economic evaluation will be 

### made using cost ofliving increases. Changes will require a resubmission as revision to the PA State Implementation Plan. The applicant shari bear the cost ofpublic hearing and notification required for EPA approval as stipulated in 25 PA Code §129.9(h). Modifications or changes may require additional controls or more strict emission limits depending on the applicable regulation triggered as a result ofthe modification or change.
I 

### Heat Input Cap Process Unit Source (MMBTUlhr) Unit 137: FI heater 415 F2 heater 155 

## Yflit i!31: B IQI 

## J:te,*ef 9-l 

### Unit 433: H-I heater 243 Unit 1332: H-400 heater 186 I 

### Unit 1232: B-\04 heater 70 Boiler House #3: Boilers #37, #38. #39 495 Boiler #40 660 bfl:lae Idflit 

### i! IQB: 

### H:t=R: Hi!Q I**~** 

# I Hydrocracker Unit 859: HTR IHI 76 HTR IH2 70 I 

### Reformer Unit 864: HTR PH3 80 I 

### HTR PHS 90

. HTR PH2 45 I 

### HTR PH4 57 ! 

### Hydrogen Plant 861 : HTR 3HlS p" _:> 

### HTR 3HIN 125 D.**~shall** 

### monitor all fuel input to all heaters and boilers with BTU limitations on a daily basis to insure capacity limits are not exceeded or Stlftshall install fuel limiting devices on the heaters or boilers to keep capacities below allowable. The compliance method must be in place by June 30'h 2000.

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### RACT PLAN APPROVAL S\ffi6e9, Iae. (R&Ml. Page 5 E. All fuel combustion sources with heat input equal to or greater than 20 MMBTUlhr and less than 50 MMBTUlhr shall comply with applicable presumptive RACT requirements of 25 PA Code 1 29.93(b)(2)-(5). All fuel combustion sources with heat input less than 20 MMBTUihr shall comply with presumptive RACT requirements of 15 PA Code 129.93(c). F. RACT for 22 Boiler House: Boiler # 

### I. Boiler #2, and Boiler #3 is combustion tuning. G. RACT for Reformer Unit 860 HTR 2H9 is combus£ion tuning. H. The 868 FCCU NOx emissions shall be limited to 569 tons per year calculated on a 365 day rolling average basis. 

# Smt shall follow good combustion practices controlling the level of excess oxygen and CO promoter in the regenerator to minimize NOx emissions from the regenerator. J.**~**

### shall utilize an inspection and maintenance/monitoring program for VOC fugitive emissions from cooling towers. 

### K.**~** 

### shall utilize a fugitive emissions leak detection and repair program (LDAR) for all valves, pumps, flanges, and compressors in VOC service. All applicable equipment shall be tagged by May 31, 1995. Monitoring of components shall begin by July 31, 1995 and shall be conducted on a quarterly basis (gaseous service) and an annual basis (liquid service) for all sources not covered under an existing LDAR program. 

### L. The 1232 FCCU CO Boiler: CO waste gas combustion unit (580 MMBTUlhr) shall comply with the presumptive RACT requirements of15 PA Code 129.93(c)(4). which is installation, maintenance and operation of the source in accordance with manufacturers specifications. 

## (**~A~d~d-c-o-n-tr-o~lt-e-c~hn-o~lo-g~i-es~fu-r~U~n~it-2~1~0~-~H~1~0~1~(I-ow~N~O~x-----'** 3. RACT Implementation Schedule 

## burners) and Unit 21 0-H201 (ultra-low NOx burners). A. Upon issuance of this approval, StlReee, 

### hIe. (R&M), IR9, 

### shall begin immediate implementation of the measures necessary to comply with the approved RACT proposal. 

## B. 

## s proposing combustion tuning to comply with RACT requirements of25 PA Code 129.91(f) shall perform the annual c ustion tuning by December 31 st 

### ofeach year not to exceed 12 months between tunings. C. Sources applicable resumptive RACT requirements of 25 PA Code 129.93(b)(2) shall complete the annual adjustment or tune-up by ember 

### 31" ofeach year not to exceed 12 months between tunings. D. Sources proposing installing Ultra Lo Ox Burners to comply with RACT requirements of25 PA Code 129.9l(f) shall perform combustion tuning annually I:) 

### ecem 

## Add description that original RACT limits apply until the 4. Testing Requirements and Stack Emission Limitations 

## installation of ultra-low NOx burners on Unit 231-8101 and Unit 865-11H1. A. For units installing ULNB.**~shall** 

### conduct performance tests for NOx. The results of these tests have been submitted to AMS. B. The final NOx RACT emission limits for the #3 Boiler House boilers. 137 Unit FI heater, #22 Boiler House boilers: #1,2, 

## & 3 and the 860 unit Boiler 2H9 have been established through the use of Department approved Continuous Emission Monitoring System (CEMS). Compliance with the limitation listed below 

## will be on a 30 day rolling average ba d h I 

### fCEM d 

### t se on our y averages 0 

### a a. Source 

# I Limitation Boiler House #3 - boilers #37, #38, #39, and #40 

# I 0.330 Ibs. NOxlMMBTU 137 Unit FI heater Reformer Unit 860 Boiler 2H9 #22 Boiler House boilers # I, 

### #2. and # nce with emission limi£s for combustion so C. Complia with a p AMS m separate ortable NOx analyzer. After one year sa ay. at any time. require three one-hour s Iy. AMS may. at any time. require three 0 ! 

### 0.230 Ibs. NOxiMMBTU 

# I 0.20 Ibs. NOxlMMBTU • 0.20 Ibs. NOx/MMBTU rces listed below shall be determined by quarterly stack sampling flpling,**~may** 

### pe£ition AMS for semi-annual monitoring. llck tests per fuel type for each unit where fuels can be fired e-hour stack tests for dual-fuel type combustion sources where 

## Add description that !\lOx RACT emission limit for Unit L 

## 210-H201 has been established based on a rolling 365-day average using CEMS.

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### RACT PLAN APPROVAL 

### Sl:Ifleee. IRC. 

### (R:&Ml. Page 6 both fuels must be fired at the same time and compliance with emission limits will be through the use ofone set of three one-hour stack tests. Limitation (lbs. NOxlMMBTU) Source

### ~ Gas Oil Process Heater Unit 433 n-l**~** 

### 0.060 

## N/A Add NOx emission Process Heater Unit 1332 H-400 heater 

# -- ...Q..156 

## N/A Process Heater Unit 1332 H-401 heater 0.156 

# --**~** 

## rate for Unit Crude Unit 2IOA HTR HIOI 0.089 

### G4 

# - 865-11 H2, Unit Crude Unit nOB HTR H20I

### ~ G,4 

## 866-12H1, and Unit Crude Unit ZIOC HTR 13HI 0.104 

## OA 868-8H101 Hydrocracker Unit 859 HTR 1 H3 0.134 0.4 Hydrogen Plant 861 HTRJHIS 0.133 

## N/A Hydrogen Plant 861 HTR3H 1 N 0.133 

## N/A F-2 

## @ 137 Unit 0.257 

## OA F-3 

## @ 137 Unit 

## N/A OA 8 HH@231 YRit**~** 

### Nf.A H-Z @ 1332 Unit 0.300 

## N/A B·I04@ 1232 Unit 0.177 

## N/A IH-I 

## @859 Unit 0.123 

## OA IH-2 

## @ 859 Unit 0.123 0.4 PH-3 

## @ 864 Unit 0.284 0.4 PH-5 

## @ 864 Unit 0.283 

## OA PH-I 

## @ 864 Unit 0.167 0.4 PH-4 

## @ 864 Unit 0.102 

## OA PH-II 

## @ 864 Unit 0.145 0.4 PH-12 

## @ 864 Unit 0.119 0.4 IIW I @ 

### Sa§**YRi~** 

### G:-J:..J.:; G,4 

### 2H-3 

## @ 860 Unit 0.163 0.4 2H-5 

## @ 860 Unit 0.163 0.4 2H-2 

## @ 860 Unit 0.350 0.4 2H-4 

## @ 860 Unit 0.270 

## OA 2H-7 

## @ 860 Unit 0.157 0.4



### . . D. All annual combustIOn tunmg shall at a minimum meet the reqUirements set forth In 

### 129.93 (b)(2) through (5). E. At least thirty (30) days prior to a perfonnance NOx test,**~shall** 

### infonn AMS ofthe date and time ofthe scheduled test. 5. Recordkeeping and Reporting Requirements A. The pennittee shall maintain a file containing all the records and other data that are required to be collected to demonstrate compliance with NOxlVOC RACT requirements of25 PA Code 129.91 • 129.94. 8. 

### The records shall provide sufficient data and calculations to clearly demonstrate that the requirements of §129.91- 129.94 are met. C. Data or infonnation required to detennine compliance shall be recorded and maintained in a time frame consistent with the averaging period ofthe requirement. D. Records shall be retained for at least two years and shall be made available to 

### the Department on request. 6. The operation of the aforementioned sources shall not at any time result in the emission of visible air contaminants in excess of the limitations specified in Section 123AI. particulate matter in excess of the limitations specified in Section 123.11 or sulfur oxides in excess of the limitations specified in Section 123.22, all Sections orChapter 113 of Article III of the Rules and Regulations of the Department of Environmental Resources. or in the emission of any of these or any

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# c I • 

### RACT PLAN APPROVAL 

## StUlf'lee, IRe. (R&Mt Page 7 other type ofair contaminant in excess ofthe limitations specified in, or established pursuant to. any other applicable rule orregulation contained in Article III. 7. The company shall not impose conditions upon or otherwise restrict the Department's access to the aforementioned source(s) and/or any associated air cleaning device(s) and shall allow the Department to have access at any time to said source(s) and associated air cleaning device(s) with such measuring and recording equipment, including equipment recording visual observations, as the Department deems necessary and proper for performing its duties and for the effective enforcement ofthe Air Pollution Control Act. 8. Revisions to any emission limitations incorporated in 

### this RACT Approval will 

### require resubmission as revision to 

### the PA State Implementation Plan. The applicant shall bear the cost of public hearing and notification required for EPA approval as stipulated in 25 PA Code §129.9(h).

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# c AppendixA RACTCost Effectiveness Analysis

### NOx RACT Control Cost Effectiveness Cost Effectiveness Summary

# ~~'"- Unit 231-BlIn NA 102.243

NA ILNB&SNCR NA ILNB& FGR NA ISNCR 39,924 Unit 865-11Hl NA NA I\A I\A NA 42,874 Cost Effectiveness (!(fon) Unit865-11H2**Uni~** Unit 21O-H201 Unil86b-12Hl Unit &68-8HIOl 34,287 30,796 !'JA 34,831 35,060 32,909 27,397 !'JA 33,524 33,782 6,737 9,477 NA 6,737 6,737 11,045 57,667 162,271 11,331 14,513 8,704 I\A NA 8,960 12,965 13,132 10,825 28,098 13,379 13,482

## ~~~~~~!t~=::::::===t==1!:g[=:::1Based on 90% equity cost ofthe average Carlyle energv funds and 10% after tax debt cost ACF

## = ;(1 + i)R (1

### +/)"-1 EPA Air PollutionControl Cost Manual, Sixth Edition, EPA!452/8-02-001 - Equation 2.8a Chemical Year Engineering Cost Index 1986 318.4 1991 361 2012 582.2 Cost Escalation Factor for SCR1 1,83 Cost Escalation Factor for LNB, SNCR, 1.61 and feR' I Costdata from Allenuztillf! Control Techmques Document· NOs Emissionsfrom Process Hetll:ers (Revised)· EPA-453!R93-034 scaled from 1986 102012cosl5 using the Cost Escalation factor. 'Costdata from Altertlalive Control Techniques DommentNO, EmissifJ1lsfrom Process Heaters (R.emsed) - EPA-453!R93-034 scaled from 1991 10 2012 cosl5 using theCost Escalation Factor. Soun:. Ultra low-NO,burner.; and Selective ULNB&SCR Catalytic Reduction SelectiveCatalytic Reduction SCR Ultra low-NO, burner.; UL"IB Low-NO,burner.; and Selective Non- L"IB& SNCR Catalytic Reduction Low-NO, burners and FlueGas LNB&FGR Rffirculation Selective !'Jon-Catalylic Reduction SNCR Design Capacity Soun:e N;un. (MMBtWhr) Unit 231·B101 104,5 Unit 865-11Hl 87.3 Unit 865-11H2 I 64.2 Unit 210-HI01 192.0 Unit 210-H201 254.0 Unit 86b-12Hl 61.2 Unit 86S-llHl01 60,0 Control Efficiency Comment

96% Combmmg both removal efficiencies of Ul.NB and SCR 85% Based on Unit 1332 perfonuance, 66 to 87% Based on vendorexperienceat 0,03 Ib!MMBtu. Combining buth removal efficiencies. Assumes 50% control efficiency for LNB and 40% control efficiency 70% for SNCR. Altenmtive CotltrO/ Techlliqlles Documenl- NO, £misswllsfrom Proc£ss Healers (Re,,;sed) - EPA453/R-93-034, 55% Irol Techlliqlles DOCIIment - NO, Emissionsfrom Proc£ss Heaters (Rel'ised) . EPA-453/R·93-034, 40% Heat"r stack temperatun> below 700"F results in low NO,removal efficiency, EPA Air Pollution Control Technology FactSheet - EPA452/F-024l31. NO. Emission Number of Rate Summary ofTeclmkallnfeasibilitles for NO, Control (lbjMMBtu) Burners

0,030 None. SCR would not physically fit the plot space and there is not adequate pressure to 0,030 8 overcome the SCR pressure drop; therefore, SCR is infeasible. FGR installation would require the installatmn ofmechanical draft bumer.;, which is a major re-design of the unit therefore FGR is infeasible. 0,113 8 None. 0.089 6 FGR would not physically fit theplot space; therefore, it is infeasible, SCR would notphysically fit the plot space and thereis not adequate pressure to 0.030 8 overcome theSCR pressure drop; lhefPfore, SCR is infeasible. FGR installation would require theinstallation of mechanical draft burners, which is a major re-design of the unit therefore FGR is infeasible. 0.113 6 None. 0.113 4 None. 

### I

App A RACT Cost Effectiveness 9-6-2013.xlsx RACT Cost Summary lof66

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JPES Refinery Heaterfiring Rate Increase Plan Approval NO. RACTControl CostEffectiveness Costsderived fromAlternalive Conlrol Techniques Document NOx Emissionsfrom Procl!5s Heaters (Rn>ised) - EPA-453/R-93-034 AU costs are scaled from 2012 1.1.5. dollar.; using the appropriate Cost Escalation Factor. Capita! CostofLow NO Burners lpage6-4 and 6-51: Tel 

## =30,000 

## +HQ[5,230 - (622 )( BQ) 

## +(26.1 )( BQ')] Where: TO**~** Total Capital Investment HQ**~** heatereapadty (GJjhr) BQ**~** burner heat release rate (GJ/hr) BQ**~** HQ/NB x (1.158 + 8/HQ) NB**~** numberofburners Capital Costof Ultra-low NO, Burners: See the 'Refinery ULt..'1l Control Costs" tab for capital cost detailsfor ultra-low NO. Burners Capital CostofSelective Non-Catalvtic Reduction (page 6-7):

Tel = 31,850(HQ)o.6 HQ**~** heatercapacily (GJ/hr) Overatins Cost ofSelective Non,catalytic Reduction (page b-Il): ( 1 moleNOr) (17 lb NH3) (1 mole NH3) ($0.125) ( hOUrS) NH3cost =Q x (lbIMMBtu) x 46lbNO z )( 1moleNH3 x 1 mole NOr x IbNH3 )( 8,760 year Where:**Q~** heatercapacity. MMBIu/hr ( 0.3 kWh) (ton NH3) ($0.06) Electricty cost = ---H- x --- x -k h tonN 3 year W Where:



## --- =Q x Ib NO MMBtu) x )( )( x --- x 8,760-- tonNH 3 

# (1 moleNOr) (17 Ib NH3) 

# (1 mole Nfl3) ( ton ) ( hOUrS) year (rl 46 Ib NOr 1moieNfl 3 1moieNOz 20001b year Capita! Costof Selective Catalytic Reduction (pageb-Ill: ( Q)O'6 (Q) Tel 1,373,000 x 48.5 

### +49,000)( 485 Where: Q**~** heater capacity, MMBIu/hr OperatingCostof Selectivp Catalytic Reduction (page6-91:

_ (1 moleNOr) (17 Ib Nfl,) (1 moleNfl3) ($0.125) (8,760 hOUrs) Nfl3 cost - Q )( (lbIMMBtu)( 46lb NOr X 1 moleNfl3 )( 1 mole NOr X lb Nfl3 X year Where: Q**~** heater eapacily, MMBIu/hr Note thecapacity factor has been assumed tobe equat to 1; theretoT(', the capacily factor term has been omitted Catalyst Replacementeast 

## =49,000 x years Electricty cost =

# (~~~~~:) X

# CO;e~:3) x

# (~~:) Where:

ton NII3 _ 

# (1 mole NOr) (17IbNII,) 

# (1 mole Nil,) ( ton \ ( hourS)

year - Q x (lb NOrIMMBtu) X 46lb NOr X 1moleNfl3 x 1 mole NOr X 2000 lb) X 8,760 year CapitalCostof Fine Gas RPcirculation /page6-9):

Tel = 12,800(HQ)O.6 Where: HQ**~** heatereapacily (GJ/hr) Operating CostofF1"" Gas Recirculation /page6-10): ( 0.75 kW) (8,760 hOurs) ($0.06) Electrictycost 

## = (motor hp) x ----;:;:;;- X year x kWh Where: motor hp**~** FGR fan motor horsepower, (1/5) x (Q) Q**~** heater capacity, MMBIu/hr
App A - RACT Cost Effectiveness 9-6-2013.xlsx Refinery Control Costs 2 of 66

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# r'
PES Refinery HeaterFiring Rate Increase Plan Approval NOx RACT Control Cost Effectiveness 

# r

Ultra Low NO. Burner Costs - from PES Refinerv Proiect Experience Economic Data 1332 H-400/H-401 Heater 137 F-3 Heater
Source Name Unit 2.."I1-BI0l Unit 865-11HI Unit 865-11H2 Unit 210-H101 Unit 210-H201 Unit 866-12Hl Unit 868-8HI01 Heater Fired Duty (MMBtu/hr)
Design Capacity

(MMBtufhr) 104.5 87.3 64.2 192.0 254.0 61.2 60.0

App A - RACT Cost Effectiveness 9-6-2013.xlsx 

### Number of Burners

ULNB Capital

Cost Using ($jMMBtufhr) $617,103 $515,532 $379,120 $1,133,816 $1,499,944 $361,404 $,:154,317 BurnerHeat Release (MMBtufhrfbumer) 7.8 15 ULNB Total Capital Investment NA NA $559,581 $1,673,512 NA $533,432 $522,973 Base Year ULNB Cost ($fburner)

Refinery Burner Control Costs 

### Normalized Cost ($jMMBtufhr) $6,444 $5,367 $5,905 

# r

3 of 66

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# r' ('
PES Refinery Heater Firing Rate Increase Plan Approval Unit 231-BIOl 

### RACT Cost Effectiveness Summary A B 

### C D E 

### F G H 

### Control Option Current , Design Firing 

# IE' , R 

### t Potential EmissIOns miSSion a e (MMBtu/hr) 1 (TrY) 

### (lb/MMBtu) Maximum Post Control 

# I Control Emissions Efficiency @ 

### Design Firing (%) 'TPY 2012 

### Total 

# I2012 

### O&M Cost Capital Cost ($) ($) 

### 13.7 104.5 104.5 104.5 6.2 104.5 

### 8.2 104.5 13.7 

### Calculation =C*O-D Notes: 11.7 9.6 

### 7.6 

### 5.5 0.0 = 

### C-E NA 4,118,447

NA NA 773,123



### NA

1 

### ULNB are planned to be installed on the Unit 231-B101 heater and the currentemission rate is assumed to be O.03lb/MMBtu. 2

### See "RACT Cost Summary" tab for details on the Annualized Cost Factor (ACF).

App A - RACT Cost Effectiveness 9-6-2013.)(ls)( 231-B101 RACT 

### NA 7 2012 

### Annualized Cost2

($) 

# ('

2012 

### Cost Effectiveness

($/Ton)

NA

4of66

# JPES 

### Refinery Heater FiringRate Increase Plan Approval NO); RACT Control Cost Effectiveness Source Unit 23]·B]0] Control SCR Rated Heat Input ]04.5 Number ofBurners 26.0 Baseline Actual Emissions 13.73 Current Emission Rate 0.030 Control Efficiency 85% Heater Capacity 110.3 Burner Heat Release Rate 5.2 Evaluated at New Firing Limit at 2012 Cost and Efficiencies MMBtu/hr Burners tpy IblMMBtu G.Jlhr GJ/hr Costs derived from 

### Alternative Control Techniques Document- NOx Emissions/rom Process Heaters (Revised) - EPA-453/R-93-034

DIRECTCOSTS COST COMPONENT:
PurchasedEquipment Costs

Equipment Cost (EC) Instrumentation (Included in above costs) Sales taxes (Included in above costs) Freight (Included in above costs) 

### Subtotal- PurchasedEquipment Costs (PEC) Direct Installalion Costs Foundations & supports; handling & erection; electrical; piping; etc. Site Preparation I Buildings- Included above 

### Subtotal - DirectInstallation Costs TOTAL DIRECTCOSTS (TDC) INDIRECTINSTALLATION COSTS Engineering Costs (Included in above costs) Construct. & Field Expenses (Included in above costs) Contractor Fees (Included in above costs) Start-up (Included in above costs) Perfonnance Test (Included in above costs) Contingency (3% ofPEC) TOTAL INDIRECTCOSTS. IC 

## TOTAL CAPITAL INVESTMENT (Tel)

App A - RAG Cost Effectiveness 9-6-2013.xtsx Unit 231-B10l SCR COST ($)

3,998,493

3,998,493


# o

--- o 3,998,493

119.955 119,955 4,118,447

5 

### of 66

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### PES Refinery Heater Firing Rate Increase Plan Approval NOx RACT Control Cost Effectiveness COST COMPONENT: ANNUAL DIRECTCOSTS Operation andMaintenance Labor Maintenance Labor and Material (2.75% ofTCI) 

### Annualized Cost Factor Replacement Life (years) 

### = Interest Rate (%) Annualized Cost Factor Replacement cost 

### Subtotal- Operation andMaintenance Labor Utilities Ammonia Cost Catalyst Replacement Cost Electricity Cost 

### Subtotal - Utilities 

### TOTAL 

## ANNUAL DIRECT COSTS·
COST COMPONENT: TOTALANNUAL O&M COSTS Annualized Cost Factor Equipment Life (years) 

### = Interest Rate (%) = 

### Annualized Cost Factor 

### CAPITAL RECOVERY COSTS TOTAL CAPITAL REQUIREMENT TOTALANNUAL CAPITAL REQUIREMENT TOTAL ANNUAliZED COST (Total annual O&M cost andannualizedcapital cost)

App A - RACT Cost Effectiveness 9-6-2013.xlsx Unit 231-B101 SCR 

### COST ($)


### 113,257 

### 113.257 10 21.83 0.25

2,046 34,054

0.1 

### 36,100 149,357
COST ($)



### 149,357 10 21.83 0.25 4,118,447 

### 1,043,985 1.193,342

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### PES Refinery HeaterFiring Rate Increase Plan Approval NOx RACT Control Cost Effectiveness Source l:nit 231·BIOI Control SNCR Rated Heat Input 104.5**~umber** of Burners 26.0 Baseline Actual Emissions 13.73 Current Emission Rate 0.030 Control Efficiency 40% Heater Capacity 110.3 Burner Heat Release Rate 5.2 Evaluated at New Firing Limit at 2012 Cost and Efficiencies MMBtulhr Burners tpy IbfMMBtu GJlhr GJlhr Costs derived from Alternative Control Techniques Document- NOx Emissions from ProcessHeaters (Revised) - EPA-453/R·9J.-034

DiRECTCOSTS COST COMPONENT:
PurchasedEquipment Costs

Equipment Cost (EC) Instrumentation (Included in above costs) Sales taxes (Included in above costs) Freight (Included in above costs) Subtotal- PurchasedEquipment Costs (PEC) Direct Installation Costs (Based on Vendor Discussion) Foundations & supports; handling & erection; electrical; piping; etc. Site Preparation I Buildings· Included above Subtotal- DirectInstallation Costs TOTAL DIRECT COSTS (TDC) INDIRECTINSTALLA TlON COSTS Engineering Costs (Included in above costs) Construct. & Field Expenses (Included in above costs) Contractor Fees (Included in above costs) Start-up (Included in above costs) Performance Test (Included in above costs) Contingency (3% ofPEC) TOTAL INDIRECTCOSTS. IC 

### TOTAL CAPITAL INVESTMENT (TCI)

App A - RAeT 

### Cost Effectiveness 9·6-2013.xlsx Unit 231-B101 SNCR COST (5)

750,605

750,605


## o o 750,605

22,518 22,518 773,123



### 7 of 66

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JPES Refinery Heater Firing Rate Increase Plan Approval NOx RACT Control Cost Effectiveness COST COMPONENT: 

### ANNUAL DIRECTCOSTS Operation andMaintenance Labor Maintenance Labor and Material (2.75% ofTCl) 

### Annualized Cost Factor Replacement Life (years) 

### = Interest Rate (%) 

### = Annualized Cost Factor Replacement cost 

### Subtotal- Operation andMaintenance Labor Utilities Ammonia Cost Electricity Cost 

### Subtotal - Utilities 

### TOTAL ANNUAL DIRECT COSTS 8
COST COMPONENT: 

### TOTAL ANNUAL O&M COSTS Annualized Cost Factor Equipment Life (years) 

### = Interest Rate (%) 

### = Annualized Cost Factor 

### CAPITAL RECOVERY COSTS TOTAL CAPITAL REQUIREMENT TOTAL ANNUAL CAPITAL REQUIREMENT TOTAL ANNUALIZED COST (Total annual O&Mcostandannualizedcapital cost)

App A - RACT Cost Effectiveness 9-6-2013.xlsx Unit 231-B101 SNCR COST ($)
21,261 21,261 10 21.83 0.25

2,046 0.1 2,046 23,307
COST ($)

23,307 10 21.83 0.25 773,123 195,979 219,286

8of66

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PES Refinery Heater Firing Rate Increase Plan Approval Unit 865-11H1 RACT Cost EHectiveness Summary A B 

### C D E F G H 

### Current Control Maximum Post Potential 2012 Total Control Option Design Firing Emission Rate Potential Emissions Efficiency Control Emissions NO, Capital Cost 2012 O&M Cost (MMBtu/hr) (lb/MMBtu)l 

### (TPY) (%) @ 

### Design Firing Reduced ($) ($) 

### (TPY) (TPY) ULNB&SCR 87.3 0.03 11.5 %% 0.5 11.0 NA NA SCR 87.3 0.03 11.5 85% 1.7 9.8 NA NA LNB&SNCR 87.3 0.03 11.5 70% 3.4 8.0 NA NA LNB& FGR 87.3 0.03 11.5 55% 5.2 6.3 NA NA SNCR 87.3 0.03 11.5 40% 6.9 4.6 694,045 20,796 ULNB 87.3 0.03 11.5 0% 11.5 0.0 NA NA Calculation : A • B • 8760 / 2000 

## =C' (1 - D) 

## =C-E Technicallnfeasibilities: SCR would not physically fit the plot space and there is not adequate pressure to overcome the SCR pressure drop; therefore, SCR is infeasible FGR installation would require the installation of mechanical draft burners, which is a major re-design ofthe unit; therefore FGR is infeasible Notes: 1 

### ULNB are planned tobe installed on the Unit 865-11H1 heater and the currentemission rate is assumed to be 0.03 lb/MMBtu. 2 

### See "RACT Cost Summary" tab for details on the Annualized Cost Factor (ACF).

App A - RACT Cost Effectiveness 9-6-2013.xlsx 

### 865-UH1 RACT 

# t'

2012 Annualized 2012 Cost Cost2 

### Effectiveness

($) ($/Ton) NA NA NA NA NA NA NA NA 196,729 42,874

NA NA 

## =(G' ACF) + 

### H 

## =I / F

9 of 66

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# c PES Refinery Heater Firing Rate Increase Plan Approval NOx RACT Control Cost Effectiveness Source lInit 865-11Hl Control S"ICR Rated Heat Input 87.3 Number ofBurners 8.0 Baseline Actual Emissions 11.47 Current Emission Rate 0.030 Control Efficiency 40% Heater Capacity 92.1 Burner Heat Release Rate 14.3 Evaluated at New Firing Limit at 2012 Cost and Efficiencies MMBtulhr Burners tpy IblMMBtu GJlhr GJlhr Costs derived from 

### Altl!1'native Control Techniques Document - NOxEmissions from Process Heaters**(R~ised)** 

### - EPA-4531R-93-034

DIRECTCOSTS COST COMPONENT:
PurchasedEquipment Costs

Equipment Cost (EC) Instrumentation (Included in above costs) Sales taxes (Included in above costs) Freight (Included in above costs) 

### Subtotal- PurchasedEquipment Costs (PEC) Direct installation Costs (Based on Vendor Discussion) Foundations & supports; handling & erection; electrical; piping; etc. Site Preparation 

### I Buildings- Included above 

### SUbtotal- Direct Installation Costs TOTAL DIRECT COSTS (TDC) INDIRECTINSTALLA TION COSTS Engineering Costs (Included in above costs) Construct. & Field Expenses (Included in above costs) Contractor Fees (Included in above costs) Start-up (Included in above costs) Performance Test (Included in above costs) Contingency (3% ofPEC) TOTAL INDIRECT COSTS, IC 

## TOTAL CAPITAL INVESTMENT (TCI)

App A - RACT Cost Effectiveness 9-6-2013.xlsx Unit 865-11H1 

### SNCR COST ($)

673,830

673.830


## o 

# o 673.830

20,215 20,215 694,045



### 10 

### of 66

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# , PES Refinery HeaterFiring Rate Increase Plan Approval NOx RACT Control Cost Effectiveness COST COMPONENT: ANNUAL DIRECTCOSTS Operation andMaintenance Labor Maintenance Labor and Material (2.75% ofTCl) Annualized Cost Factor Replacement Life (years) Interest Rate (%) = 

### Annualized Cost Factor Replacement cost Subtotal - Operation andMaintenance Labor Utilities Ammonia Cost Electricity Cost Subtotal- Utilities 

### TOTAL ANNUAL DIRECT COSTS·
COST COMPONENT: TOTAL ANNUAL O&M COSTS Annualized Cost Factor Equipment Life (years) 

### = Interest Rate (%) 

### = Annualized Cost Factor CAPITAL RECOVERYCOSTS TOTAL CAPITAL REQUIREMENT TOTAL ANNUAL CAPITAL REQUIREMENT TOTALANNUALlZED COST (Total annual O&M cost andannualizedcapital cost)



### App A - RACT Cost Effectiveness 9-6-2013.xlsx Unit 

### 865-11Hl SNCR COST(S)
19.086 19,086 10 21.83 0.25

1,709 0.1 1,709 20,796
COST ($)



### 20,796 10 

### 21.83 0.25 694.045 175,933 196,729



### 11 

### of66

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# r'**~** PES Refinery Heater Firing Rate Increase Plan Approval Unit 865-11H2 RACT Cost Effectiveness Summary A B 

### C D E F G 

### 1-1 Current Control Maximum Post Potential 2012 Total Control Option Design Firing Emission Rate Potentia1Emissions Efficiency Control Emissions NO, Capital Cost 2012 O&M Cost (MMBtu/hr) (lb/MMBtu)l (I'rY) 

### (%) @ 

### Design Firing Reduced 

### ($) ($) (TPY) (TPY) ULNB&SCR 64.2 0.113 31.8 96% 1.3 30.5 3,631,525 125,523 SCR 64.2 0.113 31.8 85% 4.8 27.0 3,071,944 110,135 ULNB 64.2 0.113 31.8 73% 8.4 23.3 559,581 15,388 LNB&SNCR 64.2 0.113 31.8 70% 9.5 22.2 857,483 28,316 LNB&FGR 64.2 0.113 31.8 55% 14.3 17.5 512,272 22,250 SNCR 64.2 0.113 31.8 40% 19.1 12.7 577,165 20,607 Cakulation 

### = A • B• 8760 / 

### 2000 = 

### C' (1 - 

### D) =C-E Notes: 1 

### Unit 865-111-12 is projected to 

### be above PADEP presumptive RACT firing limits and assumed NO, emission rate limit ofO.1l3Ib/MMBtu is 

### used. 2 

### See "RACT Cost Summary" tab for details on the Annualized Cost Factor (ACF).

App A· RACT Cost Effectiveness 9-6-2013.xlsx 

### 86S-11H2 RACT

# ~

2012 Annualized 2012 Cost Effectiveness 

### ($) ($/Ton) 1,046,078 34,287 888,841 32,909 157,237 6,737 245,679 11,045 152,106 8,704 166,913 13,132 = (G • ACF) + 

### 1-1 = 

### I / F

12 of 66

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JPES Refinery Healer Firing Rate Increase PlanApproval NO. RACf Co•• rol Cost Effectiv.... ' Source lInit865-1lH2 Control ULNB&SCR Rated lies. Input 64.2 Number ofBurners 8.0 Basd'MActual Emissions 31.78 Current Emission Rate 0.113 Cootrol Effici.ncy**96~.** He.lerCapacity 67.7 Bumer lIesl Rele.,e Rale 10.8 Evaluated at New Firilll Limit at 2012 Cost and Efficiencies MMBlulhr BUfners tpy IblMMBtu GJlhr GJlbr Cosl, derived fromAlter""tive Colllro! T ecilniqlles Doell""'''''NOx EmissioltS from ProcessHeater> (Rt!t';sed) - EPA-453IR-93-034

IDIRECTCOSTS - ULNB COST COMPONENT:
PurchasedEquipment Costs

Equipment Cost (EC) Instrumentation (10"10 ofEC) Sales taxes (5% ofEC) Freight (8% ofEC) Sllbtotal- PurcnasedElfllipment Costs (PEG) DirectInstallation Costs (Basedon Vendor Discussion) Foundations & supports; handling & erection; electrical; piping: etc. Site Preparation / Buildings- Included above SlIbtotaJ - DirectInstaIlation Com TOTAL DIRECTCOSTS (TOC) ULNB INDIRECTINSTALU170NCOSTS - ULNB Engineering Costs (5% ofPEC) Construct. & Field Expenses (InclUded in above costs) Contractor Fees (l0"!, ofPEC) Start-up (l%ofPEC) Performance Te.. (1% ofPEC) Contingency (3% ofPEC) TOTAL INDIRECT COSTS, IC - ULNB DIRECTCOSTS - SCII PurchasedEquipment Costs Equipment Cost (EC) Instrumentation (Included in above costs) Sales taxes (Included in above costs) Freight (Included in above costs) SPbtotal- l'llrchasedElfllipment Costs (PEG) Direct Instal/atioH Costs Foundations & supports; handling &erection: electrical; piping; etc. Site Preparation / Buildings-Included above SlIbtotaJ - Direct Instaliati"" Costs 

### I TOTAL DIRECTCOSTS (TDC) - SCII INDIRECTINSTALLATIONCOSTS - SCII Engineering Costs (Included in above costs) C struet & Feld Expenses (In I d d· bove costs) ! on I cue ma Contractor Fees (inCluded in above costs) Stan.up (Included In above costs) Performance Test (Included in above \:osts) Contmgency (3% ofPEC) 

### I TOTAL INDIRECT COSTS, IC - sell ITOTAt CAPITAL INVESTMENT (TCI) - ULNB ITOTAL CAPITAL INVESTMENT (TCI) - SCR ITOTAL CAPITAL INVESTMENT (TCI)

App A - RACT Cost Effectiveness 9-6-2013.•ls. Unit 865-11H2 ULNB & SCR COST ($)
379.120 37.912 18.956 30.330 466,317



### o 466,.317 23.316 46.632 4.663 4.663 13.990 93.263
2.982.470
2,982.470


### o

-

### o 2.982.470

.,

### -
,., 89.474 89,474 559.581 3.071,944 3.631,525

13 of66

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# JPES Refinery Healer FiringRale increaS<' Plan Approval NO. RACT Conlrol C.. II1IT.<ti......

COST COMPONI1NT: ANNUAL DIRECTCOSTS Operation andMainlenance Labor Maintenance Labor and Matenal (2.75% ofTCi) Annualized COSI Faclor Replacement Life (years)**~** Interest Rate (%) = Annualized Cost Factor Replacement cost ...v.hin/111 - Operation alldMainJelUlnce Labor U,ilities Ammonia Cost Catalyst Replacement Cost Electricity CoS! SlIbtotal- Utilities l U lAL Al'Il"lUAL lJIKL"l 

## "u"'"
COST COMPONl1i11T: TOTALANNUAL O&'M COSTS AnnualizedCost Factor Equipment Life (years)**~** Interest Rate (%) = Annualized Cost Factor CAPITAL RECOVERYCOSTS TOTAL CAPITAL REQUIREMENT TOTAL ANNUAL CAPITAL REQUIREMENT TOTALA/,;'!'>VALIZED COST (T

oID.Ia"""alOdMcost anda"""aii",dct1pilalcost) 10 21.83

10 21.83

App A. RACT Cost Effectiveness 9·6-2013.•ls. Unit 865-11H2 ULNB & 5CR COST(S)
99,867 99,867

0.25

4,735 20,921

OJ 25,650 

### I 125,523 COST(S) 125,523

0.25 3,631,525 920,555 i 1,046,078

14 of66

# J

### PES Refinery Heater FiringRate Increase Plan Approval NOx RACT Control Cost Effectiveness Source Unit 865-l1H2 Control SCR Rated Heat Input 64.2 Number ofBurners 8.0 Baseline Actual Emissions 31.78 Current Emission Rate 0.113 Control Efficiency 85% Heater Capacity 67.7 Burner Heat Release Rate 10.8 Evaluated at New Firing Limit at 2012 Cost and Efficiencies MMBtu/hr Burners tpy IblMMBtu GJ/hr GJ/hr Costs derived from Alternative Control Techniques Document - NOxEmissions/rom Process Heaters (Revised) - 

### EPA-453/R-93-034

DIRECTCOSTS 

### COST COMPONENT:
PurchasedEquipment Costs

Equipment Cost (EC) Instrumentation (Included in above costs) Sales taxes (Included in above costs) Freight (Included in above costs) 

### Subtotal - PurchasedEquipment Costs (PEC) Direct Installation Costs Foundations & supports; handling & erection; electrical; piping; etc. Site Preparation 

### I Buildings- Included above 

### Subtotal - Direct Instal/ation Costs TOTAL DIRECT COSTS (TDCj INDIRECTINSTALLATION COSTS 

### Engineering Costs (Included in above costs) Construct. & 

### Field Expenses (Included in above costs) Contractor Fees (Included in above costs) Start-up (Included in above costs) Performance Test (Included in above costs) Contingency (3% ofPEC) TOTAL INDIRECTCOSTS, IC 

### TOTAL CAPITAL INVESTMENT (TCI)

App A· RACT Cost Effectiveness 9-6-2013.xlsx Unit 86S-11H2 SCR 

### COST ($)


### 2,982,470


### 2,982,470


# o

... o 2,982,470

89,474 

### 89,474 3,071,944

lS of 66

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### PES Refinery Heater Firing Rate Increase Plan Approval NOx RACT Control Cost Effectiveness COST COMPONENT: ANNUAL DIRECTCOSTS Operation andMaintenance Labor Maintenance Labor and Material (2.75% ofTCI) Annualized Cost Factor Replacement Life (years) = 

### Interest Rate (%) Annualized Cost Factor Replacement cost Subtotal - Operation andMaintenance Labor Utilities Ammonia Cost Catalyst Replacement Cost Electricity Cost Subtotal - Utilities 

### TOTALANNUAL DIRECT 

## COSTS·
COST COMPONENT: TOTALANNUAL O&'M COSTS Annualized Cost Factor Equipment Life (years) = 

### Interest Rate (%) 

### = Annualized Cost Factor CAPITAL RECOVERYCOSTS TOTAL CAPITAL REQUIREMENT TOTALANNUAL CAPITAL REQUIREMENT TOTAL ANNUALIZED COST (Totalannual O&Mcostandannualizedcapital cost)



### App A RAG Cost Effectiveness 9-6-2013.xlsx 

### Unit 865-11H2 SCR 

### COST(S)
84,478 84,478 10 21.83 0.25

4,735 20,921

0.3 25,656 110,135 COST(S)

110,135 10 21.83 0.25 3,071,944 778,707 888,841

16 of 66

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### PES 

### Refinery Heater Firing Rate Increase Plan Approval NOx RACT Control Cost Effectiveness Source lJnit 865-IIH2 Control lJLNB Rated Heat Input 64.2 Number ofBurners 8.0 Baseline Actual Emissions 31.78 Current Emission Rate 0.113 Control Efficiency 73% Heater Capacity 67.7 BurnerHeat Release Rate 10.8 Evaluated at New Firing Limit at 2012 Cost and Efficiencies MMBtu/hr Burners tpy IblMMBtu GJlhr GJ/hr Costs derived from 

### Alternative Control Techniques Document- NOx 

### Emissions/romProcess Heaters (Revised) - EPA-4531R-93-034

DIRECTCOSTS 

### COST COMPONENT:
PurchasedEquipment Costs



### Equipment Cost (EC) Instrumentation (10% ofEC) Sales taxes (5% ofEC) Freight (8% ofEC) 

### Subtotal- PurchasedEquipment Costs (PEC) Direct Instal/ation Costs (Based on Vendor Discussion) 

### Foundations & 

### supports; handling & 

### erection; electrical; piping; etc. Site Preparation I 

### BuiIdings- Included above 

### Subtotal- Direct Installation Costs TOTAL DIRECT COSTS (TDC) INDIRECTINSTALLATION COSTS 

### Engineering Costs (5% ofPEC) Construct. & 

### Field Expenses (Included in above costs) Contractor Fees (10% ofPEC) Start-up (1% 

### ofPEC) Performance Test (1% ofPEC) Contingency (3% ofPEC) TOTAL INDIRECT COSTS, IC 

### TOTAL CAPITAL INVESTMENT (TCI)

App A - RACT Cost Effectiveness 9-5-2013,xlsx Unit 855-11H2 ULNB 

### COST ($)


### 379,120 37,912 18,956 30,330 466,317


# o o 466,317 23,316 46,632 4,663 4,663 13,990 93,263 559,581



### 17 of 55

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# , PES Refinery HeaterFiring Rate Increase Plan Approval NOx RACT Control Cost Effectiveness COST COMPONENT: ANNUAL DIRECTCOSTS Operation andMaintenance Labor Maintenance Labor and Material (2.75% ofTCI) 

### Annualized Cost Factor Replacement Life (years) Interest Rate (%) Annualized Cost Factol Replacement cost 

### SublOtaI- Operlllion andMaintenance Labor Utilities None 

### Subtotal- Utilities 

### TOTAL 

## ANNUAL DIRECT COSTS·
COST COMPONENT: TOTAL ANNUAL O&M COSTS AnnualizedCost Factor Equipment Life (years) = Interest Rate (%) Annualized Cost Factor 

### CAPITAL RECOVERYCOSTS TOTAL CAPITAL REQUIREMENT TOTALANNUAL CAPITAL REQUIREMENT TOTAL ANNUALIZED COST (Total annual O&M cost andannualizedcapitalcost)

App A - RACT Cost Effectiveness 9-6-2013.xlsx Unit 865-11H2 UlNB 

### COST ($)
15,388 15,388 10 21.83 0.25



### 0.0 15,388


### COST ($)

15,388 

### 10 21.83 0.25 559,581 141,848 157,237

18of66

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JPES Refinery 

# C HeaterFiring Rate In<",.,., Plan Approval NO, RACT Control CO"Ellf<:Iiv..... ' Sou,.. Unit 865-IIHZ Control LNB&SNCR Ra.... lleatlnput 64.Z MMBhlfbr Nwnber ofll&arners 8.Il Burnen Baseline Actu.ai Emissions 31.78 tpy CUrTeDt Emission Rate 0.113 Ib/MMBru ControJ Efficiency 70"1. HeaterC.pacity 67.7 GJ/hr Burner H•• t Release Rate 10.8 GJlbr Evaluated.lN("W Firing Limit at 2012 C.,t and Effldenties C.,,,, derived rrom AI1_", Control Techniques n-mOftt- NOx Elffissions frOlff I'rocfls fl.",.... (R"'''d) EPA-lS3/R-9J.034 COST COMPONENT: COST(S) DIRECTCOSTS- !.NB Purchased £quipmenl COSIS Equipment Cost (Eel 189.917 Instrumentation (lO% ofEC) 18,992 Sales taxes (5%ofEC) 9,496 Freight (8% ofEC) 15,193 Sub.OIoJ- PII,dws.d Eqllipmml Com (PEC) Z33,593 DirectInsto/Jalion Costs IBoscd on Vendor Discussion) Foundations & supports; handling & erection; eleetrical; plping: etc, 0 Site Preparation I Buildings- Included above --- 

### ---- SNbtotaJ- Dir«1 I Ifstall_ion CnstJ 0 TOTAL DIRECTCOSTS ([DC) - LNB 133,598 INDIRECTINST:4LL4TION COSTS - LNB EngineeringCosts (5% ofPEC) 11.680 Construct. & Field Expenses (Included in above eosts) Contractor Fees (lon/o ofPEC) 23.360**Start~up** 0% ofPEC) 2.336 Performance Test (1 % ofPEC) 2,336 Contingency (3616 ofPEC) 7,008 TOTAL INDIRECTCOSTS, IC - LNB 44>,710 DIRECTCOSTS - SNCR PurchasedEquipment C05/5 Equipment Cost {Eel 560.355 lnstrumemation (Included jn above cost,,) -- - Sales taxes (Included in above costs) 

### -- - Freight (Included in above costs) SM_oJ- PII,cMasedEqltipIMlfJ Com (PEe) 560,355 DireCI Imaol/alion Cos's (Based on Vendor Discussion) Foundations & supports; handling & erection: electrical: piping; etc, 0 Sile Preparation!**Buildjngs~** Included above --0-- SMlnoIaJ**~ Dir~cll"'JIaJhUi.o"**  Costs TOT:4L DIRECTCOSTS ITDCI- SNCR 56O,3SS INDIRECTJNSTALL4TION COSTS - SNCR Engineering Costs (Included in abovc costs) Construct & field Expenses (Included in above costs) Contractor Fees (Included in above costs) 

### -_. Start·up (lnduded in above costs) Perfonnance Test (Included in above costs) 

### -- Contingency (3% ofPEC) 16,811 TOTAL INDIRECTCOSTS, IC - SNCR 16,811 TOTAL CAPITAL INVESTMENT (TCI) - LNB 280,318 

## I TOTAL CAPITAL INVESTMENT (l'CI) - SNCR 577,165 

### I TOTAL CAPITAL INVESTMENT (TCI) 857,483 

### I

App A - RACT Cost Effectiveness 9-G-2013.xI5X Unit 86S-11H2 LNB & SNCR 19 of 66

# JPES Refinery HeaterFiring Rate Increase Plan Approval NO. RACf Control Co•• ElIKtI"".... COST COMPONENT: ANNUAL DIRECTCOSTS Operalion andMaintenance Labor Maintenance Labor and Material (2,75% ofTef) Annuo{izeJCost Fac/or Replacement Life (years) = Interest Rate ('Yo)**~** Annualized Cost Factor Replacement coo S,,_ol· ()p<ralkmllJldM"mu"mu:eL,u",r l.ilililie3 AmmomaCOS1 ElectricityCost Salnotol. Uti/It... TOTAL ANNUAL DIRECTCOSTS'
COSTCOMPONENT: TOTALANNlJAL OAMCOSTS Annualized COSl FacIOI' Equipmenl Life (years) "" futerest Rate (11;0) = Annualized Cost Factor CAPITAL RECOVERYCOSTS TOTAL CAPITAL REQUIREMENT TOTAL ANNlJAL CAPITAL REQUIREMENT TOTAL ANNlJALIZED COST (1'''''''_01O&M CQStIlJId/1JJ".0Iju;J cop/ttllcost) COST(S)**~** 23,581 10 2L83 025

4,735 OJ 4.735 28,316 COST(S)

2ll,J16 10 21.83 0,25 857,483 217,363 245,679

App A· RACT Cost Effectiveness 9-6-2013.xI5x Unit 865-11H2 LNB & SNCR 20 of66

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# " PES Refinery Heater Firing Rate Increase Plan Approval NOx RACT Control Cost Effectiveness Source Unit**86~IIH2** Control LNB& FGR Rated Heat Input 64.2 Nwnbel"

### or Rumen 8.0 Baseline Actual Emissions 31.78 CUrTen. Emission Ratt- 0.113 Control Efficiency 55°/. Healel" Capacity 67.7 BumerHeat Release Rate 10.8 Evaluated at New Firing Limit at 2012 Cost and Efficiencies MMBtulhr Bumen tpy Ib/MMBIu GJ/hr GJlhr Costs derived rrom AIt01lllliw Cortlrol Teclrniqlles /JocII",enJ. NOx Elftissions/ro'" Process Healers (Revised) - EPA-453/R-93-034 COST COMPONENT: COST (5) DIRECTCOSTS - LNB PurchasedEquipment COSIS Equipment Cost (EC) 189,917 Instrumentation (10% ofEC) 18,992 Sales taxes (5% ofEC) 9,496 Freight (8% ofEC) 15,193 Subtolal - PIIrclrased EqllipmenJ Costs (PEe) 233,598 Direct Installalion Costs (Based on Vendor Discussion) Foundations & support.<;; handling & erection; electrical; piping; etc. 0 Site Preparation / Buildings-Included above -- - 

### ---- Subtotal. Dinct lnSlaJlaJion Cmlt 0 TOTAL DIRECTCOSTS (FOC) - LNB 233,598 INDIRECTINSTALLATION COSTS - LNB Engineering Costs (5% ofPEe) 11,680 Construct & Field Expenses (Included in above costs) -- - Contractor Fees (10% ofPEC) 23,360 Start-up (I% ofPEC) 2.336 Perfonnance Test (1% ofPEe) 2,336 Contingency (3% ofPEe) 7,008 TOTAL INDIRECT COSTS.IC - LNB 46,720 DIRECTCOSTS - FGR Purchased EqUipment Costs Equipment Cost (Ee) 225,197 Instrumentation (Included in above costs) 

### -- - Sales taxes (Included in above costs) -- - Freight (Included in above costs) 

### -- - SIIblo/aJ - l'Mrc._dEquipmenJ Costs (PEC) 225,197 Direcllnstallation Costs (Based on VendorDiscussion) Foundations & support.<;; handling & erection; electrical; piping; etc. 0 Site Preparation I Buildings- Included above -- - 

### ---- Subtotal - DinctlnstllllaJio" Costs 0 TOTAL DIRECTCOSTS (FOC) - FGR 225,197 INDIRECTINSTALLATION COSTS - FGR Engineering Costs (Included in above costs) 

### -- - Construct & Field Expenses (Included in above costs) -- - Contractor Fees (Included in above costs) -- - Start-up (Included in above costs) -- - Perfonnance Test (Included in above costs) -- - Contingency (3% ofPEC) 6.756 TOTAL INDIRECT COSTS.IC - FGR 6,756 TOTAL CAPITAL INVESTMENT (TCI) - LNB 280,318 TOTAL CAPITAL INVESTMENT (TCI) - FGR 231,953 TOTAL CAPITAL INVESTMENT (TCI) 512,272

App A - RACT Cost Effectiveness 9-6-2013.xlsx Unit 865-11H2 LN8 & FGR 210166

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### I PES lIefine'Y**He~ter** Firing Rale IncR'ase Plan Approval NO. RACTContl1ll Cost Efrecd....... COST COMPONENT: ANNUAL DIRECTCOSTS Operation andMaintenance Labor Ma.inlenance Labor and Material (2.75% ofTel) AnnualizedCost Fac/or Replacement Life (years) = Interest Rate (%) = Annualized Cost Factor Replacement cost SlIblotiJl- o,wlflliOlt IUUiMlliltlmana Lllbor Ulilities Electricity Cost Sltblotol. UtUItW TOTAL AI'INUAL DIRECT COSTS'
COST COMPONENT; TOTAL ANNlJAL OdM COSTS Annualized Cost Fac/or Equipment Life (years) = Interesf Rate (0/.:.) .... Annualized Cost Factor CAPITAL RECOVERYCOSTS TOTAL CAPITAL REQUIREMENT TOTAL ANNIJAL CAPITAL REQUIREMENT TOTALANM.JALIZEDCOST IT- """,,01 O&Mant IIntl""IfJIoIl1.dCIIpiUIJ Ctnl) COST ($)**~** 14,087 10 21.83 0.25

8,163 8,163 22,250
COST ($) 22,250 10 21.83 0.25 512.272 129,856 152,106

App A - RAeT Cost Effect;vene.. 9-&-2013.><ls. Unit 865-11H2 LNB & FGR 22 of 66

# C



# c PES Refinery Heater Firing Rate Increase Plan Approval NOx RACT Control Cost Effectiveness Source Unit 865-11H2 Control SNCR Rated Heat Input 64.2**~1:\1Btu/hr** 

### Number ofBurners 8.0 Burners Baseline Actual Emissions l1.78 tpy CurrentEmission Rate O.lIl IblMMBtu Control Efficiency 40% Heater Capacity 67.7 GJ/hr BurnerHeat Release Rate 10.8 GJ/hr Evaluated at New Firing Limit at 2012 Cost and Efficiencies Costs derived from Alternative Control Techniques Document - NOx Emissions from Process Heaters (Revised) - 

### EPA-45llR-9l-034

DIRECTCOSTS 

### COST COMPONENT:
Purchased Equipment Costs

Equipment Cost (EC) Instrumentation (Included in above costs) Sales taxes (Included in above costs) Freight (Included in above costs) Subtotal- PurchasedEquipment Costs (PEC) Direcllnslallalion Costs (Based on Vendor Discussion) Foundations & supports; handling & erection; electrical; piping; etc. Site Preparation / Buildings- Included above Subtotal- Direct Installation Costs TOTAL DIRECT COSTS (TDC) INDIRECTINSTALLATION COSTS Engineering Costs (Included in above costs) Construct. & Field Expenses (Included in above costs) Contractor Fees (Included in above costs) Start-up (Included in above costs) Performance Test (Included in above costs) Contingency (3% ofPEC) TOTAL INDIRECTCOSTS, IC 

### TOTAL CAPITAL INVESTMENT (TCI)

App A - RACT Cost Effectiveness 9-6-2013.xlsx Unit 865-11H2 SNCR 

### COST ($)

560,355


### 560,355


## o



# --- o 560,355

16,811 

### 16,81I 577,165

23 

### of 66

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# , PES Refinery Heater Firing Rate Increase Plan Approval NOx RACT Control Cost Effectiveness COST COMPONENT: 

### ANNUAL DIRECT COSTS Operation andMaintenance Labor Maintenance Labor and Material (2.75% ofTCI) 

### Annualized Cost Factor Replacement Life (years) = Interest Rate (%) = Annualized Cost Factor Replacement cost 

### Subtotal- Operation andMaintenance Labor Utilities Ammonia Cost Electricity Cost 

### Subtotal- Utilities 

### TOTAL ANNUAL DIRECT COSTS·
COST COMPONENT: 

### TOTAL ANNUAL O&M COSTS Annualized Cost Factor Equipment Life (years) = Interest Rate (%) = Annualized Cost Factor 

### CAPITAL RECOVERYCOSTS TOTAL CAPITAL REQUIREMENT TOTAL ANNUAL CAPITAL REQUIREMENT TOTAL ANNUALIZED COST (Total annual O&M cost andannualized capital cost)

App A - RACT Cost Effectiveness 9-6-2013.xlsx Unit 865-11H2 SNCR COST ($)
15,872 15,872 10 21.83 0.25

4,735

0.3 4,735 20,607
COST ($)

20,607 10 21.83 0.25 577,165 146,306 166,913

24 of 66

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# ('
PES Refinery Heater Firing Rate Increase Plan Approval Unit 210-HI01 RACT Cost Effectiveness Summary A B 

### C Control Option Design Firing Current Potential Emissions 74.8 74.8 74.8 192 0.089 74.8

2 0.089 74.8 192 0.089 74.8 Calculation - A • B• 8760 / 2000 Technicallnfeasibilities: FGR would not physically fit 

### the plot space; therefore, it is infeasible. Notes: D 

### Control

(%) 96% 85% 

### 70% 66% 55% 

### 40% 

# ('

E 

### Maximum Post F 

### Potential

NO, 

### G H 

### 2012 Total 

### I 2012 O&M Cost Capital Cost

I 

### Current generation UNLB is considered to be0.03Ib/MMBtu, which represents a 66% reduction from 0.0891b/MMBtu. 2 See 

### "RACT Cost Summary" tab for details on the Annualized Cost Factor (ACF).

App A - RACT Cost Effectiveness 9-6-2013.xlsx 

### 210-HIOl RACT 

### 2012 Annualized Cost2 

### 2,213,176 1,742,936 470,240

NA 

# r

2012 Cost Effectiveness 30,796 27,397 57,667 9,477 

### NA 10,825 

### =l/F

25 of66

# J

J

JPES Refinery Heater Firing Rate Increase Plan Approval NO. RACT Co.trol Cost Err.div..... Source U.it 210-HIOI Co.trol ULNB&SCR Rated Heat I.put 192.0 Number ofBurners 6.0 Baseline Actual Emissions 74.85 Currenl Emission Rate 0.089 Control Efficiency 96% Heater Capacity 202.6 Burner Heal Rei".... Rate 40.4 Evaluated.! New Firing Limit.t 2012 Cost and Efficiencies MMBtulbr Burners Ipy IblMMBtu GJlbr GJlbr Costs derived fromAllaMlive Control Tee/flliques Document- NOx Emissions from ProcessHealers (R""iseJ) - EPA-4531R-93-0J4 COSTCOMPONE!'!T: COST ($) DfRECJCOSTS- ULNB PurchasedEquipment Cosls EqUIpment Cost (EG) 1.133,816 lnstrumenlation ( I0% ofEG) 113,382 Sales laxes (5% ofEe) 56,691 Freight (S% ofEG) 90,705 Sublolal- PllrcltaseJEqllipment Costs (PEe) 1,394.593 Direclinslaliafion**C()st.~** (Basedon Vendor Discussion) Foundanons &**supporu~** handling & erection; elecrrical; piping; etc, 0 Sile Preparation I Buildings-Included above --- S"hlolal- Direcl/1ISIaUalion Costs 0 TOTAL DIRECTCOSTS (rDC) - UUIB 1,394,593 INDIRECJfNSTALLATfON COSTS- UfNB Engineering CoslS (5% ofPEe) 69,730 Construcl. & Field Expenses (Included in above cosls) 

# --- Contractor Fees (10% ofPEC) 139,459 Slart-up (l%ofPEC) 13,946 Performance Te" (1% ofPEC) 13.946 Conlingency (3% o(PEe) 41.838 TOTAL fNDfRECT COSTS, IC - ULNB 278,919 DIRECTCOSTS- SCR PurchasedEqUipment Costs Equipmenl CoS! (EC) 5.767.459 Instrumentation (Included in above costs) Sales taxes (Included in above costs) 

### --- Freighl (Included in above costs) 

### --- S"blolal- P",chased EqllipmenJ Costs (PEC) 5.767,459 Direct Installation Costs Foundations & supports: handling & erection; electrical; piping; etc, 0 Sire Preparation l Buildings- Included above Sllhlolal- DireclInstallalion Costs 0 TOTAL DIRECTCOSTS (!DC) - SeR 5,767,459 !ND/RECJINSTALLATION COSTS - SeR Engineering Costs (Included in above costs) 

### --- Construct. & Field Expenses (Included in above costs) 

# - Contractor Fees (Included in above cOSts) 

### -- Slart-up (Included in above costs) - Performance Test {Included 10 above cOStS} 

### --- Contingency (3% o(PEC) 173,024 TOTAL fNDlRECJCOSTS, IC· SeR 173,024 TOTAL CAPITAL INVESTMENT (TCI) - llLNB 1,673,512 TOTAL CAPITAL INVESTMENT (TCI)- SCR 5,940.483 TOTAL CAPITAL INVESTMENT (TCI) 7,613,995

App A - RACT Cost Effectiveness 9-6-2013.•ls. Unit 210-H101 ULNB & SCR 26 of 66

# J

J



# JPES Refinery Heater Firing RateInerea...Plan Approval NO. RACT Control Cost Effectiveness COST COMPONENT: ANNUAL DIRECTCOSTS Operation andMaintenance lAbor Maintenance Labor and Material (2.75% ofTCIl Annualized Cost Faclor Replacement Life (years) 

### = IntereSl Rate (%) Annuahzed Cost Factor Replacement cosr Su.btotal - Operation DndMaintenancelAbor Utilities AnunoniaCost Catalyst Replacement Cost Electricity Cost Subtotal.. Utilities**IIJI~L** ANN IJAI , UlKM .. LUI> 1 1>' COSTCOMPONENT: TOTALANNUAL O&M COSTS AnnualizedCost Faelor Equipment Life (years) Interest Rare (%) = Annualized Cost Factor CAPITAL RECOVERYCOSTSTOTAL CAPITAL REQUIREMENT TOTAL ANNUAL CAPITAL REQu/REMEtvT TOTALANNUALlZEn COST (Totalan""a! (J&Mcostandannuali",dcapitalcost) 10 21.83

J() 21.83

App A .. RACT Cost Effectiveness 9-<i..2013.xlsx Unit 21()"H10l ULNB &SCR COST(S)

209.385 209,385

0.25

11,152 62,568

0.8 73,721 283,106 COST ($) 283,106

0.25 7,613,995 1,930,071 2,213,176

27 of66

# J



# J

J

# , PES 

### Refinery Heater Firing Rate Increase Plan Approval NOx RACT Control Cost Effectiveness Source Unit 210-HlO] Control SCR Rated Heat Input 192.0 Number ofBurners 6.0 Baseline Actual Emissions 74.85 Current Emission Rate 0.089 Control Efficiency 85% Heater Capacity 202.6 Burner Heat Release Rate 40.4 Evaluated at New Firing Limit at 2012 Cost and Efficiencies MMBtu/hr Burners tpy Ib/MMBtu GJ/hr GJ/hr 

### Costs derived from 

### Alternative Control Techniques Document- NOxEmissions/rom Process Heaters (Revised) - EPA-4531R-93-034

DIRECTCOSTS 

### COST COMPONENT:
PurchasedEquipment Costs



### Equipment Cost (EC) Instrumentation (Included in above costs) Sales taxes (Included in above costs) Freight (Included in above costs) 

### Subtotal- PurchasedEquipment Costs (PEC) Direct Installation Costs 

### Foundations 

### & supports; handling 

### & erection; electrical; piping; etc. Site Preparation I 

### Buildings- Included above 

### Subtotal - DirectInstallation Costs TOTAL DIRECTCOSTS (TDC) INDIRECTINSTALLATION COSTS 

### Engineering Costs (Included in above costs) Construct. 

### & Field Expenses (Included in above costs) Contractor Fees (Included in above costs) Start-up (Included in above costs) Performance Test (Included in above costs) Contingency (3% ofPEC) TOTAL INDIRECTCOSTS, IC 

## TOTAL CAPITAL INVESTMENT (TCn

App A RACT Cost Effectiveness 9-6-2013.xlsx Unit 210-H10l SCR 

### COST (5)
5,767,459
5,767,459


# o

--- o 5,767,459

173.024 173,024 5,940,483

28 

### of 66

# J

### PES Refinery HeaterFiring Rate Increase Plan Approval NOx RACT Control Cost Effectiveness COST COMPONENT: 

### ANNUAL DIRECTCOSTS Operation andMaintenance Labor Maintenance Labor and Material (2.75% ofTCI) 

### Annualized Cost Factor Replacement Life (years) 

### = Interest Rate (%) = 

### Annualized Cost Factor Replacement cost 

### Subtotal- Operation andMaintenanceLabor Utilities Ammonia Cost Catalyst Replacement Cost Electricity Cost 

### Subtotal- Utilities 

### TOTAL ANNUAL DIRECT 

## COSTS 8


### COST COMPONENT: 

### TOTAL ANNUAL O&M COSTS Annualized Cost Factor Equipment Life (years) Interest Rate (%) 

### = Annualized Cost Factor 

### CAPITAL RECOVERYCOSTS TOTAL CAPITAL REQUIREMENT TOTAL ANNUAL CAPITAL REQUIREMENT TOTAL ANNUALIZED COST (Total annual O&Mcost andannualized capital cost)



### App A - RACT Cost Effectiveness 

### 9-6-2013.l<lsl< Unit 

### 2l0-HlOl SCR COST ($)


### 163,363 ]63,363 

### to 21.83 0.25

11,152 62,568

0.8 73,721 237,084
COST ($) 

### 237,084 10 21.83 0.25 5,940,483 ],505,852 1,742.936



### 29 

### of 66

# J



# JPES Refinery H••

terFiring Rate mere...PlanAppro.a1 NO. RAeTControl Con EIf.di....... Sou..... Unit**Zl~HIOI** Control LNB&SNCR Rarod Hea,lnpu' )91.0 NlUllber GrBumers 6.0 Basetil'le Actual Emissions 74.85 Currenl Emission Rate 

## 0._ Control Errldency 70% Hea....C.p.<ily 202.6 BumerHeatRelease Rate 41).4 Evaluated •• New Firinc Umit 8r2012 CDSt anti**E.ffir~ncies** MMBhlfhr B........ .py IblMMBtu GJ/hr GJ/hr Cos'" deri.... rromAltmr<lti ... CO/IJrI)/ T ecbi'l""**Dtx:tt""~1** • NUx£",/$.""'"fro". _us H.III .... (R".,.4) • EPA-453IR·9J.034 COST COMPONENT: COST($l DIRECTCOSTS - L'JB PurchasedEquipment C05/$ Equipment CoS! (Eel 6.503.358 Instrumentation (100/0 ofEC) 650,336 Sales taxes (5% ofEe) 325.168 Freight (8% ofEC) 520.269 SabtOlal. PW",.a..ed£'1"lpmM1 CMls (PEC) 7.999.131 Direct Ins/allat/on Costs (Based on Vendor Discussion) Foundations &**suppons~** handhng & erection; electrical; piping; etc 0 Site Preparation;' Buildings-Included above --- 

# ---- S"blOfai- Dirrdlnstallalimt eMU 0 TOTAL DIRECTCOSTS (rOC)· LNB 7,999,13) INDIRECTINSTALLATION COSTS- LNB Engineering COSfS (5% ofPEe} 399.957 Construct & Field Expenses (Included in above costs) Contractor Fees (10% ofPEC) 799.913 Start-up (1% ofPEC) 79.991 Perfonnance Test (1%ofPEC) 79.991 Contingency (3% ofPEC} 239.974 TOTAL INDIRECT COSTS. IC - LNS 1,599,826 DIRECTCOSTS· SNCII PurchasedEquipment Cos's Equipment Cost (Ee) 1.08l.241 Instrumentarion (Included in above costs) 

### --- Sales taxes (Included in above costs) --- Freight (Included in above costs) 

### --- S..

610141-**PNrc~.4**£'1"1_,,, Costs (PEC) ),(l8),l41 Direct Installation Costs (Basedon VendorDiscussion) Foundations & supports; handljng & erection: electrical: pipmg; Cle. 0 Slfe Preparation J**Buildtngs~** lncluded above 

# --0-- S..

btotal- Dinct Ilf.fIallllllwn Com TOTAL DIRECTCOSTS (TOC) - SIVCR 1,IJII1.24 I INDIRECTINSTALLATION COSTS - SNCR EngineeringCosts(Induded in above costs) Construct & Field Expenses (Included in above COSts) 

### _. Contractorfees (lncluded in above costs) 

### ---**Start~up** {Included in above costs) Perfonnance Tess (Included in above COStS; i Contingency (3% ofPEC) 32.437 TOTAL INDIRECT COSTS. IC - SNCR 32.437 ITOTAL CAPITAL INVESTMENT (TCl)· DID 9.598.957 TOTAL C,-\PITAL INVESTMENT (TCI) - SNCR t,1I3.678 TOTAL CAPITAL INYESTMENT (TCI) 10.712,635

App A - RACT eost Effectiveness 9-6-2013.xl•• Unit 21D-H10l LNB & SNCR 

### I

30 of 66

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# , PES Refinery Heater Firing Rate Increase Plan Approval N(h RACT Control Cost Effectiveness COST COMPONENT: ANNUAL DIRECTCOSTS Operatian andMaintenance Labar Maintenance Labor and Material (2.75% ofTCI) AnnualizedCast Factor Replacement Life (years) = Interest Rate (%) = Annualized Cost Factor Replacement cost S"blotaJ - Operation andMaintenanceLabor Ulililies Ammonia Cost Electricity Cost S"blolaJ- Utilities TOTAL ANNUAL DIRECT COSTS'
COST COMPONENT: TOTALANNUAL O.lMCOSTS Annualized emilFactor Equipment Life (yean,) = Interest Rate (%) = Annualized Cost Factor CAPITAL RECOVERYCOSTS TOTAL CA PITAL REQUIREMENT TOTAL ANNUAL CAPITAL REQUIREMENT TOTAL ANNUALIZED COST (Total tulnllaJ OdMcost adannlla/iz,edcapitalcon) COST(S)

294,597 294,597 10 21.83 0.25

11,152 0.8 11,153 305,750 COST(S) 305,750 10 21.83 0.25 10,712,635 2,715,545 3,021,296

App A - RACT Cost Effectiveness 9-6-2013.xlsx Unit 21()-H101 LNB & SNCR 310166

# J

J

J

# , PES Refinery HeaterFiringRate Increase Plan Approval NOx RACT Control Cost Effectiveness Source llnit 210-HI01 Control llLNB Rated Heat Input 192.0 Number ofBurners 6.0 Baseline Actual Emissions 74.85 Current Emission Rate 0.089 Control Efficieney 66% Heater Capacity 202.6 Burner Heat Release Rate 40.4 Evaluated at New Firing Limit at 2012 Cost and Effieiencies MMBtulhr Burners tpy IblMMBtu GJlhr GJlhr Costs derived from 

### Alternative Control Techniques Document - NOx Emissions/romProcess Heaters (Revised) - EPA-453/R-93-034

DIRECTCOSTS COST COMPONENT:


### PurchasedEquipment Costs

Equipment Cost (EC) Instrumentation (10% ofEC) Sales taxes (5% ofEC) Freight (8% ofEC) 

### Subtotal- PurchasedEquipment Costs (PEC) Direct Installation Costs (Based on Vendor Discussion) Foundations & supports; handling & erection; electrical; piping; etc. Site Preparation I Buildings- Included above 

### Subtotal- DirectInstallation Costs TOTAL DIRECTCOSTS (TDC) INDIRECTINSTALLA TION COSTS Engineering Costs (5% ofPEC) Construct. & Field Expenses (Included in above costs) Contractor Fees (10% ofPEC) Start-up (1% ofPEC) Performance Test (I% ofPEC) Contingency (3% ofPEC) TOTAL INDIRECT COSTS, IC 

## TOTAL CAPITAL INVESTMENT (TCI)

App A RACT Cost Effectiveness 9-6-2013.xlsx Unit 210-HIOl UlNB COST ($)

1,133,816 

### 113,382 56,691 90,705 1,.394.593


# o o 1,.394.593

69,730 139,459 13,946 13,946 

### 41.838 278.919 1,673.512



### 32 of 

### 66

# J

J

J

# (, PES Refinery HeaterFiring Rate Increase Plan Approval NOx RACT Control Cost Effectiveness COST COMPONENT: ANNUAL DIRECTCOSTS Operation andMaintenance Labor Maintenance Labor and Material (2.75% ofTCI) AnnualizedCost Factor Replacement Life (years) 

### = Interest Rate (%) 

### = Annualized Cost Factor Replacement cost Subtotal - Operation andMaintenance Labor Utilities None Subtotal- Utilities 

## TOTAL ANNUAL DIRECT COSTS·
COST COMPONENT: TOTALANNUAL O&M COSTS AnnualizedCost Factor Equipment Life (years) 

### = Interest Rate (%) 

### = Annualized Cost Factor CAPITAL RECOVERY COSTS TOTAL CAPITAL REQUlREM/:"'NT TOTALANNUAL CAPITAL REQUIREMENT TOTALANNUALIZED COST (Totalannual O&M costandannualized capital cost)

App A - RACT Cost Effectiveness 9-6-2013.xlsx Unit 2lD-HlDl ULNB 

### COST ($)


### 46,022 46,022 10 21.83 0.25

0.0 46,022
COST ($)



### 46,022 10 21.83 0.25 1,673,512 424,218 470,240



### 33 of 66

# , PES Refinery HeaterFiring Rate Increase Plan Approval NOx RACT Control Cost Effectiveness Source Unit 210-HI01 Control SNCR Rated Heat Input 192.0 Number ofBurners 6.0 Baseline Actual Emissions 74.85 Current Emission Rate 0.089 Control Efficiency 40% HeaterCapacity 202.6 Burner Heat Release Rate 40.4 Evaluated at New Firing Limit at 2012 Cost and Efficiencies MMBtu/br Burners tpy Ib/MMBtu GJ/br GJ/br Costs derived from AlternaiWe Control Techniques Document- NOxEmissions from**Proces,~** 

### Heaters (Revised) - 

### EPA-4531R-9J-034

DIRECT COSTS 

### COST COMPONENT:
PurchasedEquipment Costs

Equipment Cost (EC) Instrumentation (Included in above costs) Sales taxes (Included in above costs) Freight (Included in above costs) 

### Subtotal- PurchasedEquipment Costs (PEC) Direct Installation Costs (Basedon Vendor Discussion) Foundations 

### & supports; handling 

### & erection; electrical; piping; etc. Site Preparation I Buildings- Included above 

### Subtotal- Direct Instalifltion Costs TOTAL DIRECT COSTS (TDC) INDIRECTINSTALLATION COSTS Engineering Costs (Included in above costs) Construct. & Field Expenses (Included in above costs) Contractor Fees (Included in above costs) Start-up (Included in above costs) Performance Test (Included in above costs) Contingency (3% ofPEC) TOTAL INDIRECT COSTS. IC 

## TOTAL CAPITAL INVESTMENT (TCI)

App A - RACT Cost Effectiveness 9-6-2013.xlsx Unit 21O-Hl0l SNCR 

### COST ($)

1,081,241


### 1,081,241


## o



# --- 

# o 1,081,241

32,437 

### 32,437 1,113,678

34 

### of 66PES 

### Refinery Heater Firing Rate Increase Plan 

### Approval NOx RACT Control Cost Effectiveness COST COMPONENT: 

### ANNUAL DIRECT COSTS Operation andMaintenance Labor Maintenance Labor and Material (2.75% ofTCI) 

### Annualized Cost Factor Replacement Life (years) = Interest Rate (%) = Annualized Cost Factor Replacement cost 

### Subtotal- Operation andMaintenance Labor Utilities Ammonia Cost Electricity Cost 

### Subtotal - Utilities 

### TOTAL ANNUAL DIRECT COSTS·
COST COMPONENT: 

### TOTAL ANNUAL O&M COSTS Annualized Cost Factor Equipment Life (years) = Interest Rate (%) = Annualized Cost Factor 

### CAPITAL RECOVERYCOSTS TOTAL CAPITAL REQUIREMENT TOTAL ANNUAL CAPITAL REQUIREMENT TOTAL ANNUALIZED COST (Total annual O&M cost andannualized capital cost)

App A - RACT Cost Effectiveness 9-6-2013.xlsx Unit 21O-HlOl SNCR COST ($)
30,626 30,626 10 21.83 0.25

11,152

0.8 11,153 41,779
COST ($)

41,779 

### JO 21.83 0.25 1,113,678 282,306 324,085

35 

### of 66

# r' 

# f' f'
PES Refinery Heater Firing Rate 

### Increase Plan Approval Unit 210·H201 

### RACT Cost Effectiveness Summary A 

### fl C D E 

### F G H 

### Current Maximum Post Potential ControlOption Design Firing Potential Emissions Control Efficiency Control Emissions NO. 2012 Total 12012 Annualized 

# I 2012 Cost Capital Cost 2012 O&M Cost . ($) 

### Cost2 

### Effecliveness ULNB&SCR SCR LNfl& SNCR LNB&FGR SNCR ULNB Technicallnfeasibilities: 2000 70% 55% 40% 0% @ 

### Design Firing TPY) 1.3 5.0 10.0 15.0 20.0 33.4 C· (1. 

### D) Reduced (TPY) ($) 

### 32.0 NA NA 28.4 NA NA 23.4 13A74,367 

### 375,519 18.4 NA NA 13.4 1,317,284 41,199 0.0 NA NA =C- E SCR would not physically fit the plot space and there is not adequate pressure to overcome the SCR pressure drop; therefore, SCR is infeasible. FGR installation would require the installation of mechanical draft burners, which is a major re-design of the unit; therefore FGR is infeasible. Notes: 1 

### ULNB is already installed on the Unit 210-H201 heater. 2 

### See "RACT Cost Summary" tabfor details on the Annualized Cost Factor (ACF).

App A - RACT Cost Effectiveness 9-6-2013.l<lsl< 210-H201 RACT ($) 

# 1 375,117 

# 1 28,098 

## I NA 

## I NA 

## I = (G • ACF) + 

### H 

## I - I / F

36 of 66PES Refinery Heater Firing Rate Increase Plan Approval NOJ. RAcr Control Cost ER'ettiveness Source Unit 2111-8201 Control LNB& SNCR Rated Heat Input 254.0 Nwnber ofBumen 8.0 Baseline Actual Emissions 33.38 CUInn! Emission Rate 0.030 Control Efficiency 70°/. Heater Capacity 268.0 Bumer Heat Release Rate 39.8 Evaluated lit New Firing Limit at 2012 Cost and Efficiencies MMBlUlhr Bumers tpy Ib/MMBIu GJIhr GJ/hr COSh derived from Allernlllive ColllroJ Tecltniques Docllmellt.NOx Emissiollsft'o", Process Hetllers (Revised) - EPA-453fR-93-034 COST COMPONENT: COST(S) DIRECT COSTS· LNB PurchasedEquipment Costs Equipment Cost (Ee) 8.236.506 Instrumentation (10% ofEC) 823,651 Sales taxes (5% ofEC) 411,825 Freight (8% ofEC) 658,920 Subtotal- PurchasedEquipment CosJs (PEe) 10,130,902 Direct Inslal/alian Costs (Basedon Vendor**D;~'cuss;on)** Foundations & supports; handling & erection; electrical; piping; etc. 

# ° Site Preparation I Buildings-Included above ... Subtotal- DinctI"stal/OIio" Costs 0 TOTAL DIRECT COSTS (TDC) . LNB 10,130,902 INDIRECTINSTALLATION COSTS· LNB Engineering Costs (5% ofPEC) 506.545 Construct. & Field Expenses (Included in above costs) ... Contractor Fees (10% ofPEC) 1,013.090 Start·up (1% ofPEC) 101.309 Performance Test (I% ofPEC) 101.309 Contingency (3% ofPEC) 303.927 TOTAL INDIRECT COSTS, IC· LNB 2,026,180 DIRECTCOSTS· SNCR PurchasedEquipment Costs Equipment Cost (EC) 1.278.916 Instrumentation (Included in above costs) ... Sales taxes (Included in above costs) ... Freight (Included in above costs) ... S"btotal - Purchased Eq"ipmelll Costs (PEC) 1,278,916 Direct Installation Costs (Basedon Vendor Discussion) Foundations & supports; handling & erection: electrical; piping; etc. 

# ° Sitc Preparation I**Buildings~** Included above ... S"btotaI- Direct/"sJa//atio" Costs 0 TOTAL DIRECT COSTS (TDC)· SNCR 1,278,916 INDIRECTINSTALLATION COSTS· SNCR Engineering Costs (Included in abovc costs) ... Construct. & Field Expenses (Included in above costs) ... Contractor Fees (Included in above costs) ... Start-up (Included in above costs) ... Performance Test (Included in above costs) ... Contingency (3% ofPEC) 38,367 TOTAL INDIRECT COSTS, IC· SNCR 38.367 TOTAL CAPITAL INVESTMENT (TCI) - LNB 12,157,os3 TOTAL CAPITAL INVESTMENT (TCI) - SNCR 1,317,284 TOTAL CAPITAL INVESTMENT (TCI) 13,474.367

App A - RACT Cost Effectiveness 9-6-2013.xlsx Unit 21()-H201 LNB & SNCR 370166

# ,

, PES Refiru>ry Healer Firing Ral.lncrease Plan Approval NO. RACf COII'rol C••, Elfecli....... COST COMPONENT: ANNUAL DIRECTCOSrs Operation andMaintenance Labor MainlenatlCe Labor and Matenld (2,75 1 %ofTel) AnnualizedCostFactor Replacement lIfe {years)"'- IntereSi Rate (%)= Annualized Cost Factor Replacement cos! s..btotl1l- (}p<!NliOll4fldMsinI_c< LIlJwr Uiilii.ies Ammonia Cost Electriclty Cost 5Mbtoll1l- UlilitiD IRECT COSTS"

COST COMPONENT: ;a OdMCOSTS Annualized COSI FaclOr Equipmenl Life (years) "'" }nterest Rate (%) "'" Annualized Cost factor CAPITAL RECOVERYCOSTS TOTAL CAPITAL REQUIREMENT TOTAL ANNUAL CAPITAL REQUIREMElVT TOTALANNUALIZED COST (1'01'"""'".'" OdMwst IUId "" ....I1I;:<tlcopitl1lcos/) COST/5)

370.545 370,545 10 21.83 0.25

4,973 0.4 4,973 375,519 COST/5) 375,519 10 21.83 0.25 13,474.367 3,415.616 3,791,135

AppA . RACT Cost Effectiveness 9-6-2013.xl .. Unit 21Q-H201 LNB & SNCR 380166

### PES Refinery HeaterFiring Rate Increase Plan Approval NOx RACT Control Cost Effectiveness Source Unit 210-H201 Control SNCR Rated Heat Input 254.0 Number ofBurners 8.0 Baseline Actual Emissions 33.38 Current Emission Rate 0.030 Control Efficiency 40% Heater Capacity 268.0 Burner Heat Release Rate 39.8 Evaluated at New Firing Limit at 2012 Cost and Efficiencies MMBtu/hr Burners tpy IblMMBtu GJ/hr GJ/hr Costs derived from 

### Alternative Control Techniques Document - NOx Emissions/rom Process Heaters (Revised) - EPA-453/R-93-034

DIRECT COSTS COST COMPONENT:
PurchasedEquipment Costs

Equipment Cost (EC) Instrumentation (Included in above costs) Sales taxes (Included in above costs) Freight (Included in above costs) 

### Subtotal- PurchasedEquipment Costs (PEC) Direct Installation Costs (Based on Vendor Discussion) Foundations & supports; handling & erection; electrical; piping; etc. Site Preparation / Buildings- Included above 

### Subtotal- DirectInstallation Costs TOTAL DIRECT COSTS (TDC) INDIRECTINSTALLATION COSTS Engineering Costs (Included in above costs) Construct. & Field Expenses (Included in above costs) Contractor Fees (Included in above costs) Start-up (Included in above costs) Performance Test (Included in above costs) Contingency (3% ofPEC) TOTAL INDIRECT COSTS, IC 

### TOTAL CAPITAL INVESTMENT (TCI)

App A - RACT Cost Effectiveness 9-6-2013.xlsx Unit 21O-H201 SNCR COST ($)

1,278,916

1.278.916


## o 

# o

. 1.278,916

38,367 38.367 1,317.284

39 

### of 66

# , " PES Refinery HeaterFiring Rate Increase Plan Approval NOx RACT Control Cost Effectiveness COST COMPONENT: 

### ANNUAL DIRECTCOSTS Operation andMaintenance Labor Maintenance Labor and Material (2.75% ofTCI) 

### Annualized Cost Factor Replacement Life (years) Interest Rate (%) = Annualized Cost Factor Replacement cost 

### Subtotal - Operation andMaintenance Labor Utilities Ammonia Cost Electricity Cost 

### Subtotal- Utilities 

## TOTAL ANNUAL DIRECT COSTS 8

COST COMPONENT: 

### TOTAL ANNUAL O&M COSTS Annualized Cost Factor Equipment Life (years) Interest Rate (%) Annualized Cost Factor 

### CAPITAL RECOVERYCOSTS TOTAL CAPITAL REQUIREMENT TOTAL ANNUAL CAPITAL REQUIREMENT TOTAL ANNUALIZED COST (Total annualO&M cost andannualizedcapital cost)



### App A - RACT Cost Effectiveness 9-6-2013.xlsx Unit 210-H201 SNCR COST ($)
36,225 36,225 10 21.83 0.25

4,973

0.4 4,973 41,199
COST ($)

41,199 10 21.83 0.25 1,317,284 333,918 375,117



### 40 of 66

# f:' 

# f'
PES Refinery Heater Firing Rate Increase Plan Approval Unit 866-12Hl RACT Cost Effectiveness Summary A B 

### C D E F 

### G H Current Control Maximum Post Potential 2012Total Control Option Design Firing Emission Rate Potential Emissions Efficiency Control Emissions @ NO, Capital Cost 2012 O&M Cost (MMBtu/hr) (lb/MMBtu)t (TPY) (%) Design Firing Reduced ($) ($) (TPY) (TPY) ULNB&SCR 61.2 0.113 30.3 %% 1.2 29.1 3,518,199 121,208 SCR 61.2 0.113 30.3 85% 4.5 25.7 2,984,767 106,538 ULNB 61.2 0.113 30.3 73% 8.0 22.2 533,432 14,669 LNB&SNCR 61.2 0.113 30.3 70% 9.1 21.2 838,966 27,585 LNB& FGR 61.2 0.113 30.3 55% 13.6 16.7 503,525 21,628 SNCR 61.2 0.113 30.3 40% 18.2 12.1 560,828 19,936 Calculation = A • B

### * 876()L 2000 = C' (1- D) =C-E Notes: t Unit 866-12111 is projected to be above PADEPpresumptive RACT firing limits and assumed NO, emission rate limit of 0.113 Ib/MMBtu is used. 2See "RACT Cost Summary" tab for details on the Annualized Cost Factor (ACF).

App A- RACT Cost Effectiveness 9-6-2013.l<lsl< 866-12Hl RACT 

# f'

2012 Annualized 2012 Cost Cost2 Effectiveness

($) ($1Ton) 1,013,036 34,831 863,147 33,524 149,889 6,737 240,255 11,331 149,267 8,960 162,101 13,379 = 

### rG* ACF) + H = 

### II F

41 of 66PES Refinery Heater Firing Rate Increase Plan Approval NO. RACf Conlrol C""I Effectiveness Source Unit 866-12HI Control ULNB&SCR Rated Heat Inppt 61.2 Number ofBurners 6.0 Baseline Actual Emissions 30.29 Current Emission Rate 0.113 Control Efficiency**96~~** H.ater Capacity 64.6 Burner Heat Rei.... Rate 13.8 Evaluated at New Firing Limit at 2012 Cost and Efficiencies MMBlulhr Burnen tpy IblMMBtp GJlhr GJlbr Cosl, derived fmmAllunal/ve COIIlroi Techlfiqll(!s Docllmelfl- NOx Emissionsfrom Process Healers (R... -iseli) EPA-4531R·93-1134 COSTCOMPONENT: COST(S) DIRECTCOSTS· ULNB PurchasedEquipment Costs Equipment COSt (Ee) 361.404 instrumentation (10% ofEC) 36,140 Sales taxes (5% ofEC) 18,070 Freight (8% ofEC) 28,912 SubtOlal·PurchasedEquipmenJ Costs (PEq 444,527 Direct Installation CoSls (Based on Vendor Discussion) Foundations & supports; handling &**erec-tion~** electrical; piping; ere, 0 Site Preparation I Buildings-Included above 

### --- SuDtOlal· Direcl {""aI/ali_ Costs 0 TOTAL DIRECTCOSTS (TDC) - ULNB 444,527 INDIRECTINSTALUTJON COSTS - ULNB Engineering Costs (5% ofPEC) 22,226 Construct. & Field Expenses (included in above costs) 

### --- Contractor Fees (10%ofPEC) 44,453 Start-up (I%ofPEC) 4,445 Performance Test (1% ofPEC) 4,445 Contmgency (3%ofPEC) 13,336 TOT AI. INDIRECTCOSTS, IC- ULNS 88,905 DIRECTCOSTS- SCR PurchasedEquipment Costs Equipmem Cost (EC) 2,897,832 Instrumentation (Included in above costs) --- Sales taxes (Included in above costs) 

### --- Freight (Included in above costs) 

### -.- SIlDtOlal· PurchasedEquipmenJ Costs (PEq 2,897,832 DirectlnSJallaf;on Costs Foundations & suppons: handling &**erection~** electrical; piping; etc. 0 Site Preparation I**Bui1dings~** Included above .. Subtotal- Direct {_al'alion Costs 0 TOTAL DIRECTCOSTS (TDC) - SCR 2,897,832 INDIRECTINSTALL4TlON COSTS - SCR Engineering Costs (Included in above costs) Construct. & Field Expenses (Induded in above costs) ContraCtor Fees (Included in above costs) Start-up (Included in above costs) Performance Test (Included tn above costs) 

### --- Contingency (3% ofPEC) 86,935 TOTAL INDIRECT COSTS, IC- SCR 86,935 TOTAL CAPITAL INVESTMENT (TCI). ULNB 533,432 TOTAL CAPITAL L,,"VESTMENT (TCI) - SCR 2,984,767 TOTAL CAPITAL INVESTMENT (TCI) 3.518,199

App A - RACT (ost Effectiveness 9-6-2013.xlsx Unit 866-12Hl ULNB & S(R 42 of 66PES Refinery Heater Firing Rat(' IlK1'I!aS<' Plan Approval NO. RACf Conlrol Cos, EfTectiveness COST COMPONENT: ANNUAL DIRECTCOSTS Operation andMaintenance Labor Maintenance Labor and Material (2.75% ofTen AnnualizedCost FaClOr Replacement Life (years)**~** Interest Rate (%)

### = Annualized Cost Factor Replacement cost Slibiotal- Operlllion andMaintenanceLa"or Utilities AmmomaCost Catalyst Replacement Cost Electricity Cost Sub/oIlll. Ulilities I U I AL ."""'IUAL IJUUA.I LU:>I:> COST COMPONENT: TOTAL ANNUAL O&MCaSTS A.nnualizedCost Factar Equipment Life (years)**~** Interest Rate (%) Annualized Cost Factor CAPITAL RECOVERYCOSTSTOTAL CAPITAL REQUIREMENT TOTAL ANNUAL CAPITAL REQUIREMENT TOTAL ANNUALIZED COST (T

oI4ianlUlai (J&Mcostandanm,aii:edcapillllcost) JO 21.83

10 21.83

App A - RACT Cost Effectiveness 9-6-2013.xlsx Unit 866-12Hl ULNB & SCR COST(S)
96,750 96,750

0.25

4.513 19,943 0.3 24,457 121,208 COST(S) 121,208

0.25 3.518.199 891,828 1,013,036

43 of 66

### PES Refinery Heater Firing Rate Increase Plan Approval NOx RACT Control Cost Effectiveness Source {]nit 866-12HI Control SCR Rated Heat Input 61.2 Number orBurners 6.0 Baseline Actual Emissions 30.29 Current Emission Rate 0.113 Control Efficiency 85% Heater Capacity 64.6 Burner Heat Release Rate 13.8 Evaluated at New Firing Limit at 2012 Cost and Efficiencies MMBtulbr Burners tpy IblMMBtu GJlbr G.I/br Costs derived rrom 

### Alternative Control Techniques Document- NOx Emissions from Process Heaters (Revised) - EPA-453/R-93-034

DlRECTCOSTS COST COMPONENT:
PurchasedEquipment Costs

Equipment Cost (EC) Instrumentation (Included in above costs) Sales taxes (Included in above costs) Freight (Included in above costs) 

### Subtotal- PurchasedEquipment Costs (PEC) Direct installation Costs Foundations & supports; handling & erection; electrical; piping; etc. Site Preparation f Buildings- Included above 

### Subtotal - Direct Installation Costs TOTAL DIRECTCOSTS (TDC) INDIRECTINSTALLATION COSTS Engineering Costs (Included in above costs) Construct. & Field Expenses (Included in above costs) Contractor Fees (Included in above costs) Start-up (Included in above costs) Performance Test (Included in above costs) Contingency (3% ofPEC) TOTALlNDIRECT COSTS. iC 

## TOTAL CAPITAL INVESTMENT (TCI)

App A RACT Cost Effectiveness 9-6-2013.xlsx Unit 866-12Hl SCR COST ($)


### 2,897,832

2,897,832


# o o 2.897,832



### 86,935 86.935 2.984.767

44 

### of 66

### PES Refinery Heater Firing Rate Increase Plan Approval NOx RACf Control Cost Effectiveness COST COMPONENT: 

### ANNUAL DIRECTCOSTS Operation andMaintenance Labor Maintenance Labor and Material (2.75% ofTCI) 

### AnnualizedCost Factor Annualized Cost Factor Replacement cost 

### Subtotal- Operation andMaintenance Labor Utilities Ammonia Cost Catalyst Replacement Cost Electricity Cost 

### Subtotal - Utilities 

### AL DIRECT 

### COSTS·
COST**COMPO~ENT:** 

### TOTAL ANNUAL O&M COSTS Annualized Cost Factor Annualized Cost Factor 

### CAPITAL RECOVERYCOSTS Replacement Life (years) Interest Rate (%)



### Equipment Life (years) Interest Rate (%)


### TOTAL CAPITAL REQUIREMENT TOTAL ANNUAL CAPITAL REQUIREMENT TOTALANNUALIZED COST (Total annual O&M cost andannualized capital cost)

App A RACT Cost Effectiveness 9-6-2013.xlsx Unit 866-12Hl SCR 

### 1 21.83

10 21.83 COST ($)


### 82,081 82,081
0.25

4,513 19,943

0.3 24,457 ]06,538
COST ($)



### 106,538

0.25 2,984,767 756,608 863,147

45 

### of 66

# " " PES Refinery Heater Firing Rate Increase Plan Approval NOx RACT Control Cost Effectiveness Source Unit 866-12Hl Control ULNB Rated Heat Input 61.2 Number ofBurners 6.0 Baseline Actual Emissions 30.29 Current Emission Rate 0.113 Control Efficiency 73% Heater Capacity 64.6 Burner Heat Release Rate 

### 13.8 Evaluated at New Firing Limit at 2012 Cost and Efficiencies MMBtulhr Burners tpy IblMMBtu GJ/hr GJ/hr Costs derived from 

### Alternative Control Techniques Document- NOxEmissions from ProcessHeaters (Revised) - EPA4531R-93-034

DIRECT COSTS COST COMPONENT:
PurchasedEquipment Costs

Equipment Cost CEC) Instrumentation (10% ofEC) Sales taxes (5% ofEC) Freight (8% ofEC) 

### Subtotal- PurchasedEquipment Costs (PEC) Direct Installalion Costs (Basedon Vendor Discussion) Foundations & supports; handling & erection; electrical; piping; etc. Site Preparation! Buildings- Included above 

### Subtotal- DiredInstallation Costs TOTAL DIRECTCOSTS (TDC) INDIRECTINSTALLATION COSTS Engineering Costs (5% ofPEe) Construct. & Field Expenses (Included in above costs) Contractor Fees (10% ofPEC) Start-up (I% ofPEC) Performance Test (I % ofPEe) Contingency (3% ofPEe) TOTAL iNDiRECTCOSTS, iC 

## TOTAL CAPITAL INVESTMENT (TCI)

App A - RACT Cost Effectiveness 9-6-2013,xlsx Unit 866-12Hl ULNB COST(S)

361.404 36,140 18,070 28,912 444,527


# o o 444,527 22,226 44,453 4,445 4,445 13,336 88,905 533,432

46 of 66

# , PES Refinery Heater Firing Rate 

### Increase PIan Approval NOx RACT Control Cost Effectiveness COST COMPONENT: 

### ANNUAL DIRECTCOSTS Operation andMaintenance Labor Maintenance Labor and Material (2.75% ofTC1) 

### Annualized Cost Factor Replacement Life (years) = Interest Rate (%) = Annualized Cost Factor Replacement cost 

### Subtotal- Operation andMaintenance Labor Utilities None 

### Subtotal - Utilities 

## TOTAL ANNUAL DIRECT COSTS·
COST COMPONENT: 

### TOTALANNUAL O&MCOSTS Annualized Cost Factor Equipment Life (years) 

### = Interest Rate (%) 

### = Annualized Cost Factor 

### CAPITAL RECOVERYCOSTS TOTAL CAPITAL REQUIREMENT TOTALANNUAL CAPITAL REQUIREMENT TOTALANNUALIZED COST (Totalannual O&Mcost andannualizedcapitalcost)

App A - RACT Cost Effectiveness 9-6-2013.xlsx Unit 866-12Hl ULNB COST ($)
14.669 14,669 10 21.83 0.25

0.0 ]4,669
COST ($)

14,669 10 21.83 0.25 533,432 135,220 149,889

47of66

# ,

, I'FS Refinery HeaterFjring Rate Increase Plan Approval NO> RACT C.ntrol Cos, Eft'ftd••...., SoIDU lInit 866-1201 Control LNB & SNCR Rat... Hea' Input 6).2 NumberofBumers 6.0 Baseli..Actual Emi....... 30.29 Current Emission**Ra~** 0.113 Control Effictel'KY 70%, Heater Capacity 64.6 BurnerHea.**Re&e~** Rate 13.8 Evalual'" at New Firillll Limit at 2011 Co....... Efficiencies MMBtvJhr Bumen tpy IblMMBtu GJIbr GJIbr Co,,,, ...ri.... fromAll.",";"" CnnJrt>l Tdlflq ...Doc.m.", • NO.EmissWi<. fr- I'rocw;H.lllers (R_.d) • EPA-453/R·93-034 COST COMPONENT; COST(S) DIRECTCOSTS· LNB PurchasedEquipment Casts Equipment Cost (Ee) 188.440 Instrumentation (10% ofEC) 18.844 Sales rllXcs(5% ofEC) 9,422 Freight (8% ofEC) 15,075 Stlbt,lIuJ • P,m:Aase4EqKipllU:nJ Costs (PEe; 231,78) Direct InstaJlation Cos/s (Basedon VendorDiscussion) Foundations & supports; handling & erection; electrical;**piping~** etc. 0 Site Preparation! Bui1dings-lncluded above ... 

### ---- SllbtoluJ· Dir<Ct IlfstuJladtm 

### em.. 0 TOTAL DIRECTCOSTS rmC) . LN8 231,781 INDIRECTINSTALLATION COSTS· LNB EngineeringCosts (S% ofPEC) 11.589 Construct. & Field Expenses (Included in aoove costs) ... ContracTorfees (I!l"/' ofPEC) 23.178 Start-up (l%ofPEC) 2.318 Performance Test (J% ofPEC) 2)18 Contingency (3% ofPEC) 6.953 TOTAL INDIRECT COSTS, IC·LNB 46,3lI6 DIRECTCOSTS· SNCR PurchasedEquipmenl Costs Equipment Cost (ECl 544,494 Instrumentation (Included in abovc costs) 

### ... Sales taxes (Included in above costs) ... Freight (Included in above eosts) --- S.DtoIuJ. PrucAfJ!J<tiEqMip""'lft COIls (PEC) 544.494 DiN!CI/nslal/alion CaSiS (Based on Vendor Dis('lw.ion) Foundations & supports; handlmg & erection; electrical; piping; etc, 0 Site Preparation JBuildings- lncluded above ... Sflbtola/**~** Di,eCl InSlfllllllion CoSB --0-- TOTAL DIRECTCOSTS (TDC) . SNCR 544,494 INDIRECTINSTALLATION COSTS· SNCR Engineering Costs (Included in above costs) Construct & Field Expenses (Included tn above costs) ContractorFees (Included in above costs) 

### _. Stan-up (Included in above costs) Penonnancc Test (Included in above costs) ... Contingency (3% ofPEC) 16.335 TOTAL INDIRECTCOSTS. IC - SNCR 16,335 TOTAL CAPITAL INVESTMENT (TCI) - LNB 278,137 TOTAL CAPITAL INVESTMENT (TCI) - SNCR 560.828 iTOTAL CAPITAL INVESTMENT (TCI) 838,966

App A· RACT Cost Effectiveness 9·6-2013.•ls. Unit 866-12Hl LNB II< 5NCR 48 0166

# , PES Refin.ry H••

terFiring RalelncreasePlanApproval NO. RACTControlCOlI' Elle<ti...... COST COMPONE"', ANNUAL DIRECTCOSTS Opera/ionandMaintenance Labor Mamtenance Labor and Material (2.75%1 ofTeT) Annualized COSI Factor Replacement Life (years)**~** Interest Rate (%) "'" Annualized Cost Faelor Replacement cost SlI.blatsJ- OperatiOlf IUUIMtlbUelJanu Labor Utilities AmmoniaCoSl Electricity Cost 8u_lIl. UIi/i1in TOTAL ANNUAL DIRECT COSTS'
COSTCOMPONENT, TOTALANNUAL 0&111 CUSTS Annualized COSIFacioI' Equipment Life (years) = Interest Rate (%) = Annualized Cost Factor CAP/TAL RECOI'ERYCOSTS TOT.4L CAPITAL REQUIREMENT TOTAL ANNUAL CAPITAL REQUIREMENT TOTALA1VNUALIZEJ) C08T (TO/Ill_ul 0&111 oost#1"/lUI""lIli;,ed C/I{JItal <",I) COST(S)

23,072 Zl,IJ72 10 21.83 0,25

4,513 0,3 4,514 

## I Z7,585 COST(S) Z7,5llS 10 21.83 0,25 838,966 212,669 248,255

App A- RACT Cost Effectiveness !H-2013.xls. Unit 866-12Hl LNB & SNCR 49 of66FES Refinery H•• ler Firing Ral.Incre...Flan Appnwal NO. RACT eontml C." EIf.di....... SOUIU Unit 861>-12Hl e ••

trol LNB&FGR Rated Ileat Input 6t.2 NumberofBumen 6.0 Baseline Actual Emissions 30.29 Curftn( Emis$ion Kale 0.113 ContmlEfficiency 550/. Healneapadty 64.6 BurnerIleal R.a.- Rate 1l.8 E.alualed alNew FiJi", Lilnit al 2012

# C." and Emde""ies MMBtulhr Burners Ipy Il>lMMBIU GJ/hr GJIhr eMU derived from Allenlati,'r Omtrol T«II1fiIlIU!S lJ.ocM",ell1-NOx EIlfLUimufro/lt Process HMos (Rel'ised) .. EPA-4SJ/R-9J..034 COST COMPONENT: COST(S) DlREC7'COSTS - LNS PurchasedEquipment Costs Equipment Cost (EC) 188,440 Instrumentation (10"10 orEe) 18.844 Sales taxes (5% cfEe) 9,422 Freight (8% ofEe) 15,075 Sltbto,aJ. PIIrdtlU<dEqMipMml C",'s (PEe) 231,781 Direct ilUlallation Cos/s (Bwed on Vendor Discussion) Foundations & supports; handling & erection: dectrical; piping: ete. 0 Site Prepanlfjon I**BuiJdings~** Included above 

# ---- Sltbrolai-**Di"~ct** InstaJWioR Costs 0 TOTAL DIRECTCOSTS (rOC) - LNS 231,781 INDIRECTINSTALLATION COSTS - LNB EngineeringCosts (5% ofPEC) 11.589 Construct. & Field Ex.penses (included in above costsI Contractor Fees (J 0% ofPEC) 23,178 Stan-up (1% ofPEC) 2,318 Perfonnance Test (1°/(, ofPEC) 2,318 Contingency (3% ofPEC) 6,953 TOTAL INDIRECTCOSTS. IC - LNB 46,356 DIRECTCOSTS - FGR PurchasedEqllipment Costs Equipment Cost (EC) 218,823 InsrrumenlatlOn (Included in above costs) --- Salestaxes (Included in above costs) Freight (included In above costs) --- 5Mbtolal- PIIrcltlllli.d Eqllipment Costs (PEe) 218,823 Direclln.HallCilion COSIS (Based on Vendor Discussi(mj Foundations &**supports~** handling & erection; electricatpiping; etc. 0 Site Preparation /**Buildings~** Induded above 

# --0-- Subtotal**~** Dine,lnstaJUtJimt. ('osIs TOTAL DIREC7'COSTS (TDCJ - FGR 218,8Z3 INDIRECTINSTALLATION COSTS - FGR EngmeeringCosts (Included in above costs) 

### --- Construct & Field Ex.penses{mcluded in above costs) --- Contractor Fees (Included in above costs) --- Start-up (Included in above costs) Perfonnance Test (Included in above costs) Contingency (3% ofPEC) 6.565 TOTAL INDIRECTCOSTS.IC- FGR 6,565 TOTAL CAPITAL INVESTMENT (TCI) - LNB 278,137 TOTAL CAPITAL**I~VESTMENT** (TCI) - FGR 225,388 TOTAL CAPITAL**rNVESTME~T** (TCI) 503,525

App A - RAG Cost Effectiveness 9-6-2013.xl.. Unit 866-12Hl LNB & FGR 50 of 66PES Refinery HeaterFiring Ratelno,,_ Plan Approval NO. RACT Control Cost En<cliv...... COST (''OMPONENT: ANNUAL DIRECTCOSTS Operation and MaintenanL'e Labor Maintenance Labor and Material (2,75% of

### IeI) AnnualizedCOS! Factor Replacemenl Life (years) = Interest Rate (%) "" Annualized Cost Factor Replacement cOSt SlllitOiai**~** OpttrtJlj(lfllUUlMaiII1elJdlfce lAbt.W Utililies Electricity Cost SltbIO/oJ - Ulilllie> TOTAL ANNUAL DIRECT COSTS·
COSTCOMPONENT: TOTALANNUAL OdM COSTS Annualized Cost Pac/or Equipment Life (yellTS) "" Interest Rate {%) = Annualized Cost Factor CAPITAL RECOVERYCOSTS TOTAL CAPITAL REQUIREMENT TOTALANNUAL CAPITALREQUIREME"T TOTALANNIJALIZEDCOST (Total PIJMaIO&MCMI iUUItmllualiudcapitalcost) COST(S)**~** 13,847
10 21.83 0,25

7.781 7,781 21,628 COST(S) 21,628 10 21.83 0.25 503.525 127,639 149,267

App A- RACT COst EffectIveness 9-6·2013.xl..**Un~** 866-12Hl LNB & FGR 

## I

Sl0166

# ,

, PES Refinery Heater Firing Rate Increase Plan Approval NOx RACT Control Cost Effectiveness Source Unit 866-12HI Control Sl'iCR Rated Heat Input 61.2 Number ofBurners 6.0 Baseline Actual Emissions 30.29 Current Emission Rate 0.113 Control Efficiency 40% Heater Capacity 64.6 Burner Heat Release Rate 13.8 Evaluated atNew Firing Limit at 2012 Cost and Efficiencies MMBtulhr Burners tpy Ib/MMBtu GJlhr GJlhr 

### Costs derived (romAlternative Control Techniques Document- NOx Emissions/romProcess Heaters (Revised) - EPA-453/R-93-034

DIRECTCOSTS 

### COST COMPONENT:
PurchasedEquipment Costs

Equipment Cost (EC) Instrumentation (Included in above costs) Sales taxes (Included in above costs) Freight (Included in above costs) 

### Subtotal- PurchasedEquipment Costs (PEC) Direct Installation Costs (Basedon Vendor Discussion) Foundations & supports; handling & erection; electrical; piping; etc. Site Preparation 

### I Buildings- Included above 

### Subtotal- DirectInstallation Costs TOTAL DIRECT COSTS (TDC) INDIRECTINSTALLATION COSTS Engineering Costs (Included in above costs) Construct. & Field Expenses (Included in above costs) Contractor Fees (Included in above costs) Start-up (Included in above costs) Performance Test (Included in above costs) Contingency (3% ofPEC) TOTAL INDIRECT COSTS. IC 

### TOTAL CAPITAL INVESTMENT (TCI)

App A RACT Cost Effectiveness 9-6-2013.xlsx Unit 

### 866-12Hl SNCR 

### COST ($)

544,494


### 544,494


# o o 544,494

16.335 

### 16.335 560.828



### 52 

### of66

# " " PES Refinery HeaterFiring Rate Increase Plan Approval NOx RACT Control Cost Effectiveness COST COMPONENT: ANNUAL DIRECTCOSTS Operation andMaintenance Labor Maintenance Labor and Material (2.75% ofTCl) 

### Annualized Cost Fac/or Replacement Life (years) Interest Rate (%) = Annualized Cost Factor Replacement cost 

### Subtotal- Operation andMaintenance Labor Utilities Ammonia Cost Electricity Cost 

### Subtotal- Utilities 

### TOTAL ANNUAL DIRECT 

### COSTSs


### COST COMPONENT: TOTAL ANNUAL O&M COSTS Annualized Cost FaClOr Equipment Life (years) = Interest Rate (%) = Annualized Cost Factor 

### CAPITAL RECOVERYCOSTS TOTAL CAPITAL REQUIREMENT TOTAL ANNUAL CAPITAL REQUIREMENT TOTAL ANNUALIZED COST (TotalannualO&Mcost andannualized capital cost)

App A - RACT Cost Effectiveness 9-6-2013.xlsx Unit 866-12Hl SNCR 

### COST ($)
15,423 

### ]5."23 10 21.83 0.25

4,513

0.3



# ....

';;]

# .. ]9,936


### COST ($)

]9,936 10 21.83 0.25 560,828 

### 142.164 162,10]

53 

### of 66

# (" 

# f"
PES Refinery Heater Firing Rate Increase Plan Approval Unit 868-8H101 RACT Cost Effectiveness Summary A B 

### C 

### D E F 

### G II 

### Current Control Maximum Post Potential 2012 Total Control Option Design Firing Emission Rate Potential Emissions Efficiency Control Emissions NO. Capital Cost 2012 O&M Cost (MMBtu/hr) (TPY) @ 

### Design Firing Reduced ($) (lb/MMBtu)l (%) (TPY) (TPY) ($) ULNB&SCR 60 0.113 29.7 96% 1.2 28.5 3,472,395 119,468 SCR 60 0.113 29.7 85% 4.5 25.2 2,949,422 105,087 ULNB 60 0.113 29.7 73% 7.9 21.8 522,973 14,382 LNB&SNCR 60 0.113 29.7 70% 8.9 20.8 1,057,946 33,519 LNB&FGR 60 0.113 29.7 55% 13.4 

### 16.3 726,468 27,607 SNCR 60 0.113 29.7 40% 17.8 11.9 554,204 19,666 Calculation = A • B• 8760 / 2000 = C· (1- DJ =C-E Notes: 1 

### Unit 868-81:1101 is projected to be above PADEP presumptive RACT firing limits and assumed NO, emission rate limit of0.113 Ib/MMBtu is used. 2 

### See "RACT Cost Summary" tab for details on the Annualized Cost Factor (ACF).

App A - RACT Cost Effectiveness 9-6-2013.)(lsl( 868-8HIOl RACT

# ~

2012 Annualized 2012 Cost Cost2 

### Effectiveness

($) ($/Ton) 999,686 35,060 852,736 33,782 146,950 6,737 301,697 14,513 211,759 12,965 160,151 13,482 i = 

### (G* ACFJ + 

### H = I / F .



### 54 of 66

# (, PES Refinery Heater Firing Rate Increase Plan Approval NO. RACT Control Cost EfI'ectiven.., Source Unil 868-3HIOI Control ULNB&SCR Rated neal Input 60.0 MMBtulhr Number or Burners 4.0 Burners Baseline Actual Emissions 29.70 tpy Current Emission Rate 0.113 IblMMBtu Control Efficiency 968;. HeaterCapacity 63.3 GJ/hr Burner Heat Release Rate 20.3 GJlhr Evaluated atNew Firing Limit at 2012 Cost and Efficiencies C05rs d.ri,ed rrom AllulUlli". Control Techniques DocumenJ·NOx Emissionsfrom ProcessHeIllus (Revi5etI) • EPA.-453/R-93-034 COSTCOMPONENT: COST ($) DJRECTCOSTS - ULNB PurchasedEquipment Costs EquIpment Cost (EC) 354,317 Instrumentation (10% ofEe) 35.432 Sales taxes (5% ofEe) 17.716 Freight (8% ofEe) 2S.345 Sublolal.PurcluzsedEquipmenJ Costs (PEe) 435.810 Direct Installation Costs (Based on Vendnr Discussion) Foundations &**supports~** handling &. erection; electrical; piping; etc. 0 Site Preparation I Buildings-Included above ..

# - Subtotaf· Direcllnstallali,m Costs 0 "!VTAL DIRECTCOSTS rrDC)· ULNB 435.810 

# (, INDIRECTINSTALLATION COSTS· ULNB Engineering Costs (5% ofPEC) 21.791 Construct. & Field Expenses (Included in above costs) ConlTllCtor Fees (10% orPEe) 43.581 Start-up (1 % ofPEC) 4,358 Perfonnance Test (1% ofPEC) 4,358 Comingency(3% ofPEe) 13,074 TOTAL INDIRECTCOSTS. Ie - ULNB 87.162 DIRECTCOSTS - SCR Purchased Eqllipmenf Costs Equipment Cost (ECI 2.863.517 Instrumentation (Included in above costs) . -- Sales taxes (Included in above costs) ... Freight (Included in above costs) ..

### - Sublolal· Purchased Equip",enJ Costs (PEe) 2,363,517 Direct }ns/alia1ion Costs Foundations & supports; handling & erection; electrical; piping; etc. 0 Site Preparation I Buildings· Included above Sllblolaf· DireclInstallation Costs 0 TOTAL DIRECT COSTS rrDC) - SCR 2,863,517 INDIRECTINSTALLATION COSTS - SCR Engineering Costs (included in above costs) -- . Construc£, & Field Expenses (Included in aoove costs) ... Contractor Fees (lncluded in above costs) Start-up (Included in above costs) Performance Test (Included in above costs) -- Contingency (3%ofPEC) 85.906 TOTAL INDIRECTCOSTS. IC - SCR 85,906 TOTAL CAPITAL Thc'VESTMENT (TCI)· lJLNB 522,973 TOTAL CAPITAL INVESTMENT (TCI) • SCR 2.949.422 TOTAL CAPITAL INVESTMENT (TCI) 3,472.395

App A· RAeT Cost Effectiveness 9-6-2013.xlsx Unit 868-8H10l UlNB & SCR 55 of66

# (;



# , PES Refinery HeaterFiring Rate Increase Plan Appro.al NO. RACT Control Cost Err.ctive..... COST COMPONENT: ANNUAL DIRECTCOSTS Operation andMainlenance Lebor Maintenance Labor and Material (2.75% ofTCI) AnnualizedCost Factor Replacement Life (years) Interest Rate C%): Annualized Cost Factor Replacement cost Subtotal**~** Operation lind MllintentlllCt!Lahor Utilities Ammonia Cost Catalyst Replacement Cost Electricity Cost Subtotal- Utililies IIUIAJ .AI'II'IUA. UIKI>t.:1 t.:Ul!).il!) COST COMPONENT: TOTAl.AN.NUAL O&MCOSTS AnnualizedCost Factor Equipment Life (ye",,)**~** Interest Rate (%1 Annualized Cost Factor CAPITAL RECOVERYCOSTSTOTAL CAPITAL REQUiREMENT TOTALANNUAL C4PITAL REQUlREME/'.T TOTALANlVUALIZED COST (T0/4lo_al O&Mcostandannuoli;:eJcapital cost) 10 21,83

10 21,83

App A - RAeT Cost Effectiveness9-6-2013.•15' Unit 868-8HIOI ULNB & SCR COST(S)
95,491 95,491

0.25

4,425 19,552 0.3 23,978 119,468 COST(S) 119,468

0.25 3.472,395 880,217 999.686

56 of 66

# (., PES Refinery Heater Firing Rate Increase Plan Approval NOx RACT Control Cost Effectiveness Source Unit 868-8HIOI Control SCR Rated Heat Input 60.0 Number ofBurners 4.0 Baseline Actual Emissions 29.70 Current Emission Rate 0.113 Control Efficiency 85% Heater Capacity 63.3 Burner Heat Release Rate 20.3 Evaluated at New Firing Limit at 2012 Cost and Efficiencies MMBtulbr Burners tpy IblMMBtu GJlbr GJlbr Costs derived from Alternative Control Techniques Document- NOxEmissions from Process Heaters (Revised) - 

### EPA-453/R-93-034

DIRECTCOSTS 

### COST COMPONENT:
PurchasedEquipment Costs



### Equipment Cost (EC) Instrumentation (Included in above costs) Sales taxes (Included in above costs) Freight (Included in above costs) Subtotal- PurchasedEquipment Costs (PEC) Direct instal/ation Casts 

### Foundations & 

### supports; handling & 

### erection; electrical; piping; etc. Site Preparation I 

### Buildings- Included above Subtotal- Direct Installation Costs TOTAL DIRECT COSTS (TDC) iNDIRECTINSTALLATION COSTS 

### Engineering Costs (Included in above costs) Construct. & 

### Field Expenses (Included in above costs) Contractor Fees (Included in above costs) Start-up (Included in above costs) Performance Test (Included in above costs) Contingency (3% ofPEC) TOTAL INDIRECTCOSTS, IC 

## TOTAL CAPITAL INVESTMENT (TCI)

App A - RACT Cost Effectiveness 9-6-2013.xlsx Unit 

### 868-8H10l SCR COST ($)


### 2,863,517
2,863,517


## o



# ---

o 2,863,517

85,906 85,906 2.949.422



### 57 of 66

# " PES Refinery Heater Firing Rate Increase Plan Approval JliOx RACT Control Cost Effectiveness COST COMPONENT: ANNUAL DIRECTCOSTS Operation andMaintenance Labor Maintenance Labor and Material (2.75% ofTCl) Annualized Cost Factor Replacement Life (years) Interest Rate (%) Armualized Cost Factor Replacement cost Subtotal- Operation andMaintenance Labor Utilities Ammonia Cost Catalyst Replacement Cost Electricity Cost Subtotal - Utilities 

## TOTAL ANNUAL DIRECT COSTS·
COST COMPONENT: TOTAL ANNUAL O&'M COSTS Annualized Cost Factor Equipment Life (years) Interest Rate (%) 

### Armualized Cost Factor CAPITAL RECOVERYCOSTSTOTAL CAPITAL REQUIREMENT TOTALANNUAL CAPITAL REQUIREMENT TOTALANNUALIZED COST (Total annual O&'M cost andannualized capital cost)



### App A - RACT Cost Effectiveness 9-6-2013.xlsK Unit 

### 868-8H10l SCR COST ($)


### 81.109 81,109 10 21.83 0.25

4,425 19,552

0.3 23,978 105,087
COST ($)



### 105,087 10 21.83 0.25 2.949,422 747,649 852,736



### 58 of 66

# c



# , PES Refinery Heater FiringRate Increase Plan Approval NOx RACT Control Cost Effectiveness Source Vnit 868-8H]0] Control llLNB Rated Heat Input 60.0 Number ofBurners 4.0 Baseline Actual Emissions 29.70 Current Emission Rate 0.113 Control Efficiency 73% Heater Capacity 63.3 Burner Heat Release Rate 20.3 Evaluated at New Firing Limit at 2012 Cost and Efficiencies MMBtulbr Burners tpy IblMMBtu GJ/hr GJlbr Costs derived from Alternative Control Techniques Document- NOx Emissions/rom Process Heaters (Revised) - 

### EPA-453/R-93-034

DIRECTCOSTS 

### COST COMPONENT:
PurchasedEquipment Costs



### Equipment Cost (EC) Instrumentation (10% ofEC) Sales taxes (5% ofEC) Freight 

### (8% ofEC) 

### Subtotal- PurchasedEquipment Costs (PEC) DireCIInslallation Costs (Based on Vendor Discussion) 

### Foundations & 

### supports; handling & 

### erection; electrical; piping; etc. Site Preparation I 

### Buildings- Included above 

### Subtotal - DirectInstallation Costs TOTAL DIRECT COSTS (l'DC) INDIRECTINSTALLATION COSTS 

### Engineering Costs (5% ofPEC) Construct. & 

### Field Expenses (Included in above costs) Contractor Fees (10% ofPEC) Start-up 

### (1% ofPEC) Performance Test (1 % 

### ofPEC) Contingency 

### (3% ofPEC) TOTAL INDIRECTCOSTS. IC 

### TAL CAPITAL INVESTMENT (TCI)

App A - RACT Cost Effectiveness 9-6-2013.xlsx Unit 868-8H10l UlNB 

### COST ($)


### 354,317 35,432 17,716 28,345 435,810


## o 

# o 435,8]0 21,791 43,581 4,358 4,358 

### 13,074 87,162 522.973



### 59 of 66

# , PES Refinery Heater FiringRate Increase Plan Approval NOx RACT Control Cost Effectiveness COST COMPONENT: ANNUAL DIRECTCOSTS Operation andMaintenance Labor 

### Maintenance Labor and Material (2.75% ofTCI) Annualized Cost Factor 

### Replacement Life (years) 

### = Interest Rate (%) = 

### Annualized Cost Factor Replacement cost 

### Subtotal- Operation andMaintenance Labor Utilities 

### None 

### Subtotal- Utilities 

## TOTAL ANNUAL DIRECT COSTS·
COST COMPONENT: 

### TOTAL ANNUAL O&M COSTS Annualized Cost Factor 

### Equipment Life (years) 

### = Interest Rate (%) 

### Annualized Cost Factor CAPITAL RECOVERYCOSTS TOTAL CAPITAL REQUJREMENT 

### TOTAL ANNUAL CAPITAL REQUIREMENT TOTALANNUALIZED COST (Total annual O&M costandannualized capital cost)

App A RACT Cost Effectiveness 9·6·2013.xlsx Unit 868-8H 101 ULNB 

### COST ($)


### 14,382 

### 14,382 10 

### 21.83 0.25



### 0.0 14,382
COST ($)



### 14,382 10 21.83 0.25 522,973 

### 132,568 146,950

60of66

# ,

,

iPES Refinery HeaterFiring Rate Increase PlanApproval NO. !tACTControlCo..EfIf<li....... Sourer**Uni'~HIOI** Control LNB& SNCR Raled Heal Input 611.0 Nwnber ofBumen 4.0 Basetinr Actual Emissions 29.70 CumntEmission Rate 0.113 Control Ellk:i.l1(y 70°/. HeatorCapacity 63.3 BurnerH•• I Release Rate 20.3 E"aluatfod atNew FiliAlLimit at 2012 Costand Efficiencies MMBtulhr B

......... Ipy IbiMMlltu GJlhr GJlhr C.... dl'ri .... r...... AIt<mtatiw C."",t7/Technu,...lJocIl"'...t - NO:r Emiss;ons/rom Ptoa:ss

### n"",...(RtMsell) • EPA-45JIR-93-034

DIRECTCOS-m . LNS COST COMPONENT:

Purchased£quipmertl Costs

Equipment Cost (EC) Instrumentation (10% ofEC) Sales taxes (5% ofEC) Freight (8% ofEC)

Direct b1s1allalio11 Costs (Based on Ve"dorDiscussion) Foundations & supports: handling & erect1on; elecrncaL piplng; etc, Site Preparation j Buildings- Induded above !lMb/otai- D/ncJ f1tSlaillAtiotr Costs TOTAL DIRECTCOS-m (l'DC)· LNS INDIRECTINSTALLATION COS-m - LNS EngineeringCosts (5% ofPEC) Construct. & Field Expenses (Included in abovecosts) Contractor Fees (I 0%, ofPEC) Stan·up (1% ofPECj Performance Test (1% ofPEC} Contingency (3 0 /0 ofPEC) TOTAL INDIRECT COS-m. /('- V"S DIRECTCOS-m • SNCR PurchasedEquipment C05/$ Equipment COS! (EC) Instrumentation (lnc1uded inabovc costs) Sales taxes (Included in above costs} Freight (Included tn above costs)
Direct Installation Costs (Basedon Vendor**Dh~cussion)** Foundations & supports; handling &**erc~tion~** eJectrical; piping; ele Site Prepanrtion JBuildings- Included above 5MblOf1l1**~** DindJIIstsJlatio" Costs TOTAL DIRECTCOS-m (l'DC! - SNCR INDIRECTINSTALLATION COS-m· SNCR EngineeringCosts (Included in above costs) Construct. & Field Expenses (Included in above costs) Contractor Fees {Included in above costs) Start·up (Included in above costs) Performance Test (Included in above costs) Contingency (3°,0 ofPEC) COST(S)

341,289 34,129 17.064 27.303 419,785

o
419,785 20.989 41.979 4,198 4.198 12,594 83,957
538,062

--0--

538,062

16.142 ,TOTAL INDIRECT COSTS, /('- SNCR 16,142 TOTAL CAPITAL INVESTMENT (TCI - L"IB 503.742 TOTAL CAPITAL INVESTMENT (TCI) - SNCR TOTAL CAPITAL I"IVESTMENT TCI 1,857,946

AppA - RACT Cost Effectiveness 9·6-2013.xlsx Untt 868-8HIOI LNB & SNCR 610166PES Refinery Heater Firing Rate Increase Plan Approval NO. IlACT C.ntrol C••• Effecli....... COST COMPONENT: ANNUAL DIRECTCOSTS Operation andMaintenance lAbor Maintenance Labor and Material (2.75% ofTen Annualized COSI Facfor Replacement Life (years) = Interest Rate**(~;&)** =- Annualized Cost Factor Replacement cost 5MbtlJlal- Opt!rtllilJlfm;d**Mabu~"tllfu** Labo, Ulililies Ammonlll Cost Electricity Cost 5Mbtolol- lJ,1l1t1r.i TOTAL ANNlJAL DIRECT COSTS'
COST COMPONENT: TOTALANNUAL O&M COSTS Annualized Cost Factor Equipment Life (years) = Inlercst Rate (0,'0) "" Annualized COSI Factor CAPITAL RECOVERYCOSTS TOTAL CAPITAL REQUlRE}.f£,\'T TOTALANNlJAL CAPITAL REQVlREME!IIT IVTALANNUAlJZEDCOST (Totollllfnllol O&M COIJtlUIdlUInualizdcapiIaleost) COST(S)**~** 29,1)94 10 21.83 0.25

4,425 0.3 4,425 33,519 COST(S) 33,519 10 21.S3 0.25 1.057,946 268.179 3111,697

App A - RACT Cost Effectiveness 9-6-2013,xl.. Unit 868-8HIOIlNB & SNCR 620166PES Refinery HeaterFiring Rale Inc"'.... PlanApproval NO. RACfC... troIC.. t EIf.cdv...... Sou.... lInil868.8HIOI Cootrol LNB& FGR RaCed Heat Input 60.0 Number

### .rBumo... 4.0 BueliDtActual Emissions 29.70 CUI'I'Ut Emission Rate 0.113 Control Elftd<n<y 55% HtaterCapacity 63.3 BumerHeat**R~** Rate 20.3 Evaluated al NN Firing Limit atlOUCOSI and Emcien(ie! MMBtulhr Burners tpy IblMMBru GJlhr GJlhr Costs derivrG fromA/lenrllliw COItIro/Teclutiq"nDocItmenJ.NOx Emissimts/romProcessHestO'S (RelTsedj - EPA4-53/R-9J..{)34 COST COMPONENT: COST(S) DIRECTCOSTS· WB PurchasedEquipment Costs Equipment Cost (Ee) 341.289 Instrumentation (10% ofEC) 34.129 Sales taxes (5% ofEC) 17,064 Freight (8% ofEe) 27,303 Subtotal. Pw,cJ"mtlEqHi_", Costs (PEe) 419,785 Directlnslallal;on Costs (Basedon Vendor Discussion) Foundations & supports; handling & erection; elt>ctrical: piping; etc. 0 Site Preparation I Buildings-Included above ...
---- SllbJota/- DirectJ",s/allaJimt Costs 0 TOTAL DIRECTCOSTS (FOC)·LNB 419,785 INDIRECTlNSTALLATION COSTS· LNB Englneering Costs (5% ofPEC) 20,989 Construct & Field Expenses (Included in above costs., Contractor Fees ( 10% ofPEC) 41,979 Start-up (1% ofPEC) 4,19R Pcrfonnance Test (I% ofPEC) 4,198 Contingency (3% ofPEC) 12,594 TOTAL INDlRECTCOSTS. IC ·LNB 83,957 DIRECTCOSTS· FGR PurchasedEquipment Costs Equipment Cost (EC) 216,239 Instrumentation (Included in above costs) ... Sales taxes (Included in above**cost~)** Freight (Included in above costs) 

### ... Sub,,,,aI. Pwrc/JasedEquipllfeltl Costs (PEe) 216,239 DirectJralallalion Cost-, (BasedOn Vendor**Dis<-:lL~sion)** Foundations & supports; handling & erection: electrical; piplng; etc. 0 Site Preparation I**Buildings~** Included above 

# --0-- 5Mb10/4I- Dirm IltsJIIJl.t1JiOlt Costs TOTAL DIRECTCOSTS (rOC) . FGR 216.239 INDIRECTINSTALLATION COSTS· FGR Engineering COS!S (lnduded in above costs) .-- Construct & f'icld Expenses (lnc1uded in above costs} ... Contractor Fees (Included in above costs) Start-up (Included in above costs) Perfonnance Test (Included in above costs) Contingency (3% ofPEe) 6.4R7 TOTAL INDIRECTCOSTS. IC· FGR 6,487 TOTAL CAPITAL INVESTMENT (TCI) . LNB 503,742 TOTAL CAPITAL INVESTMENT (TCI) - FGR 222,726 TOTAL CAPITAL INVESTMENT (TCI) 726,468

App A • RACT COst Effectiveness 9·&-2013.xlsx Unit 868·8H10l LNB & FGR 630/66PFS Refinery HeaterFiring Rate Increase Plan Approl.'al NO. RACT Control CostElTectiv...... COST COMPONENT: ANNUAL DIRECTCOSTS Operation a"dMail1lenance Labor Maintenance Labor and Malerial (2.7S'!."o ofTel) AmtlJolizeriCos/Factor Annualized Cost Factor Replacement cos1
Utilities Electricity Cost 8.b/0Ia1· Utilities !TOTAL ANNUAL DIRECT COSTS'
COST COMPONENT: roTALANNUAL O&MCOSTS AnnualizedCost FacIOI' Annualized C(Jst Factor CAPITAL RECOVERYCOSTS TOTAL CAPITAL REQUIREMENT Replacement Life (yem)**~** Interest Rate**(I,l/~)** =

Equ;pment Life (years)**~** Interest Rate (%1'""

TlffALANNUAL CAPITAL REQUIR1:."MENT TOTALANNUALIZED C08T (TOIaI ... If"a1 ruM_ fUfd ...."a1i;dCtIpiI4J CO$l) 10 21.83

10 21.83 COST (51**~** 19,978
0,25

7,629 7,629 27,607
COST ($) 27,607
0,25 726,468 184,152 211,759

AppA - RAGCost Effectiveness 9-6-2013,.1.. Unit 868-8H10llNB & FGR 640166

# ,

, PES Refinery Heater Firing Rate Increase Plan Approval NOx RACT Control Cost Effectiveness Source Unit 868-8HI01 Control SNCR Rated Heat Input 60.0 Number ofBurners 4.0 Baseline Actual Emissions 29.70 Current Emission Rate 0.113 Control Efficiency 40"/0 Heater Capacity 63.3 Burner Heat Release Rate 20.3 Evaluated at New Firing Limit at 2012 Cost and Efficiencies MMBtulhr Burners tpy IblMMBtu GJlhr GJlhr Costs derived from Alternative Control Techniques Document- NOx Emissions/romProcess Healers (Revised) - 

### EPA-4531R-93-034

DIRECT COSTS 

### COST**COMPO~E~T:**
PurchasedEquipment Costs

Equipment Cost (EC) Instrumentation (Included in above costs) Sales taxes (Included in above costs) Freight (Included in above costs) 

### Subtotal.PurchasedEquipment Costs (PEC) Direct Installation Costs (Basedon Vendor Discussion) Foundations & supports; handling & erection; electrical; piping; etc. Site Preparation I Buildings- Included above 

### Subtotal - DirectInstallation Costs TOTAL DIRECTCOSTS (TDC) INDIRECTINSTALLATION COSTS Engineering Costs (Included in above costs) Construct. & Field Expenses (Included in above costs) Contractor Fees (Included in above costs) Start-up (Included in above costs) Performance Test (Included in above costs) Contingency (3% ofPEC) TOTAL INDIRECT COSTS. IC 

### TOTAL CAPITAL INVESTMENT (TCI)

App A - RACT Cost Effectiveness 9-6-2013.xlsx Unit 868-8H10l SNCR 

### COST ($)

538,062



### 538.062


# o



# --- 

## o 538,062

16,142 

### 16,142 554,204

65 of 66

### PES Refinery HeaterFiring Rate Increase Plan Approval NOx RACT Control Cost Effectiveness COST**COMPO~E~T:** 

### ANNUAL DJRECTCOSTS Operalion andMaintenance Labor Maintenance Labor and Material 

### (2.75% ofTCI) 

### Annualized Cost Faelor Replacement Life (years) = Interest Rate 

### (%) = Annualized Cost Factor Replacement cost 

### Subtotal- Operation andMaintenance Labor Utililies Ammonia Cost Electricity Cost 

### Subtotal· Utilities 

## TOTAL ANNUAL DIRECT COSTS 8


### COST COMPONENT: TOTAL ANNUAL O&M COSTS Annualized Cosl Faclor Equipment Life (years) Interest Rate 

### (%) Annualized Cost Factor 

### CAPITAL RECOVERYCOSTS TOTAL CAPiTAL REQUiREMENT TOTAL ANNUAL CAPITAL REQUIREMENT TOTAL ANNUALIZED COST (Total annual O&M costandannualizedcapitalcost)

App A - RACT Cost Effectiveness 9-6-2013.xlsx Unit 86B-8H101 SNCR 

### COST ($)


### 15,241 15,241 10 21.83 0.25

4,425 0.3 4,425 19.666


### COST ($)



### 19,666 10 21,83 0.25 554,204 14M85 160,151

66 of 66

# AttachmentB AMS Plan ApprovalApplication Forms

# CITY OF PHILADELPHIA DEPARTMENTOF PUBUC HEALTH PUBUC HEALTH SERVICES AIR MANAGEMENT SERVICES 

### Nt Management

### ServIcaI 321 Untvwalty Avenue PhIIadeI,phIe 

### PA 19104-4543 Phone: (215) 885-7572 FAX: (215) 888-7693 

## APPLICATION FOR PLANAPP1tOVALTOCONSTR.UCI', MODIFYORREAcnv ATEAN AIR CONTAMINATION SOURCE AND/ORAIRCLEANING DEVICE



## (Prepan "II

## bl/trmUl.t.iDn armpldelyill

## printor

## type in triplicll.U)

# (' 

# t' 

# f"

SECTION F I - GENERAL SOURCE INFORMATION I. SOURCE 2. NORMAL PROCESS OPERATING SCHEDULE A. B 

### C. D. 

### E. A. B. 

### C. D. TypeSoun:e Manulaclurer ModclNo. Rated Capacity Type ofMaterials Processed Amount Average Total % Throughput/Quarter (Describe) ofSoun;e (Specify units) Processed/yr. hr/day hr/yr (Specify units} I" 2"" 3n1 4'" I Target heaters See Attached Report for Proposed Heater Firing Changes



# -- 3. ESTIMATED FUEL USAGE (Specify Units) 4. ANNUAL FUEL USAGE

-------- A. B. 

## e. D. E. F. G. A. B. 

## e. D. Used Type Fuel Average Maximum Percent Percent Ash Heating Value Annual Amounts Average Total hr/yr % '[broughput/Quarter

in Hourly Hourly Rate Sulfur hr/day Unit Rate 

## " 2"" 3'" 4" See Attached Report for Proposed Fired Htr. Duty Changes

S. IMPORTANT: Attach on a separate sheet a flow diagram ofprocess giving all (gaseous, liquid, and solid) flow rales. Aim list raw materials charged to process equipment alld the amounts charged (tons/hour, etc.) at rated capacity (give maximum, minimum and average charges describing fully expected variations in production ntes). Indicate (on diall:ram) all poinlS where contaminalilS are controlled (location ofwater sprays, hoods or otherpickup paints, etc.).

# c 

# " SECTION Fl· GENERAL SOURCE INFORMATION**CO~TINUEO** 6 Describe process equipments in detail. See Attached Report Sections

7. 

### Describe fully the methods used to monitor and record all opmllingconditions that may affect the emission ofair contammants. Provide detailed infonnation to show that these methods provided are adequale. No New Monltoring Equipment 15 Proposed or Required

8. Describemodifications to proces.<; equipments in detail. See Attached Report Sections

9. Auach any and all additional infonnation necessary to adequately describe the process equipment and to plrlorrn a thorough evaluation ofthc extent and nature ofits emissions. See Attached Report that includes a BATIRACT analysis

PROVIDE EQUIPMEr-rT INFORMATION ON THlS PAGE If SOURCES DO NOTBELONG TO SPECIAL CATEGORIES IN f2 TO FS, OTHERWISE REMOVE THIS PAGE FROM Tm'i APPLlC:\**T10~** IF THERE ARE MORE EQUIPMENT, COpy THIS PAGE AND FlLL IN THE INFORMATION AS INDICATED

### SECTION F 2· COMBUSTION UNITS INFORMATION I COMBUSTION UNITS HIOI; H201; 11Hl; 11H2; 12Hl; 8HI01; BIOI· See Discussion Sections

A. Manufacturer NA B. 

### ModdNo. NA 

### 0 Rated heat input (Btulhr) E 

### Peak heat input (Btu/hr) NA NA G. Method firing 

# o Pulvenzed 

## 0 Spreader Stoker

## 0 Cyclone 

## 0 Tangential 

## 0 Normal 

## 0 FIUldi7.a1**~** 

# o Other 2 

### FUEL REQUIREMENTS lYPE 

### QUANTITY QUANTITY SULFUR HOURLY ANNUALLY OIL NuMBER NA NA NA NA OTHER NA NA NA NA 3. COMBUSTION AIDS. CONTROLS, AND MONITORS (No New Equipment) 

# o A O"erflfejets 

### Type Number
i 

# o B. 

### Draft controls Type Type 

# I 0 C. 

### Oil preheat



# o D. Soot cleaning Temperature (" F) Frequency IDE. Slack sprays Method



# o F. 

### Opacity monitoring device Method 

# o G. Sulfur oxides monitoring device Type Method 

## I8:I H. 

### N itrogCIJ oxides monitoring device Type Method 

## I8:I t 

### Fuel metering and/or recording devices Type Method 

## OJ. Atomization interlocking device Type Method 

# o K. 

### Collected flyash reentrainment prevenlative device Type 

# o L. Modulating controls 

# B Step Automalic 

## 4.0 Flyash reinjection. (De:scribeoperntion) NIA 5. Describe method ofsupplying make up air to the furnace room. NIA

USE TIllS PAGE FOR COMBUSTIOI' SOURCE. OTHERWISE REMOVE THIS PAGE FROM THIS APPLICATION IF THERE ARE MORE THAN OI'E UNn', COpy THIS PAGE AND FILL IN THE INFORMATION AS INDICATED 

### C Unit No. NA F Use NA



### ASH BTUCOr.TENT NA NA NA NA Height above gmte

Cost COSI COSI 

### Cost CostSECTION F 2 - COMBUSTION UNITS INFORMATION, CONTINUED 6 OPERATING SCHEDULE

- NA hours/day NA days/week NA weeks/year 7. SEASONAL PERIODS (MONTHS) N/A Opa-dlingusing primary fuel Operaling usmg secondary fuel __ .. to 10 Non.aperaling to 8. Ifheal input is in excess of250 x 10 " Btuihr .. describe fully the methods used 10 record the following: rale of fuel bum<XI; heating value. sulfur and ash content of fuels; smoke. sulfur oxides and nitrogen oxides emissions; and if electric generating plant. the average electrical output and the minimum and maximum hourly generation rate. PES will continue to monitor, record, and report witb applicable reqnirements found in tbe Pbiladelpbia Refinery'S existingTitle V permit and the Consent Decree

9. Describemodifications to boilerin detaiI. See Attached Report Sections

10. Type and method ofdisposal ofall waste materials generat<XI by this boiler. (Is a Solid Waste Disposal Permit ne<XI<XI? 

## 0 Yes 

## 181 No)

II. Briefly describe the method ofhandling the waste water Irom this boiler and its associat<XI air pollution control equipment. (Is a Water quality Management Pennit needed? 

## 0 Yes 

## 181 No)

12. Attach any andall additional information necessary to perfonn a thorough evaluation ofthis boiler. See Attacbed Report Sections**U~'E** THIS PAGE FOR COMBUSTION SOURCE. OfHERWlSE REMOVE nIlS PAGE FROM THIS APPLICATION. IF THERE ARE MORE THAN ONE UNIT, COPY THIS PAGE AND FILL L"I THE INFORMATION AS INDICATED 

# ISECfION G - FLUE AND AIR CONTAMINANT EMISSION INFORMATION I. STACK AND EXHAUSTER 

# ! This project does 001 inwlve any changes to e'd.ting stacks or emission points. A. Outlet volume ofexhaust gases 

### B. Exhauster (attach fan curves) CFM @ ___ oF % Moisture in w.g.**HP~.** ___ , ..**~_~**___**._~_** RPM 

### C Stack height above grade (It) D Stack diameter (ft) or Oulld duct area 

### (sq. 

### fl.) E Weather Cap Grade elevation (fI) DyES 

# o NO Distance from discharge to nearest property line(fi) F. Indicate on an attached she<:! the location ofsampling 

### ports with respect to exhaust fan. bre.x;hing. etc. Give all necessary dimensions.

2 POTENTlAL PROCESS EMISSIONS (OUTLET FROM PROCESS. BEFORE ANY CONTROL EQUIPMENT) See Attached Report Sections (lbslhr or gr/DSCF) 

### B. Specific gravity ofparticulate (not bulk den "J . Attached particle size distribution infollllation D. Specify gaseouscontaminants and concentration Contaminant Concentration VOC Contaminants Concentration (1) SO, ppm (Vol.) Ibs/hr (4) ppm (Vol.) Ibslhr (2) NO. ppm (Vol.) Ibs/hr (5) ppm(Vol.) Ibslhr 

# m CO ppm (Vol.) Ibs/hr (6) ppm (Vol.) Ibslhr E. 

### Does process vent through the con!ro] device ': 

### U YES 

# o NO

- If YES continueand fill out theappropriate SECTION H CONTROL EQUIPMENT

If NO skip 10 SECTION] - MISCELLA."lEOUS INFORMATION F. Can the control equipment be bypassed: (IfYes, explain) 

### U YES 

# o NO 3, ATMOSPHERIC EMISSIONS

A. Particulate matteremissions (tons per year) See Attached Report Sections



### B. Gaseous contaminant emissions Contaminants Concentration VOC Contaminants Concentration (I) ___(tPy) (4)_

-- Itpy) (2) __(tpy) (5) (tpy) (3) (tpy) (6) (tpy) See Attacbed Report Sections 

# ,SECTION H • CONTROL EQlJIPMENT CONTINUE[) 12. COSTS - See Attached Report Sections

A. List costs associated with control equipment. (Ust individual controls separately) Control Equipment Cost DlTtxtCost: Indirect Cost: B Estimated annual operating costs ofcontrol equipment only. 13. Describe modifications to control equipment in detail. 

### NiA 14. Describe in detail the method ofdust removal from the air cleaning and methods ofcontrolling fugitive emissions from dust removal, handling and disposal. 

### N/A 15. 

### Docs air cleaning device employhopP"" healers, hopper vibrators or hopp<r level detectors? Ifso, describe. 

### N/A 16. Attach manufucture:r's perfolTl1ance guarantees and/or warranties for each ofthe majorcomponents ofthecontrol system (or complete system). 17. Attach the maintenance schedule for the control equipment and any part ofthe process equipment that ifin disrepair would increase the air contaminant emissions. Periodic maintenance reports are to be submitted to the Department. Maintenance will continue to be be pro\ided as per the manufacturer'srecommendations and the Title V Permit. 18. Attach any and all additional infolTlllllion necessary tothoroughly evaluate thecontrol equipment. See Attached Report Sections

SECTION 1- MISCELLANEOUS INFORMATION I Specify monitoring and recording devices will be used tor monitoring and recording of tbe emission ofair contammants. Provide detailed intonnation to show that the faCilities provided are adequate. Include cost and maintenance information. 

## 0 OpllCity monitoring system 

# o SOx monitoring system 

## 181 NOx monitormg system 

## 0 COmonitoring system 

# o C02 monitoring system 

## 181 Oxygen monitoring system 

## 0 HCL monitoring system 

# o -rn.S monitoring system 

# o H2S monitoring system 

## 0 Temperature monitoring system 

# o Stack flow monitoring system 

# o OthaIfchecked. provide manufucturer's name, model no. and pertinent technical specifications. NO CHANGES PROPOSED FROM EXISTrNG MONITORING, AS OUTLINED IN EXISTrNG TITLE V PERMIT.
PROVIDE CONTROL EQUlPMENT INFORMATION ON THIS PAGE IF IT PERTAINSTOTillS APPLlCA**T'O~.** OTHERWISE REMOVE THIS PAGF FROM THE APPLICATION. IFTHERE ARE MORE OF THE SAMETYPE OF CONTROL EQUlPMEl\.'T, COpy THAT PAGE AND FILL IN THE IN.ORMATION AS I:-':OIC,o.TED COl\!rROL EQCIPMEN'T**CA~** SE FOUND FROM A MANCFAcnJRF.RCATA LOGUE OR VENDORS.

# " 2. Anach Air Pollution Episode Strategy (ifapplicable) 

### NA 3 Ifthe SOUf1:e is subJeCt to 25 Pa. Code Subchapter E. New SOur1:e Review requirements, a. Demonstrate the availability ofemission offset (ifapplicable)
b. Provide an analysis ofalternate sites, sizes, production processes and envitonmental controltechniquc:s demonstrating thaI the benefits ofthe proposed soun:e outweigh theenvironmental and social costs. 

### CO Dispersion modeling is required for PSD purposes. NSR for nonattainment pollutants is not applicable. See the attached Report Sections. 4. Attach calculations and any additional infonnation necessary to thoroughly evaluate compliance with all the applicable requirements ofArticle III ofthe ru Ics and regulations of PbiladeJphia AirManagement, Pennsylvania Department ofEnvironmental Protection and those requirements promulgated by the Admimstro!tor ofthe United States EnvtlUnmental Protection Agency pursuant to the provisions ofthe Clean Air Act. 

### See A ttached Report Sections

PROVIDE COl';,ROl EQUlrMENT**lNFOR~lA**TtON Ol' THIS PAGE IF rr PERTAINS TO THIS '\Pl'llCATION. OTHERWlSE REMOVE TIll' I'AGE FRc)M TIlE APPLICATION. IF THERE ARE MORF. OfTIlE SAME TYPE OF CONTROL EQUIPMENT, COPY TRAT PAGE AND FllllN THE INFORMATION AS INDICATED CONTROL EQUIPMENT CAN BE FOUl':D FROM A MANUFACTURER CATALOGUE OR VENOOHS