## a Duke illf1Power.
George T. Everett, Ph.D. Director,EIWironmenta!IL.egislativeA.ffairs March 30, 2006 Mr. William G. Ross, Jr., SecretaJy NorthCarolina Department ofEnvironment and Natural Resources 160I Mail Service Center Raleigh, NC 27699-1601 Subject: Docket No. E-7, Sub 718 Duke PowerCompliance Plan Annual UpdateNO. Control Record No. NC CAP005 Dear Mr. Ross: 919-235-0955 gtevereti@duke-energy.com

Duke Poweris required by SenateBill!078to file information onorbefore I April ofeachyeartoupdate the Commission on progress to date, upcomingactivities andexpected strategies to achieve the emissionslimitations setoutin G.S. 143-215.1070. Enclosedforfiling are the original and thirty (30) copies ofDuke Power's Compliance Plan Annual Update for2006 that fully describe the company's effortsto complywith this clean airlegislation. The currentplan to meetthe emissionrequirements for NOx and SO,includes: NO, Control- The installation ofSelective Catalytic Reduction (SCR) on Cliffside Steam StationUnit 5and Belews Creek Steam Station Units 1&2 bas been completed. OurNOx plansinclude installation ofSelective Non-catalytic Reduction (SNCR) at 15 units, andburner work atourremaining sites with the. exception ofCliffside Units 1-4. With these installations, Duke can demonstrate compliance with our2007 and 2009 NOx caps underSenate Bill 1078. SO, Control

- The installation ofwet scrubbers on ourtwelve largestgeneratingunits continues tobeourplan. We have worked with theDepartment ofEnvironment andNatural Resources on aplanto accelerate the scrubber installation scheduleatPlant Allen. Acceleration ofthe Allen scrubbers maintains ourdesign and construction continuity andhelps assure DukePowercan meetthe recentlyfinalizedCleanAirInterstate Rule. Costs for our scrubberprojectshave goneupatPlantAllen due to increases in material (steel andpetroleum-basedproducts) and. laborcosts. Explanationsfor these increases have been shared with the Public Staff. ExhibitsA and B outline currentunit specific technology selections, projected operational dates, expectedemissionrates, and the correspondingtons ofemissions that demonstrate compliance with thelegislative requirements to the best ofDuke Power's knowledge at this time. Theprojected estimates of'environmental compliancecosts' forthesepollution control projects are includedinExhibit C. Duke Powerwill continue to examine thetechnology selection, implementationschedule and associated costs. Annnalupdates willbe · ded to the NC Utilities Conunissionas required. If you have questions regarding any aspect ofourplan, please do to contactmy office at 9 I9-235-0955. 

# _..e

T

...

# _<-"Ev~ere~.f'**~** Director,

### En~~ntal!Legislative Affairs DukePower Enclosures

cc: B. Keith Overcash, Director NorthCarolinaDivisionofAirQuality 1641 Mail Service Center Raleigh, NC 27699-1641 

# rn**~&mow~**

# ill APit'- 52m-

AIRguAUTY DIVISION

01 ECTORS OFfiCE

### Duke Power Company General Assembly of North Carolina Session 2001 Senate Bi111078 -Improve Air Quality/Electric Utilities (NC Clean Air Legislation) 2006 Annual Data Submittal

1. Adetailed report on the investor-owned public utility's plans for meeting the emissions limitations set out in G.S. 143-215.1070. Exhibits Aand Boutline the plan as of this date for technology selections by facility and unit, projected operational dates, expected emission rates, and the corresponding tons of emissions that demonstrate compliance with the provisions of G.S. 143-215.1070. Changes to the expected plan for meeting these emissions limitations as compared to past compliance plans are highlighted in these exhibits and described below: NOx Compliance • Technology Change
- The Dan River Unit 3 SNCR project has been deleted from the plan because ofthe expected high cost to install and operate asingle unit SNCR system. • Schedule Changes
- Numerous project schedule changes are included in this 2006 update: • The Buck Units 3&4 Burner projects were accelerated from 2008 to the spring of 2007 to better support compliance with the Phase I cap of 35,000 tons peryear. • The Buck Unit 5SNCR project was accelerated to the fall of2006 to better align with the Buck Unit 6SNCR schedule and allowforthe most effective outage and work sequencing. • The Dan River Units 2&3 Burner projects were delayed until the fall of 2006 because of the elimination of the pollution control project (PCP) exemption in July 2005 and its effect on the permitting process. • The Riverbend Unit 4SNCR project was accelerated to the spring of 2007 for outage optimization andto better support compliance with the Phase I cap of 35,000 tons peryear. • The Riverbend Units 6&7 SNCR projects were accelerated to the fall of 2006 foroutage optimization. • Rate Changes
- Expected rates have been adjusted in this 2006 update based on 2005 operational performance, project schedule changes and other factors: • Allen Units 1-5 expected rates were adjusted based on 2005 ozone season performance; Allen Units 1 &3 SNCR operation demonstrated that 0.16 could be achieved with system optimization. • The Belews Creek Units 1 &2 expected rates were also lowered based on 2005 ozone season results. • The Buck Units 3&4 rates were adjusted as aresult of the Burner project accelerations.

Page 1• Buck Units 5&6 expected rates were lowered based on 

### 2005 ozone season performance along with SNCR equipment guarantees. • Cliffside Units 

### 1 &2 expected rates increased based on 

### 2005 ozone season performance. • The Cliffside 

### 5 expected rate decreased slightly based on 

### 2005 ozone season performance ofthe SCR equipment. • The Dan River Unit 

### 2 expected rate was adjusted slightly based on expected performance. • The Dan River Unit 3 expected rate was changed based on expected performance ofthe burnerequipment, the bumeroutage schedule and the deletion ofthe SNCR equipment. • The Marshall Unit 

### 2expected rate changed due to the timing ofthe SNCR installation outage and 

### 2005 ozone season performance. • The Marshall Units 

### 3&4 expected rates changed based on the 

### 2005 ozone season performance and the current SNCR installation outage schedule; the 

### 2009 expected rates for these units reflect expected further optimization ofthe SNCR equipment. • The Riverbend expected rates were adjusted based on the SNCR installation schedule changes and lowerSNCR equipmentguarantees. Because the expected 

### 2009 NOx emissions are so close to the 

### 31,000 ton limit, Duke will continue to evaluate options to improve performance, including the addition of SCR on Marshall Unit3and reconsideration of aDan River Unit 3SNCR system. S02 Compliance • New Pulverized Coal (PC) Units
- This 

### 2006 update includes the proposed addition of two new 

### 800 MW coal units in 

### 2011 and 

### 2012 at the Cliffside Steam Station. The 

### 2013 expected compliance plan includes these units along with the associated retirement of Cliffside Units 1-4 if the new units are put in service. • Schedule Changes
- Both the Belews Creek Unit 

### 2and Clfffside Unit 5 FGD (Scrubber) operational dates were adjusted in this plan. The Belews Creek Unit 

### 2 operational date has shifted slightly from the fall of 

### 2007 until early 

### 2008; the Cliffside 5 operational date has shifted out to 

### 2010 to better align with the proposed operational dates forthe new units. • Rate Changes
- Expected rate changes have been adjusted in this 

### 2006 update based on changes to operational dates and other considerations: • The Allen expected rates were adjusted based on the new sequencing of FGD operational dates in 

### 2009; Allen Units 

### 1, 2&5are now expected to be operational in the spring of 

### 2009 and supported by one FGD absorber while Units 

### 4&5 are expected to be operational in the fall of 

### 2009 and supported bythe second FGD absorber. • The Buck rates were adjusted based on the expected use of alowersulfur coal • The Cliffside rates were adjusted based on the expected use of ahigher sulfurcoal and the FGD operational date change for Unit5.
Page22. The actual environmental compliance costs incurred bythe investor-owned public utility in 

### the previous calendar year, including a description of the construction undertaken and completed during that year. In the 2005 calendar year, Duke Power Company spent $346,420,000 on activities in support of compliance with the provisions of G.S. 143-215.1070. Exact amounts associated with each project are provided in Exhibit C, and a description of the associated activities is provided below: Allen Steam Station FGD • Initiated Phase II portion of project including preliminary engineering, project scope development, plant interlace studies, contract exhibits and project estimates Belews Creek Steam Station FGD • Executed the Engineering, Procurement and Construction (EPC) agreement with the Consortium of ALSTOM Power Inc. and Shaw/Stone & Webster (Aistom/Shaw) • Mobilized the project's construction management team to the Belews Creek site and initiated construction activities • Completed the installation of a new fuel oil tank and the removal of the existing fuel oil and elevated waterstorage tanks from the area planned for the main portions ofthe FGD system • Removed the existing hill from the area planned for the main portions of the FGD system (approximately300,000 cubic yards of soil and rock) • Initiated construction ofthe majorfoundations forthe FGD system • Completed approximately 20% of the overall project (approximately 10% of the construction activities) Cliffside Steam Station Unit5 FGD • Continued preliminary construction planning and development of conceptual site layout Marshall Steam Station FGD • Completed fabrication and installation of absorberoutlet ducts and flue liners • Completed site earthworkfor gypsum landfill, wetlands (including plantings) • Completed all remaining major building and equipment foundations including wetlands equalization basin, transformers, switchgearand major tanks • Completed structural steel erection for absorber, reagent prep, dewatering buildings, transfer towers 1 &2, limestone unloading & stackout, and duct support sections 1through 11 • Completed assembly of ball mills, absorber recycle pumps, hydrocyclones, dewatering belt filters, limestone unloading and majorfield-erected tanks • Completed installation of underground piping, above group piping systems and makeup water station tie·ins

Page 3• Completed majority of transformers setting, switchgear and underground ductbankwork • Completed majority of material handing equipment installation • Completed erection of all wastewater treatment tanks and sludge press building Allen Steam Station SNCR, Unit 2 • Completed preliminary engineering Allen Steam Station SNCR, Unit3 • Completed installation of Unit 3 SNCR equipment and supporting plant air equipment Allen Steam Station SNCR, Unit 4 • Completed detailed engineering and received mechanical, electrical and installation drawings • Procured material in preparation for2006 installation Allen Steam Station SNCR. Unit 5 • Completed preliminary engineering Buck Steam Station SNCR. Unit 5 • Completed preliminary engineering Buck Steam Station SNCR, Unit 6 • Completed preliminaryengineering Dan River Steam Station Burners. Unit 2 • Completed detailed engineering and material procurement in preparation for 2006 installation Dan River Steam Station Classifiers. Unit 2 • Completed installation of advanced static classifiertechnology in fall of2005 Dan River Steam Station Burners, Unit 3 • Completed detailed engineering and material procurement in preparation for 2006 installation Dan River Steam Station Classifiers, Unit 3 • Completed installation of advanced static classifiertechnology in fall of 2005 Marshall Steam Station SNCR, Unit 1 • Completed detailed engineering and received mechanical, electrical and installation drawings • Procured material in preparation for 2006 installation

Page4Marshall Steam Station SNCR, Unit 2 • Completed preliminary engineering Marshall Steam Station SNCR, Unit 3 • Completed installation of SNCR equipment Marshall Steam Station SNCR, Unit 4 • Continued preliminary engineering and planning for project Riverbend Steam Station SNCR, Unit 4 • Completed preliminary engineering Riverbend Steam Station Burners, Unit 5 • Incurred final costs associated with project to install burners on unit in early 2005 Riverbend Steam Station SNCR, Unit 5 • Completed preliminary engineering Riverbend Steam Station Burners, Unit 6 • Completed installation of SOFA technology on unit in spring of2005 Riverbend Steam Station Classifiers, Unit 6 • Completed installation of advanced static classifier technology in spring of 2005 Riverbend Steam Station SNCR, Unit 6 • Completed preliminary engineering Riverbend Steam Station SNCR, Unit 7 • Completed preliminary engineering 3. The amount of the investor-owned public utility's environmental compliance costs amortized in the previous calendar

### year. In the 2005 calendaryear, $311,236,000 was amortized related to construction work activity in support of compliance with the provisions of G.S. 143·215.1070. $637,429,142 in total has now been amortized forthe program through year-end 2005. 4. An estimate of the investor-owned public utility's environmental compliance costs and the basis for any revisions of those estimates when compared to the estimates submitted during the previous year. The estimated 'environmental compliance costs' as defined in G.S. 143-215.1070 are provided in Exhibit C. Changes to the expected costs as compared to past compliance plans are highlighted in this exhibit and described below:
Page 5• Allen FGD Project- The Allen FGD estimate has increased since 2005 and is attributable to ramp up in the power generation and/or environmental retrofit construction market, and continued escalation oflabor costs. The Cliffside 5 FGD estimate is also affected by these issues, but is expected to be offset by savings if this project is executed in conjunction with the proposed construction ofnew generating units at the Cliffside station. • SNCR Projects
- In addition to the deletion of the Dan River Unit 3 SNCR project, refinement ofthe SNCR work scope at each location has resulted in a lower overall estimated cost. The most significant change to this scope over the last year has been to remove the Riverbend central reagent (urea) distribution center scope of work and replace with individual station storage and dilution waterequipment. • Dan River Unit 3 Burner Project
- The Dan River Unit 3 Burner project experienced some costs increases estimated at $470,000 due to the delay in installation discussed above. 5. Adescription of all permits required in order to comply with the provisions of G.S. 143- 215.1070 for which the investor-owned public utility has applied and the status of those permits or permit applications. Belews Creek Steam Station FGD • NPDES Permit Modification- Submitted 6/30/04; received 5/16/05 • Initial Erosion Control Permit- Submitted 2/4/05;.received 3/7/05 • Landfill Site SuitabilityApplication
- Submitted 3/30/05; expect Site Suitability by Apri/2006 • Air PermitApplication for Belews Creek FGD project- Submitted 4/18/05; received 2/6/06 • Request to revise NPDES Permit to include FGD wastewater- Submitted 6/30/04; received permit revision 5/16/05 • Authorization to Construct (ATC) application forWastewaterTreatment System- Submitted 7/21/05; received 12/27/05 • Authorization to Construct (ATC) application forConstructed WetlandsSubmitted 7/21/05; expect final permitApri/2006 • Revised Landfill Construction Plan Application- Submitted 9/30/05; expect permitJuly 2006 • Air Permit- Notice ofIntentto Construct- Submitted 10/11/05; received 10/24/05 • NOTE: Revisions to Erosion Control Permit submitted on various dates; most recent revised permit received 12/20/05

Page 6Cliffside Steam Station Unit 5FGD • Air Permit Application
- Submitted 

### 12/16/05 • NOTE: Acomplimentary PSD permit application was submitted on this same 

### 12/16/05 date for the proposed new generating units at the Cliffside site. If this associated PSD air permit is not approved orwithdrawn, itwill be necessaryto**subm~** arevised Air Penni! Application for astandalone Unit 

### 5 FGD. Marshall Steam Station FGD • Landfill Construction Plan Application- Submitted 

### 4/1/04; received 

### 2/4/05 • Sedimentation and Erosion Control Plan Permits • Limestone/Gypsum Conveyor- Submitted 

### 6/17/04; received 

### 7/9/04 • Limestone/Gypsum Conveyor Expansion
- Submitted 

### 12/15/04; received 

### 12/30/04 • Constructed Wetland Treatment System- Submitted 

### 7/26/04; received 

### 8/18/04 • Gypsum Landfill- Submitted 

### 3/31/04; received 

### 4/21/04 • Authorization to Construct (ATC) application forSolids Removal System
- Submitted 

### 11/19/04; received 

### 12/22/04 • Authorization to Construct (ATC) application for Constructed Wetlands
- Submitted 

### 5/21/04; received 

### 8/10/04

.Allen Steam Station SNCR. Unit 3 • Air Penni! Application
- Submitted 

### 7/15/04; Received 

### 2/5/05 Allen Steam Station SNCR. Unit 4 • Air Permit Application
- Submitted 

### 7/15/05; Received 

### 1/15/06 Marshall Steam Station SNCR. Unit 1 • Air Penni! Application- Submitted 

### 9/18/05; Received 

### 12/20/05 Marshall Steam Station SNCR.**Un~** 2 • Air Permit Application
- Submitted 

### 9/18/05; Received 

### 12/20/05 Marshall Steam Station SNCR. Unit 3 • Air Penni!Application- Submitted 

### 5/14/04; Received 

### 10/13/04 Riverbend Steam Station SNCR, Unit 4 • Air Permit Application
- Submitted 

### 3/20/05; Received 

### 811/05 Riverbend Steam Station Burners. Unit 5 • Air PermitApplication- Submitted 

### 4/2/04; Received 

### 4/30/04 Riverbend Steam Station SNCR, Unit 5 • Air Permit Application- Submitted 

### 3/20/05; Received 

### 811/05

Page 7Riverbend Steam Station Burners, Unit 6 • Air Permit Application- Submitted 5/14/03; Received September2003 Riverbend Steam Station SNCR, Unit 6 • Air PermitApplication- Submitted 11/5/05; Received 1/1/06 Riverbend Steam Station SNCR, Unit 7 • Air PermitApplication- Submitted 11/5/05; Received 1/1/06 6. Adescription of the construction related to compliance with the provisions of G.S. 143- 215.1070 that is anticipated during the following year. Allen Steam Station FGD • Finalize EPC agreement wtth theAlstom/Shaw consortium • Relocate existing plant services including ash sluice lines, diesel oil tank, electrical and potable water lines • Relocate existing rail spurs and switches • Construct new FGD entrance road from state highway • Begin earthworkand grading for project, including initial site clearing • Begin installation of piles and foundations • Install new ductworktie-ins to Unit 2 Belews Creek Steam Station FGD • Complete the construction ofthe majorfoundations forthe FGD system • Complete the construction ofthe concrete shell for the two new chimneys • Complete all construction on approximately 5% ofthe sub-systems that make up the total FGD system • Complete construction ofthe Constructed Wetlands (part ofthe wastewater treatment system) • Initiate commissioning activities on the completed sub-systems ofthe total FGD system • Achieve acompletion status of 75% on the overall project (65% of construction activities) Cliffside Steam Station Unit 5FGD • Continue engineering studyto finalize the project scope, funding and implementation schedule Marshall Steam Station FGD • Mobilize large crane forductwork installation • Complete initial tie-in ofthe Unit 4ductwork and install blanking plate • Complete ductwork installation using large crane • Complete construction, turnover and commissioning of Unit 4and common systems

Page 8• Complete final tie-in of the Unit 4ductwork and removal of blanking plate • Begin testing and tuning of Unit 4and common systems • Achieve Substantial Completion lor Unit4and common systems • Complete initial tie-in of the Unit 3ductwork and install blanking plate • Complete construction, turnover and commissioning of Unit 3systems • Complete final tie-in of the Unit 3ductwork and removal of blanking plate • Begin testing and tuning of Unit 3and common systems • Achieve Substantial Completion for Unit 3systems Allen Steam Station SNCR, Unit 2 • Complete detailed engineering for SNCR equipment and reagent storage • Begin material procurement activities in support of installation in early 2007 • Complete procurement and construction of reagent storage equipment Allen Steam Station SNCR. Unit 4 • Complete installation of SNCR equipment, including incremental compressed air and dilution water systems, in time to support 2006 ozone season operation Allen Steam Station SNCR. Unit 5 • No significant activity expected in 2006 Buck Steam Station Burners, Unit 3 • Complete detailed engineering and material procurement activities in support of installation in early2007 Buck Steam Station Classifiers. Unit 3 • No significant activity expected in 2006 Buck Steam Station Burners, Unit 4 • Complete detailed engineering and material procurement activities in support of installation in early 2007 Buck Steam Station Classifiers. Unit 4 • No significant activity expected in 2006 Buck Steam Station SNCR, Unit 5 • Complete detailed engineering and material procurement activities in support of installation in late 2006 • Substantially complete installation of SNCR equipment including incremental air, dilution water and storage needs in time to support 2007 operation

Page 9Buck Steam Station SNCR, Unit 6
o Complete detailed engineering and material procurement activities in support of installation in late 2006
o Substantially complete installation of SNCR equipment including incremental air, dilution waterand storage needs in time to support 2007 operation Dan River Steam Station Burners, Unit 1
o No significant activity expected in 2006 Dan River Steam Station Burners, Unit 2 • Substantially complete installation of burners Dan River Steam Station Burners, Unit 3 • Substantially complete installation of burners Marshall Steam Station SNCR, Unit 1 • Complete installation of SNCR equipment in time to support 2006 ozone season operation Marshall Steam Station SNCR. Unit 2 • Completedetailed engineering for SNCR equipment and reagent storage • Begin material procurement activities in support of installation in early2007 • Complete procurementand construction of reagentstorage equipment Marshall Steam Station SNCR. Unit4 • Complete detailed engineering for SNCR equipment • Begin material procurement activities in support of installation in early 2007 Riverbend Steam Station SNCR. Unit 4 • Complete detailed engineering for SNCR equipment • Begin material procurement activities in support of installation in early 2007 Riverbend Steam Station SNCR. Unit 5 • Complete detailed engineering for SNCR equipment • Begin material procurement activities in support of installation in late 2007 Riverbend Steam Station SNCR. Unit 6 • Complete detailed engineering and material procurement activities in support of installation in late 2006 • Substantiallycomplete installation of SNCR equipment including reagent storage needs in time to support2007 operation

Page 10Riverbend Steam Station SNCR, Unit 7 • Complete detailed engineering and material procurement activities in support of installation in late 

### 2006 • Substantially complete installation of SNCR equipment including incremental airand dilution water needs in time to support 

### 2007 operation 7. A description of the applications for permits required in order to comply with the provisions of G.S. 

### 143-215.1070 that are anticipated during the following year. Allen Steam Station FGD • Authorization to Construct (ATC) application forWastewaterTreatment System- Plan to submit August

### 2006; expect to receive February 

### 2007 • Air PermitApplication
- Plan to submit April 

### 2006; expect to receive approval July

### 2006 • Request to revise NPDES Permitto include FGD wastewater- Submitted 

### 1/24/2006; expect to receive revision May

### 2006 • Submittal to DENRI ACOE regarding stream crossing ofentrance road
- Plan to submit March 

### 2006 • NOTE: all erosion control permits are in EPC contractor's scope forthe Allen FGD Project Belews Creek Steam Station FGD • Authorization to Construct (ATC) application for Sanitary Waste Lagoon
- Plan to submit March 

### 2006; expect to receive September

### 2006 Cliffside Steam Station Unit 5FGD • NOTE: Acomplimentary PSD permit application was submitted on 

### 12/16/05 for the proposed new generating units at the Cliffside site. Ifthis associated PSD air permit is not approved orwithdrawn, itwill be necessaryto submit a revised Air Permit Application forastandalone Unit 5FGD. This application would be made in the 3rd or

### 4th Quarterof

### 2006. Allen Steam Station SNCR. Unit 2 • Air Permit Application
- Plan to submit July 

### 2006; expect to receive approval January

### 2007 Allen Steam Station SNCR, Unit 4 • Authorization to Construct (ATC) application for the dilution water piping
- Plan to submit to the City of Belmont March 

### 2006 Buck Steam Station Burners, Unit 3 • Air PermitApplication
- Plan to submit March 

### 2006; expect to receive approval February 

### 2007

Page 11Buck Steam Station Burners, Unit 4 • Air PermitApplication- Plan to submit March 2006; expect to receive approval February2007 Buck Steam Station SNCR. Unit 5 • Air PermitApplication- Plan to submit March 2006; expect to receive approval July 2006 Buck Steam Station SNCR. Unit 6 • Air Permit Application
- Plan to submit March 2006; expect to receive approval July2006 Dan RiverSteam Station Burners. Unit 1 • Air PermitApplication
- Submitted 2/23/06; expect to receive approvalAugust 2006 Dan RiverSteam Station Burners, Unit 2 • Air Permit Application
- Submitted 2/23/06; expect to receive approval September2006 Dan River Steam Station Burner Project. Unit3 • Air Permit Application
- Submitted 2/23/06; expect to receive approval September2006 Marshall Steam Station SNCR. Unit 

### 4 • Air Permit Application
- Plan to submit September2006; expect to receive approval January2007 8. The results ofequipment testing related to compliance with G.S. 143·215.1070.
No additional equipment related testing occurred in 2005. The SNCR and SCR tests that occurred in prior years that were used in evaluating technology selections are repeated in this 2006 report for reference. Allen Steam Station SNCR, Unit 1 • SNCR Equipment installation was completed in May 2003 followed by equipment acceptance testing in late 2003. During this test run, it was determined that the SNCR system met all commercial performance guarantees with approximately a25% reduction in NOx with ammonia slip of less than 5ppm at full load • During the 2004 ozone season, Allen Unit 

### 1achieved a0.162# NO,JMMBTU outlet rate, 5% betterthan the 0.17#/MMBTU target established for the unit.

Page 12Belews Creek Steam Station SCR • SCR Equipment installation was completed in 2003 in support ol the EPA/SIP Call requirements lor NO, reduction. While Belews Creek had operational problems in the first hall ol the 2004 ozone season, many ol these issues were addressed on Belews Creek Unit 1 by August, 2004. Subsequently, tests perlonmed during the months ol August and September showed that when the SCR Equipment was in service during this time, emissions averaged 0.07# NOJMMBTU
9. The number of tons of oxides of nitrogen (NO,) and sulfur dioxide 

### (S02) emitted during the previous calendar year from the coal-fired generating units that are subject to the emissions limitations set out in G.S. 143-215.1070. In the 2005 calendaryear, 56,073.3 tons 

## ot NO, and 298,780.5 tons 

## ot SOz were emitted from the North Carolina based Duke Power Company coal-fired units located in North Carolina and subjectto the emissions limitations set out in G.S 143-215.107D. 1

0. The emissions allowances described in G.S. 143·215.107D(i) that are acquired by the investor-owned public utility that result from compliance with the emissions limitations set out in G.S. 143·215.1070. No emissions allowances have been acquired by Duke Power Company resulting from compliance with the emissions limitations set out in G.S. 143-215.107D. 11. Any other information requested by the Commission or Department of Environment and Natural Resources. No additional information has been requested to be included in this annual data submittal.

Page 13I 

### Expected Duke PowerCompany Compliance for NC Clean Air Plan as of4/1/2006 (ExhibitA)
NO.

. . . . '(·< ' '. ,.,,..**/"~'·** '.<··''/'· 

### ·'>'··' ;i '·>7:''i 2007 Facility Unit Technology**~** "u' I Rate Date lftMMtl : s Tons 2009 IRate**Iff~** IMtliUS Tons Allen 1 SNCR 2003 ·.·• j ''• •,lDUf 851 Allen 2 SNCR 2007 · 798

# cE:,~. 

# . ; TunlngOnl '"·"'' :::·\,,

# .<:~:,::

# 360**!~** 58111 1. :··•. ·,'.;' 0
:1501 

# it

Clllfolde 2 Tl 2004 ,. ;**·~: }JI~~~**  • ..3601 26l Cllffolde 3 2004 o.4001 •.4001**5~** Clllfolde _4 2004 0.400 5931 0.4001 53! Clllfolde 5 SCR 2002

..··.·,· '·''. Oc060

### 1,~~!.~.'·•.·.. ,,,. '

### ~**1,~:** Don River 1 Burnero ·.;c·,,· ..2008 · ..,;., 0.370 .,, '•"' ,.., ·. 

## ffiJ" ·- O.n River 2 Burners 2008 ··. ·'' · ··,·. 1.2201 31181.· ·;;,;•.(; !69

llorsholl 2 SNCR 2007 , ' ". ··'0.19()j 2,008f**~;i!-----7~** Marshall 3 SNCR 2005 • '''·"' 0.1901 4,3221 Ol80 (328)

7 SNCR ·<:>i;c2006·· i;.:-1''·· ·....x
... ··, 1.1.501 ;·. 160 57! ITotal:

### ~ :!IIMQ i"'NOTE1- Compllance Limit: ;:; 

# 31:ooo

- NOTE 1

- Becausethe a><pec:ted 2009 NO,omissions n**so~dcl~.;;** ...**~~u;;;J:i,OOOt;;i;i;;i;:o;;i** Duk;'a,1 will;u;;l 1 ccnli;.n

### ;;'i;

...**~;;;;;~..,.p'ti;;;"---...=.:=;..a** improveparfonnance, including SCR on**M~nhall** Unit 3and/orSNCR on Dan River Unit3. Technology: Burners- OvOitiredAirorSep81111e<1OverfiredAiroith "S1i<lfiaaed Mit Classifierins1sllalians SCR

- Selective Catalytic Reduction SNCR

- Selective Non-Catalytic Reduction !Changesfrom 41112005 Plan HighliShted 'iJ 

### I

## Expected Duke Power Company Compliance for NC Clean Air Plan as of

# 4/1/2006 (Exhibit B)

Facility Allen**~len ~len** **~len** Unit 1

Allen 5 Belews Creek 1 Belews Creek 2 Buck 3 Buck 4 luc 5 luc

( 

### . 

### .

# .. Dan River Dan River Dan River 3 4 5
r .. 2 J 1 2 3 4 4 5 6 7 Technology**~.-~·** Q..V •u• ,'**r~:te** Date .cu• 2009 •:•:·.·••. :· : .0.51J!JI 2009 .·' •,:•.v..........•0.5001 2019 ,;•.:. 2019 ••**,.~··**••.• : 2019 : ' :.·.. \,, :,·' •).500 2008 0.150 '.•' ·, ' . ' '', 0,150 ,·•·:<./,•!.MOO ',.,,,,·,,;

..;,, '1:100

. ·,

! • ,.., ,; ·: ,. ,· ' '· '100

; "·'' ' •••.. ,6511 I•: ...·•·:. ·ii' !.6501

# ····~..· .•.•...•,.i••t··ll I ,, .•,:.2010· 

### I·'"'':···:·.:,'· 1.6501 :• ' ' : '·,•.• :•, ,.,,,, "·0.0001 ·•· r·:·:,·:.2012. 

### c··:l·· 

### ····o.ooo

2007 2007 2007 2006 1.400 1.400 1.4001 0.150 0.150 0.150 0.150 1.550 ' 1.51i(l

1.550 1,:,00 Tons 2013(

## ,'r~:te !,6511 0.1501 !,4661 0.150 9,864 0.150 10,746 0.150

,215 0.150 5,927 0.150 

# _4:; IL·' ct:'::i .:" '; ·,4121;':''.'' ,.. ''



### ..<: 170 .; ,·'

. 

# .•**····~0001** 3' ,19 0 150 0

. ••,V·.I (180 2,164 1.400 !,33a 1.400 5,202 1.400 1,952 0.150 Tons 141 721 1,18::**_1.~1** ,21: ' 5,512 ' 4,639

4, Yf

0**_2.7~1** ! 2,240

•!37

33

,940 0.15C 1,5 3,539 0.150 3,5

333 0.150 367 635 1.550 620 J 641 1.550 "**~** i,799 1.550 573a 5._942 

### J·S!iOL 5,891 Compliance

# ~-l.i**0**

.. mta ...

# it**.=:.'------~.:;:. 129** 

# ::.::..L**46**

______

# ~::::1•r.::::::..Jooo I Changes 1rom 4/1/2005 Plan Highlighled :•·

## Expected Duke PowerCompany Compliance Plan for NC Clean Air Plan as of4/1/2006 (Exhibit C)

Spentto D1te

Allen 4 SNCR 2001 iO.O**~0.0 ~0.0**  lf.9**~- ~-**  _41!!2**~~**

Dan River 1 Burner

. ,·•2008•·'••·· $0.0 $0.0 10.0 IO.C**~ ~~** **~-** Dan River 1 $0.0 $0.0 iO. iO.O _:s<JJ]**~ ~**  Dan River 2 Burner 2001_ $0.0 w.u iO. .0 75.4 $1,23L1**~l.~.~** 2
- -···." 2005' .·" •, $0.0 $0,0 i<Jj liJ_**~~** $0.0 • 113 Dan River 3 Burner 2001 17.5 $162.3 $ !2.2 $5 !.8 7!-**~** lo''•.· ;••,;,,,-' , 3 -· -2<IOti J.O oU.U $0.0 $0.0 1184.3 $0.0 118 Marshall 1 SNCR 2001 100 10.0 $0.8 _$16f2**~~ ~**  1.:1::.'::::::!:1**~** Marshall 2 !_NCII_

_**~1-** iO.O 10.0 $197.6 $185.4 $778.3 $5,292.0 1·-£•:. '..' , Marshall 3 SNCR 2005 $0.0 $0.0 $1,577A $652.1**$2~** _!ll:_lJ 1.2:: ··. ·",.· r:!:"_ Mlnoholl 4**~** 2001 iO.O $0. $0.0 $0.1 $43.3 $3,925.0 88.3
: Burner •

# =.'**~ ~~-** **~ $2~** **~ ~'-~**  '''!·; ;.;

### ~ 5 2005 oO.O iO.O 10.0 $159.6 _$()l)

_ _!OJ) o1_59.6 5 SNCR 2008 10.0 iO.O ;o.o $1.5 $321 .7 $3,758. 6 _lill_rn!'_ 2005 $ 140 ..1'16"-**.Ji~ ~** **~ ~** **~ ~**  6 2005 $0.0 $00 10.0 $0.0**~189__c4** !OJ! '1118. 6 SNCR ••'.'- 2006.c •,c•;; $0.0 $0.0 iOO**~ ~-**  $4, 2g;rl---T,**$44~,,1!1ll'r** ••**~9** 1 SNCit ·. · ; 20IIti · '''

_$0,0 _WJ)_ IO_J)_ _148_1>_**~ _>4_~5f~**  _!O,II_.,.ol./ $692.4 $1,024.2 $18,424.9 $106,834.5 $346,420.0 $1,258,114.4 NC-CAP Total. $1,731,510.4 !Significant changes from 41112005 Plan Highlighted
- : ·

### ·1 NO,