a Duke 

illf1Power. 

George T. Everett, Ph.D. 

Director, EIWironmenta!IL.egislativeA.ffairs 

March 30, 2006 

Mr. William G. Ross, Jr., SecretaJy 

North Carolina Department of Environment and Natural Resources 

160 I Mail Service Center 

Raleigh, NC 27699-1601 

Subject: Docket No. E-7, Sub 718 

Duke Power Compliance Plan Annual Update NO. Control 

Record No. NC CAP 005 

Dear Mr. Ross: 

919-235-0955 

gtevereti@duke-energy.com 

Duke Power is required by Senate Bill!078 to file information on or before I April ofeachyearto update the Commission on 

progress to date, upcoming activities and expected strategies to achieve the emissions limitations set out in G.S. 143-215.1070. 

Enclosed for filing are the original and thirty (30) copies of Duke Power's Compliance Plan Annual Update for 2006 that fully 

describe the company's efforts to comply with this clean air legislation. 

The current plan to meet the emission requirements for NOx and SO, includes: 

NO, Control- The installation of Selective Catalytic Reduction (SCR) on Cliffside Steam Station Unit 5 and Belews 

Creek Steam Station Units 1&2 bas been completed. Our NOx plans include installation of Selective Non-catalytic 

Reduction (SNCR) at 15 units, and burner work at our remaining sites with the. exception of Cliffside Units 1-4. With 

these installations, Duke can demonstrate compliance with our 2007 and 2009 NOx caps under Senate Bill 1078. 

SO, Control - The installation of wet scrubbers on our twelve largest generating units continues to be our plan. 

We have worked with the Department of Environment and Natural Resources on a plan to accelerate the scrubber 

installation schedule at Plant Allen. Acceleration of the Allen scrubbers maintains our design and construction 

continuity and helps assure Duke Power can meet the recently finalized Clean Air Interstate Rule. Costs for our 

scrubber projects have gone up at Plant Allen due to increases in material (steel and petroleum-based products) and. 

labor costs. Explanations for these increases have been shared with the Public Staff. 

Exhibits A and B outline current unit specific technology selections, projected operational dates, expected emission rates, and 

the corresponding tons of emissions that demonstrate compliance with the legislative requirements to the best of Duke Power's 

knowledge at this time. The projected estimates of 'environmental compliance costs' for these pollution control projects are 

included in Exhibit C. 

Duke Power will continue to examine the technology selection, implementation schedule and associated costs. Annnal updates 

will be · ded to the NC Utilities Conunission as required. If you have questions regarding any aspect of our plan, please do 

to contact my office at 9 I 9-235-0955. 

Director, 

_..e T ... 

En~~ntal!Legislative 

_<-"Ev~ere~.f' ~ Affairs 

Duke Power 

Enclosures 

cc: B. Keith Overcash, Director 

North Carolina Division of Air Quality 

1641 Mail Service Center 

Raleigh, NC 27699-1641 

rn ~&mow~ 

APit'- 5 2m- ill 

AIR guAUTY 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. A detailed report on the investor-owned public utility's plans for meeting the emissions 

limitations set out in G.S. 143-215.1070. 

Exhibits A and B outline 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 of the expected high cost to install and operate a single 

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 per year. 

• The Buck Unit 5 SNCR project was accelerated to the fall of 2006 to better 

align with the Buck Unit 6 SNCR schedule and allow for the 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 4 SNCR project was accelerated to the spring of 2007 

for outage optimization and to better support compliance with the Phase I 

cap of 35,000 tons per year. 

• The Riverbend Units 6& 7 SNCR projects were accelerated to the fall of 

2006 for outage 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 a result 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 of the 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 of the burner equipment, the bumer outage schedule and the 

deletion of the SNCR equipment. 

• The Marshall Unit 2 expected rate changed due to the timing of the 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 of the SNCR equipment. 

• The Riverbend expected rates were adjusted based on the SNCR 

installation schedule changes and lower SNCR equipment guarantees. 

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 Unit 3 and reconsideration of a Dan River Unit 3 SNCR 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 2 and 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 for the 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 & 5 are 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 by the second FGD absorber. 

• The Buck rates were adjusted based on the expected use of a lower sulfur 

coal 

• The Cliffside rates were adjusted based on the expected use of a higher 

sulfur coal and the FGD operational date change for Unit 5. 

Page2 
2. The actual environmental compliance costs incurred by the 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 water storage tanks from the area planned for the 

main portions of the FGD system 

• Removed the existing hill from the area planned for the main portions of the 

FGD system (approximately 300,000 cubic yards of soil and rock) 

• Initiated construction of the major foundations for the FGD system 

• Completed approximately 20% of the overall project (approximately 10% of 

the construction activities) 

Cliffside Steam Station Unit 5 FGD 

• Continued preliminary construction planning and development of conceptual 

site layout 

Marshall Steam Station FGD 

• Completed fabrication and installation of absorber outlet ducts and flue liners 

• Completed site earthwork for gypsum landfill, wetlands (including plantings) 

• Completed all remaining major building and equipment foundations including 

wetlands equalization basin, transformers, switchgear and major tanks 

• Completed structural steel erection for absorber, reagent prep, dewatering 

buildings, transfer towers 1 &2, limestone unloading & stack out, and duct 

support sections 1 through 11 

• Completed assembly of ball mills, absorber recycle pumps, hydrocyclones, 

dewatering belt filters, limestone unloading and major field-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 

d uctban k work 

• 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, Unit 3 

• 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 for 2006 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 preliminary engineering 

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 classifier technology in fall of 2005 

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 classifier technology 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 

Page4 
Marshall 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 of 2005 

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 calendar year, $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 for the 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 of labor 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 of new generating units at the Cliffside station. 

• SNCR Projects - In addition to the deletion of the Dan River Unit 3 SNCR 

project, refinement of the 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 water equipment. 

• 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. A description 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 Suitability Application - Submitted 3/30/05; expect Site Suitability 

by Apri/2006 

• Air Permit Application 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 for Wastewater Treatment 

System- Submitted 7/21/05; received 12/27/05 

• Authorization to Construct (ATC) application for Constructed WetlandsSubmitted 7/21/05; expect final permit Apri/2006 

• Revised Landfill Construction Plan Application- Submitted 9/30/05; expect 

permit July 2006 

• Air Permit- Notice of Intent to 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 6 
Cliffside Steam Station Unit 5 FGD 

• Air Permit Application - Submitted 12/16/05 

• NOTE: A complimentary 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 or withdrawn, it will be 

necessary to subm~ a revised Air Penni! Application for a standalone 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 for Solids 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 Permit Application- 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 7 
Riverbend Steam Station Burners, Unit 6 

• Air Permit Application- Submitted 5/14/03; Received September 2003 

Riverbend Steam Station SNCR, Unit 6 

• Air Permit Application- Submitted 11/5/05; Received 1/1/06 

Riverbend Steam Station SNCR, Unit 7 

• Air Permit Application- Submitted 11/5/05; Received 1/1/06 

6. A description 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 the Alstom/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 earthwork and grading for project, including initial site clearing 

• Begin installation of piles and foundations 

• Install new ductwork tie-ins to Unit 2 

Belews Creek Steam Station FGD 

• Complete the construction of the major foundations for the FGD system 

• Complete the construction of the concrete shell for the two new chimneys 

• Complete all construction on approximately 5% of the sub-systems that make 

up the total FGD system 

• Complete construction of the Constructed Wetlands (part of the wastewater 

treatment system) 

• Initiate commissioning activities on the completed sub-systems of the total 

FGD system 

• Achieve a completion status of 75% on the overall project (65% of 

construction activities) 

Cliffside Steam Station Unit 5 FGD 

• Continue engineering study to finalize the project scope, funding and 

implementation schedule 

Marshall Steam Station FGD 

• Mobilize large crane for ductwork installation 

• Complete initial tie-in of the Unit 4 ductwork and install blanking plate 

• Complete ductwork installation using large crane 

• Complete construction, turnover and commissioning of Unit 4 and common 

systems 

Page 8 
• Complete final tie-in of the Unit 4 ductwork and removal of blanking plate 

• Begin testing and tuning of Unit 4 and common systems 

• Achieve Substantial Completion lor Unit 4 and common systems 

• Complete initial tie-in of the Unit 3 ductwork and install blanking plate 

• Complete construction, turnover and commissioning of Unit 3 systems 

• Complete final tie-in of the Unit 3 ductwork and removal of blanking plate 

• Begin testing and tuning of Unit 3 and common systems 

• Achieve Substantial Completion for Unit 3 systems 

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 early 2007 

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 9 
Buck 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 water and 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 

• 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 

Marshall 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 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 

• Substantially complete installation of SNCR equipment including reagent 

storage needs in time to support 2007 operation 

Page 10 
Riverbend 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 

air and 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 for Wastewater Treatment 

System-Plan to submit August 2006; expect to receive February 2007 

• Air Permit Application - Plan to submit April 2006; expect to receive approval 

July 2006 

• Request to revise NPDES Permit to include FGD wastewater- Submitted 

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

• Submittal to DENRI ACOE regarding stream crossing of entrance road - Plan 

to submit March 2006 

• NOTE: all erosion control permits are in EPC contractor's scope for the 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 5 FGD 

• NOTE: A complimentary PSD permit application was submitted on 12/16/05 

for the proposed new generating units at the Cliffside site. If this associated 

PSD air permit is not approved or withdrawn, it will be necessary to submit a 

revised Air Permit Application for a standalone Unit 5 FGD. This application 

would be made in the 3rd or 4th Quarter of 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 Permit Application - Plan to submit March 2006; expect to receive 

approval February 2007 

Page 11 
Buck Steam Station Burners, Unit 4 

• Air Permit Application- Plan to submit March 2006; expect to receive 

approval February 2007 

Buck Steam Station SNCR. Unit 5 

• Air Permit Application- 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 July 2006 

Dan River Steam Station Burners. Unit 1 

• Air Permit Application - Submitted 2/23/06; expect to receive approval August 

2006 

Dan River Steam Station Burners, Unit 2 

• Air Permit Application - Submitted 2/23/06; expect to receive approval 

September 2006 

Dan River Steam Station Burner Project. Unit 3 

• Air Permit Application - Submitted 2/23/06; expect to receive approval 

September 2006 

Marshall Steam Station SNCR. Unit 4 

• Air Permit Application - Plan to submit September 2006; expect to receive 

approval January 2007 

8. The results of equipment testing related to compliance with G.S. 143·215.1 070. 

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 a 25% reduction in NOx with ammonia slip of 

less than 5 ppm at full load 

• During the 2004 ozone season, Allen Unit 1 achieved a 0.162# NO,JMMBTU 

outlet rate, 5% better than the 0.17#/MMBTU target established for the unit. 

Page 12 
Belews 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 calendar year, 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 

subject to the emissions limitations set out in G.S 143-215.107D. 

1 0. The emissions allowances described in G.S. 143·215.1 07D(i) that are acquired by the 

investor-owned public utility that result from compliance with the emissions limitations 

set out in G.S. 143·215.1 070. 

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 13 
I 

Expected Duke Power Company Compliance for NC Clean Air Plan as of 4/1/2006 

(Exhibit A) 

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

:

150

1 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! 

I Total: ~ :!IIMQ i"'NOTE1-

Compllance Limit: ;:; 31 :ooo - NOTE 1 - Because the 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 

improve parfonnance, including SCR on M~nhall Unit 3 and/or SNCR on Dan River Unit 3. 

Technology: 

Burners- OvOitiredAir or Sep81111e<1 Overfired Airoith "S1i<lfiaaed Mit Classifier ins1sllalians 

SCR - Selective Catalytic Reduction 

SNCR - Selective Non-Catalytic Reduction 

!Changes from 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:; I L·' 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.i0 .. mta ... it.=:.'------~.:;:. 129::.::..L

46 

______ ~::::1•r.::::::..Jooo I Changes 1rom 4/1/2005 Plan Highlighled : • · 
Expected Duke Power Company Compliance Plan for NC Clean Air Plan as of 4/1/2006 

(Exhibit C) 

Spent to 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,