# Oklahoma Gas & Electric

Sooner Units 1 & 2, Muskogee Units 4 & 5

Dry FGD BART Analysis Follow-Up Report

Prepared by: Sargent & Lundy LLC

Chicago, Illinois



# December 28, 2009

# Oklahoma Gas & Electric December 28, 2009

BART Analysis Follow-Up Report Project No. 11418-019

TOC-1 

# Table of Contents

Page

Table of Contents 1

1.0 INTRODUCTION 1

2.0 2009 COST ESTIMATES AND COST EFFECTIVNESS UPDATE 4

2.1 2009 Conceptual Capital Cost Estimate 4



# 2.2 Methodology for Developing the Conceptual Cost Estimate 5



# 2.3 Comparison between 2008 and 2009 Cost Estimates 6



# 2.4 Updated Total Annual Costs and Cost Effectiveness 7



# 2.4.1 Capital Costs 8

2.4.2 Operating Costs 9

2.4.3 2009 Cost Effectiveness 11

2.5 Comparison of 2009 Capital Costs against Ot her Published Capital Cost Information 16



# 2.5.1 Colorado Department of Public Health and Environment Report 16

2.5.3 “Update: What’s That Scrubber Going to Cost” article 18

3.0 BART Report Comparisons 19

3.1 Comparison of Baseline SO 2 

# Emissions 19



# 3.2 Comparison of Modeled Visibility Improvement 20



# 4.0 Conclusions 23

# Oklahoma Gas & Electric December 28, 2009

BART Analysis Follow-Up Report (Rev. 1) Project No. 11418-019

Page 1 

# 1.0 INTRODUCTION

In spring 2008, S&L completed Best Availabl e Retrofit Technology (BART) evaluations for

Sooner Units 1 & 2, Muskogee Units 4 & 5, and Seminole Units 1, 2, & 3. The BART

evaluations included an analysis of potentially feasible retrofit emission control technologies to

control emissions of nitrogen oxide (NO X 

# ), sulfur dioxide (SO 2 

# ), and particulate matter (PM 10 

# )

from each unit. BART evaluations included in the 2008 reports followed the five-step BART

determination process described in Appendix Y to 40 CFR Part 51 “Guidelines for BART

Determinations under the Regional Haze Rule.” The five-step BART determination process

includes:

Step 1: Identify all available retrofit control technologies;

Step 2: Eliminate technically infeasible options;

Step 3: Evaluate the control effectiveness of the remaining control options;

Step 4: Evaluate impacts and document the results; and

Step 5: Evaluate visibility impacts.

Step 4 of the process involves an evaluation of th e potential environmental, energy, and economic

impacts to the facility associated with the inst allation and operation of the technically feasible

retrofit control options. To address economic imp acts, S&L prepared a cost estimate for each

technically feasible retrofit control option. To the extent possible, cost estimating methodologies

described in the Office of Air Quality Planni ng and Standards Cost Control Manual (“OAQPS

Cost Manual”) were used to estimate annual costs. Cost estimates were used to evaluate the cost

effectiveness of each technology in terms of a nnual dollars per ton of pollutant removed.

On November 13, 2009, the State of Oklahoma published its draft Regiona l Haze Implementation

Plan Revision (“Regional Haze Implementation Plan”). The draft implementation plan required

OG&E to control SO 2 

# emissions from Sooner Units 1 & 2 and Muskogee Units 3 & 4 with dry

flue gas desulfurization (DFGD) control systems as BART. In the draft implementation plan, the

Oklahoma Department of Environmental Quality (D EQ) questioned the cost estimates included in

OG&E’s 2008 BART evaluation, stating “OG&E’s esti mated costs were found to be substantially

higher than those reported for similar projects.” DEQ based its BART determination on revised

cost estimates, both capital and operating and main tenance (O&M) costs, as well as a revised cost

effectiveness evaluation.

# Oklahoma Gas & Electric December 28, 2009

BART Analysis Follow-Up Report (Rev. 1) Project No. 11418-019

Page 2 

# Specifically, DEQ questioned the following items in the OG&E DFGD cost estimates:

a) The higher than expected DFGD capital co sts when compared to other sources of

information and the availability of back up information to support the cost estimates.

b) The high cost effectiveness ($9,625 to $10,843 $/ton) compared to other BART evaluations.

c) What the 2009 capital costs would be considering costs likely peaked in 2008 around the

time of the original BART report and have likely fallen since then.

d) The accuracy of using factors from the EPA Ai r Pollution Control Cost Manual to develop

annual operating costs given the large escalation in capital costs over the last few years.

The economic impact analysis included in the 2008 OG&E BART determinations calculated the

cost effectiveness of DFGD control technology for Sooner Units 1 & 2 and Muskogee Units 4 &

5 on a dollar per ton of pollutant removed basis. Annual costs were calculated by adding annual

operation and maintenance (O&M) costs to the annualized capital cost of a DFGD control

system. To the extent possible, methodologies d escribed in the OAQPS Cost Manual were used

to estimate capital and O&M costs. Cost effec tiveness ($/ton) of a DFGD was calculated by

dividing the total annual cost ($/yr) by the reduction in annual emissions (ton/yr).

In addition to comments from DE Q, on December 4, 2009, the U.S. Department of the Interior,

U.S. Fish and Wildlife Service (FWS), in cons ultation with the National Park Service (NPS)

submitted comments to DEQ regarding the draft Regional Haze Implementation Plan. FWS/NPS

agreed with DEQ that costs presented by OG&E for SO 2 

# control were excessive. To respond to

DEQ and FWS/NPS questions and conc erns, S&L prepared the following:

a) Updated 2009 Conceptual Capital Cost Estimates

The original 2008 BART report capital cost est imates were study type +/-30% estimates

based primarily on conceptual cost estimates pr epared for similar projects that were scaled

to account for major differences. The 2009 c onceptual capital cost estimates (included

herein) for all four OG&E coal fired BART-a pplicable units (i.e., Sooner Units 1 & 2 and

Muskogee Units 4 & 5) are based on project-specific vendor quotations for certain major

equipment items and inputs developed by perform ing preliminary project engineering. The

2009 conceptual capital cost estimates are in the +/-20% accuracy range. A comparison of

the revised capital cost estimates against th e sources cited by DEQ in the draft Regional

Haze Implementation Plan is also included. The draft schedule included in Attachment A,

assumes the Muskogee work will take place afte r the Sooner work; therefore, the Muskogee

cost estimate has additional escalation costs included.

# Oklahoma Gas & Electric December 28, 2009

BART Analysis Follow-Up Report (Rev. 1) Project No. 11418-019

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# b) Operating Cost Estimates

Operating costs included in the original 2008 BART report were primarily based on default

factors taken from the OAQPS Cost Manual a nd U.S.EPA’s Coal Utility Environmental

Cost (CUECost) model. Updated operating cost s included in this report were developed by

S&L using OG&E supplied tax, wage, financial, and insurance information, as well as

industry standards and vendor quotations.

c) Updated Cost Effectiveness Estimates

The updated conceptual capital cost and opera ting cost estimates were used to calculate

revised cost effectiveness estimates.

d) Alternative Methods for Calcul ating Reductions in Annual Emissions and Visibility Impacts

FWS/NPS also questioned the methodology u sed by OG&E to calculate the amount of

pollutant removed with DFGD controls. Th e amount of pollutant removed (tons/year)

has a direct effect on the cost effectivene ss of the pollution control system. To address

the FWS/NPS comments, emission reductions from each of the OG&E units were

calculated based on using two different base line emission rates and three different post

DFGD emission rates. This was done to s how the effect on the cost effectiveness

calculations, and to “envelope” the cost effec tiveness calculations. Cost effectiveness in

terms of modeled visibility improvements at affected Class I Areas ($/dV) were also

revised to reflect the updated cost estimates.

e) Comparison against BART submittals from similar projects

Results of the OG&E BART cost effectiven ess impacts ($/ton and $/dV) are compared

against impacts reported in other BART evaluations.

# Oklahoma Gas & Electric December 28, 2009

BART Analysis Follow-Up Report (Rev. 1) Project No. 11418-019

Page 4 

# 2.0 2009 COST ESTIMATES AND COST EFFECTIVNESS UPDATE

2.1 2009 CONCEPTUAL CAPITAL COST ESTIMATE

The 2009 conceptual capital cost estimate and supporting information for all four OG&E coalfired BART-applicable units are included in Att achment A. Table 1 provides a summary of the

Sooner and Muskogee 2009 conceptual capital cost es timates. Cost estimat es were prepared for

each generating station, and divided evenly between the generating units.

Table 1

2009 Capital Cost Estimates

Item Sooner Unit 1 or Unit 2

2009 Cost Estimate Muskogee Unit 4 or Unit 5

2009 Cost Estimate

Direct Costs $162,651,000 $167,572,100

Indirect Costs $24,045,000 $24,801,000

Escalation $23,301,000 $31,638,600

Sales Tax $0 $0

Contingency $29,337,000 $31,552,100

AFUDC & Bond Costs $52,960,000 $61,629,800

TOTAL CAPITAL COST $292,294,000 $317,193,600

Cost Per kw (gross) $514 $555



# The conceptual cost estimates provided in Attach ment A take into account the retrofit difficulty

that can be expected from the existing site configur ations. In degree of difficulty, the retrofits at

Sooner and Muskogee could be described as average.

At Sooner, the new DFGD locations are relativel y clear but Unit 1 is tightly bounded on the east

side by two coal conveyors that supply both units and on the west by high voltage ductbank, ash

piping, and circulating water piping. This existing equipment creates a narrow construction

corridor for installing the DFGD equipment. As a result, the Sooner DFGD has a long narrow

configuration with relatively long ductwork runs. There is also some ash piping and supports

near the existing chimney and ID fans that woul d have to be relocated to accommodate the new

ductwork. The existing storm sewer system in th e new DFGD area would have to be completely

removed and reinstalled to accommodate the new equipment foundations. A main east-west

underground piping run also goes through the new DFGD area and would have to be relocated.

These site-specific retrofit challenges, including equipment relocations, have been taken into

consideration in the Sooner conceptual cost estimate.

# Oklahoma Gas & Electric December 28, 2009

BART Analysis Follow-Up Report (Rev. 1) Project No. 11418-019

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# At Muskogee, the new DFGD locations are also relatively clear except for a coal conveyor

running in the east-west direction that supplies both units. This conveyor is only 330’ north of

the Unit 4 and 5 chimneys and results in the new baghouses and ID booste r fans being located

north of the conveyor. Thus the new ductwork is required to straddle the conveyor and associated

access road which creates longer than normal ductw ork runs and piperacks. Another retrofit

difficulty is the proximity of the existing ID fans to the chimney. In their current location, it’s not

possible to modify the ID fan outlet ductwork to su pply the new SDAs. As a result, the ID fans

will have to be relocated during the tie-in out age as indicated on the Muskogee GA drawings.

Like Sooner, the existing storm sewer system in th e DFGD area would also have to be completely

removed and reinstalled to accommodate the new equipment foundations. These equipment

relocations have been taken into consideration in the Muskogee conceptual cost estimate.

2.2 METHODOLOGY FOR DEVELOPING THE CONCEPTUAL COST ESTIMATE

S&L developed the 2009 capital cost estim ates using the following methodology:

• Plant design data were used to develop datash eets to specify the dry FGD, baghouse, and ID

booster fan operating conditions. The datasheets were issued to various manufacturers to

obtain budgetary quotations. Costs obtained fro m these quotations were used to derive the

pricing used in the capital cost estimate. The cost development for the spray dryer absorbers

and baghouse used in the estimate is described in Attachment A.

• A general arrangement (GA) drawing was deve loped using the information received in the

budgetary quotations. The GA drawing was u sed to estimate the major installation

quantities for the project including ductwork, structural steel, foundations, relocations,

cable, and pipelines.

• A motor list was assembled and used to deve lop the auxiliary power system sizing and

quantities.

• Mass balances were prepared and used to size the flue gas, material handling, material

storage, and piping systems.

• A schedule was developed to estimate escalation and AFUDC costs. It was assumed the

new DFGDs would come on line at six month intervals with the last unit being completed at

Muskogee near the end of 2015.

• Range estimating techniques were used to iden tify the appropriate amount of contingency to

obtain a 95% confidence level. The c ontingency level was approximately 14%.

• A design and cost basis document was prepar ed to document the major assumptions and

inputs for developing the cost estimate.

# Oklahoma Gas & Electric December 28, 2009

BART Analysis Follow-Up Report (Rev. 1) Project No. 11418-019

Page 6 

# • Labor cost estimates were developed usi ng Oklahoma area wage rates, installation

quantities, and installation rates taken from the S&L database.

This methodology provides a conceptual capital co st estimate with accuracy in the range of

±20%. This methodology provides a better estimate of the capital costs asso ciated with installing

DFGD control systems, and a more accurate estimat e of the actual costs that OG&E would incur

to install DFGD at the Sooner and Muskogee Stations.

2.3 COMPARISON BETWEEN 2008 AND 2009 COST ESTIMATES

A comparison of the 2008 and 2009 cost estimates for the Sooner and Muskogee Stations is

provided in Table 2.

Table 2

Sooner Unit 1 or Unit 2

2008 and 2009 Capital Cost Estimate Comparison (1)



# Sooner Unit 1 or Unit 2 Muskogee Unit 4 or Unit 5

Item 2008 Cost

Estimate 2009 Cost

Estimate 2008 Cost

Estimate 2009 Cost

Estimate

Total Costs ($) $390,406,000 $292,294,000 $373,106,000 $317,193,600

Cost per kw-gross ($/kw) $686 $514 $652 $555

Cost Difference (%) Base -25% Base -15%

Contingency ($) $56,598,000 $29,337,000 $54,089,000 $31,552,100

(1) Total Costs for DFGD summa rized in this table are divided equally between the two units at each station.

Total Costs for DFGD at the Sooner Station will be $584,588,000, and total costs at the Muskogee Station

will be $634,387,200.



# Major factors contributing to the reduction of costs from 2008 to 2009 include:

a) Direct Costs

The 2008 estimate was prepared when the demand for DFGD systems was high and costs

were near their peak. It is estimated that major equipment costs have dropped

approximately 15% to 20% since this time.

b) Contingency Costs

The 2009 estimate was based on vendor quotatio ns for major equipment and preliminary

engineering to develop quantities. As a r esult of this additional cost certainty, the

contingency factor in the 2009 estimate (14% ) is approximately 6% lower than the 2008

estimate. The difference in contingency amount s between the two estimates is illustrated in

Table 2-2.

# Oklahoma Gas & Electric December 28, 2009

BART Analysis Follow-Up Report (Rev. 1) Project No. 11418-019

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# c) Escalation Costs

The estimate of future escalation is lower in 2009 than it was in early 2008 when prices had

been rapidly increasing over the previous thr ee years. The difference in overall project

escalation factors is about 10%.

The cumulative effect of changes in the above thr ee cost items, with all other things being equal,

would be about a 20% to 30% reduction in pricing from 2008 to 2009. The actual decrease was

about 25% which falls into this range. We belie ve this validates the capital costs provided in the

2008 estimate.

2.4 UPDATED TOTAL ANNUAL COSTS AND COST EFFECTIVENESS

In general, total annual costs are the sum of th e capital recovery costs and annual O&M costs.

Cost effectiveness of a pollution control system is calculated by dividing the total annual cost of

the control system ($/year) by the total annual quantity of pollutant removed by the system

(tons/year); where:

- Annual Cost (Reference Year $/year) = A nnualized Capital Costs + Annual Operating

Costs;

- Annualized Capital Costs (Reference Year $/y ear) = Total Capital Requirement x Capital

Recovery Factor;

- Total Capital Requirement (Reference Year $) = All capitalized expenses as of the

commercial operating date, including direct costs, indirect costs, and allowance for funds

used during construction (AFUDC);

- Capital Recovery Factor = The factor that converts the Total Capital Requirement into

equal annual costs over the depreciable life of the asset, accounting for OG&E returns on

debt and equity and income taxes, expressed in real terms (i.e., inflation removed); and

- Annual Operating Costs (Reference Year $/year) = Variable O&M Costs + Fixed O&M

Costs + Indirect Operating Costs.

The following sections describe the derivation of these components of the cost estimate.

# Oklahoma Gas & Electric December 28, 2009

BART Analysis Follow-Up Report (Rev. 1) Project No. 11418-019

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# 2.4.1 Capital Costs

Conceptual capital costs for the DFGD control projects at each OG&E station were calculated

using the methodology described in Section 2.2. The total capital requirement (TCR) is the

sum of direct costs, indirect costs, contin gency, escalation, and allowance for funds used

during construction. Direct costs include equi pment, material, labor, spare parts, special

tools, consumables, and freight. Indirect costs include engineering, procurement,

construction management, start-up, commissioning, operator training, and owner's costs.

Escalation and AFUDC were calculated from the estimated distribution of cash flows during

the construction period and OG&E's before-t ax weighted average cost of capital of

8.66%/year. The 37-day tie-in outage for each unit is assumed to be coordinated with the

normal 5-week scheduled outage such that in cremental replacement cost is negligible.

The TCR for each unit is summarized in Ta bles B-1 through B-4 in Attachment B.

Capital Recovery Factor

The capital recovery factor converts the TCR in to equal annual costs over the depreciable life

of the asset, accounting for OG&E returns on debt and equity and income taxes, expressed in

real terms (i.e., inflation removed). These are also referred to as levelized capital charges.

Property taxes and insurance are sometimes included with the capital charges, but are

classified in this analysis as part of the Indir ect Operating Costs to be consistent with the

BART reports. The economic parameters used to derive the levelized capital charges are

summarized in Table 3.

Table 3

Economic Parameters to Derive Levelized Capital Charges

Commercial Operation Date (Reference Year)

Sooner 2014

Muskogee 2015

Depreciable Life 20 years

Inflation Rate 2.50%/year

Effective Income Tax Rate – Federal and State 38.12%

Common Equity Fraction 0.557

Debt Fraction 0.443

Return on Common Equity

Nominal 10.75%/year

Real 8.05%/year

Return on Debt

Nominal 6.03%/year

# Oklahoma Gas & Electric December 28, 2009

BART Analysis Follow-Up Report (Rev. 1) Project No. 11418-019

Page 9 

# Real 3.44%/year

Discount Rate (after-tax cost of capital)

Nominal 7.64%/year

Real 5.43%/year

Tax Depreciation 20-year

straight line

Levelized Capital Charges (real) 10.36%/year

Based upon the above parameters, the real leveli zed capital charge rate (capital recovery

factor) is 10.36%/year. The derivation of this value is shown in Table B-5 in Attachment B.

The TCR multiplied by 10.36% thus determines the Annualized Capital Costs.

2.4.2 Operating Costs

Annual operating costs for the DFGD system c onsist of variable O&M costs, fixed O&M

costs, and indirect operating costs. The de rivation of each cost component is described

below.

Variable O&M

Variable O&M costs are items that generally va ry in proportion to the plant capacity factor.

These consist of lime reagent costs, water cost s, FGD waste disposal costs, bag and cage

replacement costs, ash disposal costs, and auxiliary power costs, which were derived as

follows:

- Lime Reagent . Based on material balances for th e average fuel composition and 90%

capacity factor. The first-year delivered cost of lime is $118.80/ton for Sooner and

$105.53/ton for Muskogee based on budgetary lime quotations received for truck

delivery.

- Water . Based on 205,256 lb/hr at full load at Sooner, 219,839 lb/hr at full load at

Muskogee, and 90% capacity factor. The first- year cost of water is $0.49/1000 gallons at

Sooner and $2.57/1000 gallons at Muskogee. Water unit costs are based on information

received from OG&E. The Muskogee water cost includes the cost of purchasing water.

Sooner does not have any water purchase costs.

- FGD Waste Disposal . Based on material balances for the average fuel composition and

90% capacity factor. The first year cost of on-site disposal is $39.60/ton at Sooner and

$40.59/ton at Muskogee. Disposal cost only includes FGD by-products and does not

include fly ash.

# Oklahoma Gas & Electric December 28, 2009

BART Analysis Follow-Up Report (Rev. 1) Project No. 11418-019

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# - Bag and Cage Replacement . Based on the exhaust gas flow through the baghouse, air-tocloth ratio of 3.5 for pulse jet baghouse, 4% contingency for bag cleaning, and 3-year bag

life. The first year bag cost (including fabric and hangers) is $3.22/ft 2 

# at Sooner and

$3.31/ft 2 

# at Muskogee.

- Ash Disposal . Assumed no increase in ash disposal with the fabric filter due to the

existing ESP remaining in service.

- Auxiliary Power Cost . Based on auxiliary power calculations and 90% capacity factor.

The first year auxiliary power cost is $83.83/MWh at Sooner and $85.92/MWh at

Muskogee.

Fixed O&M

Fixed O&M costs are recurring annual costs that are generally independent of the plant

capacity factor. These consist of operating labor , supervisor labor, maintenance materials,

and maintenance labor, which were derived as follows:

- Operating Labor . Based on three shifts/day 365 days/year. The first year labor rate

(salary plus benefits) is $57.33/hour at Sooner and $58.76/hour at Muskogee.

- Supervisory Labor . This was based on 15% of operating labor, according to the EPA

Control Cost Manual, page 2-31. S&L dete rmined that the EPA approach provides a

reasonable estimate for this cost item.

- Maintenance Materials . This was based on 0.6% of the total plant investment, based on

Sargent & Lundy’s experience on other FGD projects.

- Maintenance Labor . This was based on 110% of operating labor, according to the EPA

Control Cost Manual, page 2-31. S&L dete rmined that the EPA approach provides a

reasonable estimate for this cost item.

Indirect Operating Costs

Indirect operating costs are recurring annual costs for the FGD system that are not part of the

direct O&M. These consist of property taxes, insurance, and administration, which were

derived as follows:

# Oklahoma Gas & Electric December 28, 2009

BART Analysis Follow-Up Report (Rev. 1) Project No. 11418-019

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# - Property Taxes . Calculated as 0.60 % of total capital investment at Sooner and 0.85% of

total capital investment at Muskogee, accordi ng to OG&E property tax rates. These rates

are significantly lower than those used in the EPA Air Pollution Control Cost Manual 6th

Ed., page 2-34.

- Insurance . Calculated as 0.0105 % of total capital investment at both Sooner and

Muskogee, according to OG&E insurance rates. These rates are significantly lower than

those used in the EPA Air Pollution Control Cost Manual 6th Ed., page 2-34.

- Administration . These are calculated as 20% of the fixed O&M based on Sargent &

Lundy’s experience on other projects. This r esults in significantly lower costs compared

to those obtained using the methodology descr ibed in the EPA Air Pollution Control Cost

Manual 6th Ed., page 2-34.

Total Annual Operating Costs

The total annual operating costs for each unit are calculated in Tables B-1 through B-4 in

Attachment B and are approximately $29 to $32/kw per year. These costs compare favorably

with industry O&M data for existing coal plants , and are within the normal range of expected

O&M costs for dry FGD systems. The annual operating cost of approximately $29 to $32/kw

is significantly lower than the $68/kw calcula ted in the 2008 BART report which was derived

using OAQPS Cost Manual and CUECost default factors, and is lower than the $43 to

$47/kw estimated by the DEQ in the draft Regional Haze Implementation Plan.

2.4.3 2009 Cost Effectiveness

Total annual DFGD costs for each unit are summarized in Table 4. Detailed cost calculations

are shown in Tables B-1 through B-4 in Attachment B. Total annual costs are divided by the

annual tons of SO 2 

# removed to calculate average cont rol technology cost effectiveness.

Annual emission reductions associated with DF GD control systems are summarized in Table

5 using the same basis as the September 2009 OG&E BART update. The SO 2 

# control

efficiency for each unit is summarized in Table 6

Table 4

DFGD Total Annual Cost Summary

Unit Capital Recovery

($/year) Annual O&M

($/year) Total Annual Cost

($/year)

Muskogee 4 $32,861,300 $18,438,900 $51,300,200

Muskogee 5 $32,861,300 $18,438,900 $51,300,200

Sooner 1 $30,281,800 $16,550,500 $46,832,300

Sooner 2 $30,281,800 $16,550,500 $46,832,300

# Oklahoma Gas & Electric December 28, 2009

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# Table 5

BART Annual SO2 Emission Reductions with Dry FGD

Unit Baseline Annual

SO2 Emissions (1)



# (tpy) Projected PostControl Annual

Emissions (2)



# (tpy) Annual Emission

Reductions

(tpy)

Muskogee 4 9,113 2,160 6,953

Muskogee 5 9,006 2,160 6,846

Sooner 1 9,394 2,017 7,377

Sooner 2 8,570 2,017 6,553

(1) In this table baseline SO 2 

# emissions are calculated as the average actual SO 2 

# emission rate during the

baseline years of 2004 – 2006.

(2) In this table projected post-control SO 2 

# emissions are calculated based on a controlled SO 2 

# emission

rate of 0.10 lb/mmBtu an d a 90% capacity factor.



# Table 6

Average Cost Effectiveness

Unit Annual Cost

($/year) SO 2 

# Removed

(tons/year) Average Cost

Effectiveness

($/ton)

Muskogee 4 $51,300,200 6,953 $7,378

Muskogee 5 $51,300,200 6,846 $7,493

Sooner 1 $46,832,300 7,377 $6,348

Sooner 2 $46,832,300 6,553 $7,147

Cost effectiveness is a function of both the cost of a control system and the annual tons of

pollutant removed. With respect to tons remove d, various bases can be used to calculate both the

baseline emission rate and the post-project contro lled emission rate. Varying either the baseline

calculation or the projected emissions calculati on will result in a different cost effectiveness

value.

To account for this variability, the cost effec tiveness of DFGD controls at Sooner and Muskogee

were calculated using various baseline and projected SO 2 

# emission rates. Emission rates were

chosen to “envelope” the cost effectiveness of th e DFGD control systems. For example, baseline

SO 2 

# emissions were based on the actual average SO 2 

# emission rate during the 2004-2006 baseline

period, as well as the highest annual SO 2 

# emissions during the baseline period. Projected SO 2



# emissions were calculated using the presumptive SO 2 

# emission rate of 0.15 lb/mmBtu, as well

controlled SO 2 

# emission rates of 0.10 and 0.08 lb/mmBtu. Finally, capacity factors of either 90%

(which is more representative of actual operati ons) or 100% (which represents potential emissions

but would represent actual operations) were also used.

# Oklahoma Gas & Electric December 28, 2009

BART Analysis Follow-Up Report (Rev. 1) Project No. 11418-019

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# Although annual O&M costs will va ry depending on the controlled SO 2 

# emission rate (i.e., lower

post-project SO 2 

# emission rates will have a higher annual variable O&M cost), for this analysis

total annual costs were held constant. Cost effectiveness calculations for two alternative

scenarios are summarized in Tables 5a & 6a and 5b & 6b.

Table 5a

BART Annual SO2 Emission Reductions with Dry FGD

(Scenario 2)

Unit Baseline Annual

SO2 Emissions (1)



# (tpy) Projected PostControl Annual

Emissions (2)



# (tpy) Annual Emission

Reductions

(tpy)

Muskogee 4 9,775 3,600 6,175

Muskogee 5 10,224 3,600 6,624

Sooner 1 10,189 3,361 6,828

Sooner 2 8,746 3,361 5,385

(1) In this table baseline SO 2 

# emissions reflect the highest annual SO 2 

# emission rate during the baseline

years of 2004 – 2006.

(2) In this table projected post-control SO 2 

# emissions are calculated based on a controlled SO 2 

# emission

rate of 0.15 lb/mmBtu (the presumptive BA RT emission rate) and a 100% capacity factor.



# Table 6a

Average Cost Effectiveness

(Scenario 2)

Unit Annual Cost

($/year) SO 2 

# Removed

(tons/year) Average Cost

Effectiveness

($/ton)

Muskogee 4 $51,300,200 6,175 $8,308

Muskogee 5 $51,300,200 6,624 $7,745

Sooner 1 $46,832,300 6,828 $6,859

Sooner 2 $46,832,300 5,385 $8,697

# Oklahoma Gas & Electric December 28, 2009

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# Table 5b

BART Annual SO2 Emission Reductions with Dry FGD

(Scenario 3)

Unit Baseline Annual

SO2 Emissions (1)



# (tpy) Projected PostControl Annual

Emissions (2)



# (tpy) Annual Emission

Reductions

(tpy)

Muskogee 4 9,775 1,920 7,855

Muskogee 5 10,224 1,920 8,304

Sooner 1 10,189 1,793 8,396

Sooner 2 8,746 1,793 6,953

(1) In this table baseline SO 2 

# emissions reflect the highest annual SO 2 

# emission rate during the baseline

years of 2004 – 2006.

(2) In this table projected post-control SO 2 

# emissions are calculated based on a controlled SO 2 

# emission

rate of 0.08 lb/mmBtu and a 100% capacity factor. A controlled SO 2 

# emission rate of 0.08 lb/mmBtu

represents the lowest SO 2 

# emission rate that could reasonably be expected to be achieved on a large

subbituminous coal-fired unit with a retrofit DFGD control system.



# Table 6b

Average Cost Effectiveness

(Scenario 3)

Unit Annual Cost

($/year) SO 2 

# Removed

(tons/year) Average Cost

Effectiveness

($/ton)

Muskogee 4 $51,300,200 7,855 $6,531

Muskogee 5 $51,300,200 8,304 $6,178

Sooner 1 $46,832,300 8,396 $5,578

Sooner 2 $46,832,300 6,953 $6,736

Cost effectiveness varies depending on the baseline and controlled SO 2 

# emission rates used in the

evaluation. Under all scenarios, DFGD cost e ffectiveness on the OG&E units is greater than

$5,550/ton. Based on the BART presumptive level of 0.15 lb/mmBtu, and assuming a 100%

capacity factor, cost effectiveness of DFGD on th e Muskogee and Sooner units would be in the

range of $6,859 to $8,697/ton (see, Table 6a). Cost effective values calculated using the BART

presumptive level should be used to compare cost effective at other BART applicable sources.

In addition to calculating cost effectiveness on a $/ton basis, with respect to regional haze

impacts, cost effectiveness can be calculated as a function of annual costs and modeled visibility

improvements at the affected Class I Areas. Modeled visibility improvements will be a function

of the proximity of the unit to the Class I Ar ea, baseline and controlled emissions, and the

pollutant being controlled. Table 7 provides a summary of the modeled reduction in visibility

impairment (measured in deciview- dv) resu lting from DFGD controls on the Muskogee and

Sooner generating units. The cost effectiven ess of DFGD controls as a function of modeled

# Oklahoma Gas & Electric December 28, 2009

BART Analysis Follow-Up Report (Rev. 1) Project No. 11418-019

Page 15 

# reductions in visibility impairment (using two diffe rent impact criteria) is provided in Tables 8

and 8a.

Table 7

Modeled Visibility Improvement at the Class I Areas (dv)

Class I Area Muskogee

Units 4 & 5 Sooner Units

1 & 2

Wichita Mountains National Wildlife

Refuge 1.275 0.51

Caney Creek Wilderness Area 0.804 0.32

Upper Buffalo Wilderness Area 1.11 0.44

Hercules-Glades Wilderness Area 1.028 1.17

Total 4.217 2.44

Table 8

Average Cost Effectiveness ($/dv)

Unit Annual Cost

($/year) Modeled Visibility

Improvement (1)



# (dv) Average Cost

Effectiveness

($/dv)

Muskogee 4 & 5 $102,600,400 1.275 $80,470,902

Sooner 1 & 2 $93,664,600 1.17 $80,055,214

(1) The modeled reduction in visibility impairment used in this table represents the highest single modeled

reduction at a single Class I Area.



# Table 8a

Average Cost Effectiveness ($/dv)

Unit Annual Cost

($/year) Modeled Visibility

Improvement (1)



# (dv) Average Cost

Effectiveness

($/dv)

Muskogee 4 & 5 $102,600,400 4.217 $24,330,187

Sooner 1 & 2 $93,664,600 2.44 $38,387,131

(1) The modeled reduction in visibility impairment used in this table represents the cumulative reduction

of all Class I Areas.



# Based on the cost effectiveness calculations summa rized above, taking into considered modeled

visibility improvements at all of the affected Class I areas, the cost effectiveness of DFGD on

Sooner Units 1 & 2 will be in the range of $38, 387,000/dv, and the cost effectiveness of DFGD

on Muskogee Units 4 & 5 will be in the range of $24,330,000/dv.

# Oklahoma Gas & Electric December 28, 2009

BART Analysis Follow-Up Report (Rev. 1) Project No. 11418-019

Page 16 

# 2.5 COMPARISON OF 2009 CAPITAL COSTS AGAINST OTHER PUBLISHED

CAPITAL COST INFORMATION

Appendix 6-4 of the November 13, 2009 Okla homa draft Regional Haze Implementation Plan

Revision includes DEQ’s BART analysis for each OG &E BART applicable unit. In each of the

OG&E BART determinations, DEQ revised the cost estimates for retrofit DFGD control systems,

including revisions to the capital costs and a nnual O&M costs. Although DEQ stated that, in

general, the cost estimating methodology used by OG&E “followed guidance provided in the

EPA Air Pollution Cost Control Manual,” DEQ conc luded, based on a review of other BART

submittals, that OG&E’s costs were substantially hi gher than those reported for similar projects.

(Draft Regional Haze Implementation Plan, Appendi x 6-4, page cliii). DEQ proceeded to revise

the capital costs and O&M costs based on cost information provided in the following

publications: (1) a Colorado Department of Public Health and Environment report titled

“Summary of Research and Potential Contro l Options, Emission Reductions and Costs for

Reducing SO2 and NOx from Ex isting Major Colorado Point So urces”; (2) a March 1, 2009

article in Power, on online industry magazine, titled “Update: What’s That Scrubber Going to

Cost” written by George W. Sharp of American Electric Power; and (3) a report prepared by

Sargent & Lundy for the National Lime Associa tion titled “Flue Gas Desulfurization Technology

Evaluation, Dry Lime vs. Wet Limestone FGD” dated March 2007.

In its comments to DEQ regarding the draft Regional Haze Implementation Plan FWS/NPS

agreed with DEQ that costs presented by OG&E for SO 2 

# control were excessive. In addition,

FWS/NPS provided an alternative lower cost an alysis using capital costs “taken from the 2007

Flue Gas Desulfurization Technology Evaluation, Dry Lime vs. Wet Limestone FGD, prepared

for National Lime Association.”

We address each of the referenced documents below.

2.5.1 Colorado Department of Public Health and Environment Report

The Colorado Department of Public Health and Environment report included unit capital

costs for retrofit dry scrubbers on 500 MW units burning PRB coal. The report was prepared

by BBC Research and Consulting, and relied on cost data in a 2003 report prepared by

Sargent & Lundy titled “Economics of Lime and Limestone for Control of Sulfur Dioxide”

(the 2003 National Lime Report). As discussed in more detail below, capital costs included

in the 2003 National Lime Report were intende d to provide a comparison between lime-based

and limestone-based scrubbing technologies, and were not intended to be used as the basis for

a project-specific capital cost estimate.

# Oklahoma Gas & Electric December 28, 2009

BART Analysis Follow-Up Report (Rev. 1) Project No. 11418-019

Page 17 

# 2.5.2 2007 National Lime Association Report

Both DEQ and FWS reference the 2007 National Lime Report prepared by Sargent & Lundy

as a basis for their capital cost revisions. In fact, the FWS’s alternative capital costs were

based on numbers provided in the 2007 National Lime Report. However, the National Lime

report was only intended to provide a comp arative cost effectiveness evaluation of wet

limestone-based FGD control systems and dry lime-based control systems. The report was

not intended to provide an evaluation of total capital requirements for either type of control

technology and was not intended to serve as the basis for a capital cost estimate. The 2007

report clearly states: 1



# FGD prices have seen a minimum of 25% inflation in the past year.

Some recent contracts have been signed at prices over 300% higher than

the market of 5 years ago. The costs [in this report] have been prepared

on a consistent, uniform basis and show a level that some buyers

achieved in mid-2006. Sargent & Lundy cautions the reader that the

costs provided herein are not indicative of any cost you may actually

achieve. However, we believe th e costs are valid for comparative

purposes. These costs should not be used for any of these purposes;

• Planning the cost of a FGD project

• Budget requests or allocations

• Solicitation of pollution control bonds

In today’s market place, it is impossible to determine capital cost of an

FGD system until the contract is signed with the supplier.

Capital costs in both the 2003 and 2007 Na tional Lime Reports were developed for

comparative purposes only. Furthermore, costs in the 2007 report were based on 2006 dollars

and did not include escalation, which can add appr oximately 10% to 20% to the project cost.

Nor do the reports take into consideration any s ite-specific retrofit challenges. Capital costs

in the National Lime Reports were presented on a consistent basis for comparative purposes

only. Cost estimates using the methodology describ ed in Section 2.1 of this report provide a

more accurate accounting of actual costs that w ill be incurred by OG&E to install and operate

dry FGD control systems at the Sooner and Muskogee generating stations.

1 

# See, Sargent & Lundy, “Flue Gas Desulfurization Technology Evaluation, Dry Lime vs. Wet Limestone

FGD,” prepared for the National Lime Association, March 2007, page 2 (emphasis in the original).

# Oklahoma Gas & Electric December 28, 2009

BART Analysis Follow-Up Report (Rev. 1) Project No. 11418-019

Page 18 

# 2.5.3 “Update: What’s That Scrubber Going to Cost” article

DEQ also used capital cost estimates summarized in a March 1, 2009 article in “Power” an

online industry magazine to adjust the capita l costs for DFGD retrofit projects at the OG&E

stations. The Power article provided a survey of FGD projects at large electric utility

generating stations during the period of D ecember 2007 through June 2008. The article

summarized the average total installed costs of FGD control systems as reported by the

survey respondents, noting that the reported cost s “were expected to have wide variation,

principally because of the peculiarities that ex ist at each project site, the retrofit project

complexity, and the timing differences between projects.” Therefore, assigning a projectspecific cost based on information summarized in the article would not be correct without

taking into consideration project specific details.

Furthermore, the 2009 OG&E conceptual cap ital costs of $514/kw (Sooner) and $555/kw

(Muskogee) are reasonably close to the $359 to $471/kw taken from this article. The article

reported that the 2008 cost surveys were 28% hi gher than those reported in the 2007 survey

with an average of $359/kw for 600 to 900 MW plant range and $471/kw for 300 to 599 MW

range. Note that these values are averages and include units with wide ranges of in-service

dates. In fact, 55% of the units in the survey were expected to be in operation by 2009

whereas the OG&E units are not expected to be in operation until 2014 and 2015. The 55%

of the units in operation by 2009 would have had their major equipment purchased prior to

the 28% run up in pricing in 2008 from late 2006 and prior to the 22% run up in pricing from

2006 to 2007 referenced in the same article . The OG&E units would be subject to these

escalated costs and future escalation.

In addition, the OG&E units would also require a higher level of contingency since the

projects are still in the early study phase. As a result, units going into service in the near

future would be expected to be below the aver age cost while units going into service at later

dates would be expected to be above the aver age cost. The article only provides an average

cost and does not provide any information on the cost distribution about the average. A wide

distribution is expected as indicated at the bo ttom of page 65 of the Power article, where it

states that “average total installed costs reporte d by the survey respondents were expected to

have wide variation” based partially on the “t iming differences between projects.” Because

of the expected wide variation in project cost s, this report can be used to illustrate recent

industry cost trends but should not be used to estimate the cost of specific units that will not

go into service for another 5 to 7 years. Agai n, it is believed that the methodology described

in Section 2.1 will provide more accurate results for a specific project than the cited article.

# Oklahoma Gas & Electric December 28, 2009

BART Analysis Follow-Up Report (Rev. 1) Project No. 11418-019

Page 19 

# 3.0 BART Report Comparisons

The cost effectiveness of a pollution control system is a function of the total annual cost of the

system (taking into consideration capital recove ry and annual O&M) and the amount of pollutant

removed by the control system (tons per year). With respect to regional haze impacts, cost

effectiveness can also be measured as a function of total annual costs divided by the modeled

improvement in visibility at the nearby Class I Areas. This measure of cost effectiveness is

reported in total annual dollars pe r deciview change in visibility impairment ($/dv). Thus, in

addition to costs, two site-specific factors that impact cost effectiveness are the quantity of

pollutant removed and the reduction in modeled visibility impairment.

3.1 COMPARISON OF BASELINE SO 2 

# EMISSIONS

Table 9 provides a summary of the baseline SO 2 

# emission rates included in several BART

evaluations. A more detailed comparison of some of the costs and cost effectiveness calculations

included in various BART determinations is included in Attachment C.

Table 9

Comparison of Baseline SO 2 

# Emissions at Several BART Units

Station Baseline SO 2



# Emission Rate

(lb/mmBtu) Baseline SO 2



# Emissions

(tpy)

Muskogee Unit 4 0.507 9,113

Muskogee Unit 5 0.514 9,006

Sooner Unit 1 0.509 9,394

Sooner Unit 2 0.516 8,570

NPPD Gerald Gentleman Unit 1 0.749 24,254

NPPD Gerald Gentleman Unit 2 0.749 25,531

White Bluff Unit 1 0.915 31,806

White Bluff Unit 2 0.854 32,510

Boardman Unit 1 0.614 14,902

Northeastern Unit 3 0.900 16,000

Northeastern Unit 4 0.900 16,000

Naughton Unit 1 1.180 8,624

Naughton Unit 2 1.180 11,187

OPPD Nebraska City Unit 1 0.815 24,191

# Oklahoma Gas & Electric December 28, 2009

BART Analysis Follow-Up Report (Rev. 1) Project No. 11418-019

Page 20 

# Of the units listed in Table 9, the OG&E units have the lowest baseline SO 2 

# emission rates, and

among the lowest baseline annual SO 2 

# emissions (tpy). Baseline emissions have a direct effect on

the cost effectiveness of a pollution control system, as shown below:

Cost Effectiveness = Total Annual Costs / (Baseline Emissions – Projected Emissions)

Assuming total annual costs and projected emissions are similar, cost effectiveness will be a

function of the baseline emissions. This holds true for units firing subbituminous coals with

baseline SO 2 

# emission rates in the range of 0.5 lb/mmBtu to approximately 2.0 lb/mmBtu because

removal efficiencies achievable with DFGD control will vary based on inlet SO 2 

# loading. In

general, DFGD control systems are capable of achieving higher removal efficiencies on units

with higher inlet SO 2 

# loading. 2 

# DFGD control systems will be more cost effective on units with

higher baseline SO 2 

# emissions because the control system will be capable of achieving higher

removal efficiencies and remove more tons of SO 2 

# per year for similar costs. Conversely, DFGD

will be less cost effective, on a $/ton basis, on units with lower SO 2 

# baseline emissions. The

difference in baseline SO 2 

# emissions summarized above accounts for some of the variability seen

in the BART cost effectiveness calculations. On the basis of the baseline emission rates alone,

with all other factors being equal, the cost e ffectiveness of the OG&E units would be about 55%

to 185% higher than the other units listed in Table 9.

3.2 COMPARISON OF MODELED VISIBILITY IMPROVEMENT

Finally, with respect to regional haze impacts, cost effectiveness can also be calculated as a

function of modeled improvements in visibility at the Class I areas. This cost effectiveness

measurement can be presented by dividing the total annual costs by the degree of visibility

improvement at an individual Class I area, or by dividing total annual costs by the sum of

visibility improvement across all affected Cl ass I areas. Using either approach, control

technologies installed on units with higher baseline emissions and located nearer a Class I area

will be more cost effective.

In its comments to DEQ, FWS/NPS argued that cost effectiveness should “consider both the

degree of visibility improvement in a given Class I area as well as the cumulative effects of

2 

# Removal efficiencies achievable with DFGD w ill be a function of several unit-specific process

parameters. Process parameters affecting remova l efficiency include: inlet and outlet flue gas

temperatures; reactant stoichiometric ratio; how close the DFGD is operated to saturation conditions; the

amount of solids product recycled to the atomizer, and the inlet SO 2 

# concentration. Chemical and physical

limitations including flue gas temper ature, Ca/S stoichiometry, approach to saturation, mixing and reaction

time limit the control efficiency of the DFGD contro l systems.

# Oklahoma Gas & Electric December 28, 2009

BART Analysis Follow-Up Report (Rev. 1) Project No. 11418-019

Page 21 

# improving visibility across all of the Class I areas affected.” 3 

# FWS/NPS reasoned that “[i]t is not

appropriate to use the same metric to evalua te the effects of reducing emission from a BART

source that impacts only one Class I area as for a BART source that impacts multiple Class I

areas.” 4 

# Taking the cumulative impact approach, co st effectiveness will also be a function of the

number of Class I areas affected by an individual BART applicable unit. Controls would be more

cost-effective on units in near proximity to a Cl ass I area, as well as units located within 300 km

of a number of Class I areas. Figure 1 shows the location of the Class I areas in the U.S.

Figure 1

Class I Areas

A majority of the Class I areas are located in the western part of the U.S. Simply due to the

number of Class I areas in the west, it is likely that a BART applicable unit located in the western

U.S. will be closer to a Class I area, and that em issions from the unit will affect visibility at more

Class I areas. For example, the Boardman Gene rating Station located in north central Oregon

approximately 150 miles east of Portland, is located within 300 km of 14 Class I areas. By

3 

# FWS/NPS Comments, page 3.

4 

# Id.

# Oklahoma Gas & Electric December 28, 2009

BART Analysis Follow-Up Report (Rev. 1) Project No. 11418-019

Page 22 

# comparison, the Sooner and Muskogee stations are located within 300 km of one and four Class I

areas, respectively.

Taking the cumulative impact approach, control t echnologies will be more cost effectiveness on

units affecting a number of Class I areas. For ex ample, modeled visibility improvement at each

Class I areas affected by the Sooner, Muskogee, a nd Boardman stations are summarized in Table

10. Assuming the cost of retrofit controls are si milar at all three stations, and assuming that each

station achieves similar emission reductions, DFGD c ontrols would be more cost effective at the

Boardman Station (on a $/dv basis) simply du e to the cumulative improvement in visibility

improvement.

Table 10

Comparison of Baseline SO 2 

# Emissions at Several BART Units

Muskogee

Units 4 & 5 Sooner Units

1 & 2 Boardman

Unit 1

1 1.275 0.51 0.777

2 0.804 0.32 0.439

3 1.11 0.44 0.802

4 1.028 1.17 0.544

5 na na 0.774

6 na na 0.655

7 na na 0.659

8 na na 0.969

9 na na 0.924

10 na na 0.614

11 na na 0.776

12 na na 0.354

13 na na 0.681

14 na na 0.874

Total 4.217 2.44 9.842

In its BART analysis submitted to the Oregon Depa rtment of Environmental Quality, total capital

requirements and total annual costs for DFGD were estimated at $247,293,000 and $36,322,000,

respectively. Using the sum of modeled visibility improvements at all 14 Class I areas, cost

effectiveness of the DFGD control system would be $3,690,510/dv (e.g., $36,322,000 divided by

9.842 dv). By comparison, because the OG&E sta tions are located relatively far from a limited

number of Class I areas, cost effectiveness at the Sooner and Muskogee stations would be

$38,387,000/dV and $24,330,000/dv, respectively. 5

5 

# Sooner = $93,664,600 ÷ 2.44 dv = $38,387,000/dv

Muskogee = $102,600,400 ÷ 4.217 dv = $24,330,000/dv

# Oklahoma Gas & Electric December 28, 2009

BART Analysis Follow-Up Report (Rev. 1) Project No. 11418-019

Page 23 

# 4.0 Conclusions

Sargent & Lundy updated the retrofit DFGD control system cost estimates for the Sooner and

Muskogee Generating Stations. The 2009 conceptual cost estimate (included in this report) was

based on project-specific vendor quotations fo r certain major equipment items and inputs

developed by performing preliminary project e ngineering. The 2009 conceptual capital cost

estimate is in the ±20% accuracy range. Total a nnual costs associated with the installation of

DFGD, including capital recovery costs and annua l O&M costs were also updated. Annual O&M

costs were derived from preliminary engineering mass balance calculations and project-specific

unit costs. The cost estimating methodology used herein to develop both capital and O&M costs

provides a more accurate estimate of actual co sts that OG&E would incur with the installation

and operation of DFGD on the Sooner and Muskogee units.

The 2009 conceptual capital cost estimates a nd supporting information for both generating

stations are included in Attachment A. Deta iled total annual cost summaries, including capital

recovery, variable O&M, and fi xed O&M calculations are included in Attachment B. Based on

the cost estimates, the total capital requirement s for DFGD controls on all four OG&E units will

be in the range of $1.22 billion dollars. Tota l annual costs (including capital recovery and O&M)

will be in the range of $93.6 million/year at Sooner and $102.6 million/year at Muskogee.

Cost effectiveness of a pollution control system is a function of the total annual cost of the system

and the quantity of pollutant removed (tons/yea r). Because of the relatively low baseline SO 2



# emission rates at both Muskogee and Sooner (see, Table 9), DFGD will be less cost effective on

these units than on similarly sized units with higher baseline SO 2 

# emissions. Based on expected

reductions in actual annual SO 2 

# emissions, the cost effectiveness of DFGD on the OG&E units

will be in the range of $6,3 48 to $7,493/ton (see, Table 6).

In addition to calculating cost effectiveness on a $/ton basis, with respect to regional haze

impacts, cost effectiveness can be calculated as a function of annual costs and modeled visibility

improvements at the affected Class I Areas. Modeled visibility improvements will be a function

of the proximity of the unit to the Class I Ar ea, baseline and controlled emissions, and the

pollutant being controlled. Because the OG&E st ations are located relatively far from a limited

number of Class I areas, DFGD will be less cost ef fective (on a $/dv basis) on the OG&E units

than on similarly sized units located closer to a Class I area or within 300 km of several Class I

areas. Based on modeled visibility improvements, the cost effectiveness at the Sooner and

Muskogee stations would be $38,387,000/dV and $24,330,000/dv, respectively.

# Oklahoma Gas & Electric December 28, 2009

BART Analysis Follow-Up Report (Rev. 1) Project No. 11418-019



# Attachment A

Sooner Units 1 & 2

Conceptual Cost Estimate

# OG&E

Sooner Units 1&2 DFGD System

Cost Estimate Account Summary Date: 12/11/2009



# Account Description Cost

Dry FGD System $86,859,600

Fabric Filter $46,335,000

Ash Recycling System - DFGD

Contractor's Scope $12,072,500

Waste Ash and Fly Ash Handling

System $14,265,600

Flue Gas System $42,463,000

Mechanical - Balance of Plant $6,891,300

Electrical - Auxiliary Power and

Balance of Plant Electrical Work $41,935,100

Controls & Instrumentation $5,088,500

Civil Work $3,597,400

Removal and Relocation of Existing

Equipment and Infrastructure $2,047,600

Other Costs $63,746,900

Total Indirect Costs $48,090,100

Escalation $46,602,900

Contingency $58,673,400

Bond Cost $4,786,700

Interest During Construction

(AFUDC) $101,133,800

Total Project Cost $584,589,400

Page 1 of 1OG & EEstimate No.: 30228 A1Sooner Units 1 & 2Project No.: 11418-019Dry FGD SystemsDate: 12/11/2009Conceptual Cost EstimatePrepared by: MNOCost Type:Reviewed by: RKEst=EstimatedApproved by: PEFAllow.=AllowanceWage Rates Based on: 9NUR06C= ContractLabor Productivity = 1.15Q=Vendor QuoteCode ofAccountsItem DescriptionScope DefinitionCost TypeQuantityUnit ofMeasureUnit Equip.CostUnit MaterialCostTotal EquipmentCostTotal Material CostCost DevelopmentUnit Man-hours(Base)Total Man-hours(Base)Total Man-hours, Prod =1.15CrewCodeCrewWageRateTotal Construction& Erection CostTotal ProjectedCostDryFGD System46,462,100 8,209,500 508,270 32,188,000 86,859,60031-45-25 Dry FGD SystemQ 2 LT 15,917,133 0.00 31,834,300 0136,400 272,800 313,720 MECH 61.53 19,303,200 51,137,50031-45-35Reagent Handling/ PreparationEst0 0031-45-35 Reagent Handling / Preparation - Mechanical Q 2 LT 3,969,614 0.00 7,939,200 033600 67,200 77,280 MECH 61.53 4,755,000 12,694,20026-13-99Lime Storage Silo with piping for pneumaticunloading (truck)Concrete Silo - SubcontractpriceQ 1 LT 3,200,000 0.00 3,200,000 00 0 0 MECH 61.53 0 3,200,00024-17-15 Elevator for lime silofour person rack and pinionmaintenance elevator -subcontract price includes laborEst 1 LT 290,000 0.00 290,000 0 0 0 0 MECH 61.53 0 290,00022-13-27 Concrete pit for the elevator Est 10 CY 0 210.00 0 2,100 7.5 75 86 CONP 51.69 4,500 6,60041-99-99 Electrical work for the elevatorallowance Est 1 LT 0 20,000.00 0 20,000 175 175 201 WIRE 66.93 13,500 33,50033-43-15 Pneumatic lime transfer equipment/pipingincluding blowers, piping, andvalvesQ 1 EA 400,000 0.00 400,000 03500 3,500 4,025 MECH 61.53 247,700 647,70023-17-23 Access GalleryEst 2,000 SF 0.00 35.00 0 70,000 0.40 800 920 GALL 67.14 61,800 131,8000DryFGD System - Civil / Structural Work0Foundations for SDA's Quantities are total for 2 units21-23-15 ExcavationEst 2,140 CY0.00 0.00 0 0 0.20 428 492 EXFD 63.95 31,500 31,50021-17-25 BackfillEst 140 CY0.00 0.00 0 0 0.30 42 48 EXFD 63.95 3,100 3,10022-13-37 ConcreteEst 2,000 CY0.00 105.00 0 210,000 1.50 3,000 3,450 CONP 51.69 178,300 388,30022-25-35 ReinforcingEst 180 TN 0.00 1,150.00 0 207,000 20.00 3,600 4,140 REIN 61.48 254,500 461,50022-17-25 FormworkEst 6,000 SF 0.00 2.50 0 15,000 0.14 810 932 FORM 71.62 66,700 81,70022-15-25 Embedded steel Est 5.00 TN 0.00 5,000.00 0 25,000 120.00 600 690 CARP 46.37 32,000 57,000SDA SuperstructureQuantities are total for 2units023-25-75 Common Penthouse for SDA'ssupport steel, roof steel, girtsand purlinsEst 152 TN 0.00 2,650.00 0 402,500 35.00 5,316 6,113 STST 87.33 533,800 936,30024-37-43 SDA Roof Insulationbetween penthouse floor andSDA roof total for 2 SDAsEst 12,070 SF 0.00 15.00 0 181,100 0.30 3,621 4,164 ROOF 45.55 189,700 370,80024-37-47 Roofing for common SDA Penthouse standing seam type. Est 8,100 SF 0.00 18 0 145,800 0.22 1,782 2,049 ROOF 45.55 93,300 239,10024-41-25 Siding for common SDA Penthouse insulated metal siding Est 16,200 SF 0.00 12 0 194,400 0.11 1,782 2,049 SDNG 63.02 129,100 323,50036-13-23 Shell Insulation subcontract cost Est 61,688 SF 30.00 0 1,850,600 0 0 0 DINS 52.16 0 1,850,60022-13-23 Concrete bottom floor for common SDA Penthouseincludes metal decking andformworkEst 99 CY 210 0 20,800 7.5 743 854 CONP 51.69 44,100 64,90041-37-99 Common Penthouse BuildingServices H&V and LightingEst 8,100 SF 0.00 30.00 0 243,000 0.30 2,430 2,795 WIRE 66.93 187,000 430,00031-41-77 Fire Protection for Penthouse Standpipe & hose stations. Est 2 LS 80,000 160,000 500.00 1,000 1,150 MECH 61.53 70,800 230,80024-17-15 ElevatorFor SDA - four person rack andpinion elevator. Suncontractprice includes laborEst 1 LT 290,000 0.00 290,000 0 0.00 0 0 MECH 61.53 0 290,00022-13-37 Concrete pit for the elevator Est 10 CY 0 210.00 0 2,100 7.5 75 86 CONP 51.69 4,500 6,60041-99-99 Electrical work for the elevatorallowance Est 1 LT 0 20,000.00 0 20,000 175 175 201 WIRE 66.93 13,500 33,500Page 1 of 14OG & EEstimate No.: 30228 A1Sooner Units 1 & 2Project No.: 11418-019Dry FGD SystemsDate: 12/11/2009Conceptual Cost EstimatePrepared by: MNOCost Type:Reviewed by: RKEst=EstimatedApproved by: PEFAllow.=AllowanceWage Rates Based on: 9NUR06C= ContractLabor Productivity = 1.15Q=Vendor QuoteCode ofAccountsItem DescriptionScope DefinitionCost TypeQuantityUnit ofMeasureUnit Equip.CostUnit MaterialCostTotal EquipmentCostTotal Material CostCost DevelopmentUnit Man-hours(Base)Total Man-hours(Base)Total Man-hours, Prod =1.15CrewCodeCrewWageRateTotal Construction& Erection CostTotal ProjectedCostSDA - Support Steel and Access Gallery23-25-75 Support Steel Included in DFGD equip. Est 300 TN 0 0 0 0 20 6,000 6,900 STST 87.33 602,600 602,60023-17-23 Walkwayfrom U1 SDA's to U2 SDA's Est 20 TN 0 0 0 0 35 700 805 STST 87.33 70,300 70,30023-17-23 Access GalleryEst 1,500 SF 0.00 35.00 0 52,500 0.40 600 690 GALL 67.14 46,300 98,80027-17-99 Touch-up painting Est 2 LT 0.00 45,000.00 0 90,000 1800.00 3,600 4,140 PNTR 56.92 235,600 325,600Reagent Handling / Preparation- Civil / StructuralWorkOne common for both units0Foundations for Lime Storage Silo21-23-15 ExcavationEst 280 CY0.00 0.00 0 0 0.20 56 64 EXFD 63.95 4,100 4,10021-17-25 BackfillEst 80 CY0.00 0.00 0 0 0.30 24 28 EXFD 63.95 1,800 1,80022-13-37 ConcreteEst 200 CY0.00 105.00 0 21,000 1.50 300 345 CONP 51.69 17,800 38,80022-25-35 ReinforcingEst 18 TN 0.00 1,150.00 0 20,700 20.00 360 414 REIN 61.48 25,500 46,20022-17-25 FormworkEst 600 SF 0.00 2.50 0 1,500 0.14 81 93 FORM 71.62 6,700 8,20022-15-25 Embedded steel Est 0.50 TN 0.00 5,000.00 0 2,500 120.00 60 69 CARP 46.37 3,200 5,70023-25-75 Support Steel for lime Storage Silo Not required - concrete silo23-17-23 GalleriesEst 1,800 SF 0.00 35.00 0 63,000 0.40 720 828 GALL 67.14 55,600 118,60023-17-53 Stair Tower for Lime Storage SiloEst 120 TN 2,650 0 318,000 0 25 3,000 3,450 STST 87.33 301,300 619,30031-41-77 Fire Protection Standpipe & hose stations Est 1 LS 60,000.00 60,000 0 400.00 400 460 YDPP 63.15 29,000 89,000Lime Preparation / Recycle Building (55' x 100' x125'H)Quantities shown are total for 2buildings, 1/unit22 Substructure021-23-15 ExcavationEst 1,070 CY0.00 0 0 0.20 214 246 EXFD 63.95 15,700 15,70021-17-25 BackfillEst 70 CY0.00 0 0 0.30 21 24 EXFD 63.95 1,500 1,50022-13-37 ConcreteEst 1,000 CY105.00 0 105,000 1.50 1,500 1,725 CONP 51.69 89,200 194,20022-25-35 ReinforcingEst 75 TN 1,150.00 0 86,300 20.00 1,500 1,725 REIN 61.48 106,100 192,40022-17-25 FormworkEst 3,000 SF 2.50 0 7,500 0.14 405 466 FORM 71.62 33,400 40,90022-15-25 Embedded steel Est 2.50 TN 5,000.00 0 12,500 120.00 300 345 CARP 46.37 16,000 28,500Superstructure23-25-75Structural SteelEst900 TN 26500 2,384,400 16 14,396 16,556 STST 87.33 1,445,800 3,830,20024-41-25Insulated Metal SidingEst80,000 SF 120 960,000 0.11 8,800 10,120 SDNG 63.02 637,800 1,597,80024-15-15RollingOverhead Doorone for each buildingEst640 SF 270 17,300 0.25 160 184 CARP 46.37 8,500 25,80023-23-23Metal Roof DeckingEst11,000 SF 2.70 29,700 0.06 660 759 STST 87.33 66,300 96,00024-37-43Rigid Roof Insulation, 2" ThickEst11,000 SF 2.40 26,400 0.015 165 190 ROOF 45.55 8,600 35,00024-37-17Cant Strips, TreatedEst620 LF 1.320 800 0.035 22 25 ROOF 45.55 1,100 1,90024-37-73Roofing(4-PlyTar & Gravel)Est11,000 SF 1.550 17,100 0.04 440 506 ROOF 45.55 23,000 40,10022-13-43Lightweight Concrete Fill 1"Est247 CY1000 24,700 1.3 321 369 ROOF 45.55 16,800 41,50024-37-27Roof FlashingEst620 LF 14.450 9,000 0.12 74 86 ROOF 45.55 3,900 12,90035-13-31Roof DrainsEst2 LT 200000 40,000 250 500 575 PLMB 47.74 27,500 67,50035-13-31Floor DrainsEst2 LT 250000 50,000 300 600 690 PLMB 47.74 32,900 82,90022-13-23 Floor Slabsincludes metal decking andformworkEst 101 CY 210 0 21,200 7.5 756 870 CONP 51.69 45,000 66,20022-13-23 Floor FinishesEst8,250 SF 2.50 20,600 0.05 413 474 CONP 51.69 24,500 45,10024-25-25Louvers/Windows/DoorsEst8,000 SF 400 320,000 0.5 4,000 4,600 CONP 51.69 237,800 557,80034-41-99Roof VentilatorsEst8 EA 150000 120,000 24 192 221 HVAC 51.91 11,500 131,50023-17-23Galleries & LandingsEst800 SF 450 36,000 0.4 320 368 GALL 67.14 24,700 60,70034-55-99H&VEst11,000 SF 16.70 183,300 0.17 1,833 2,108 HVAC 51.91 109,400 292,70041-37-99Electrical Service & LightingEst11,000 SF 20.00 220,000 0.20 2,200 2,530 WIRE 66.93 169,300 389,30031-41-77 Fire Protection Standpipe & hose stations Est 2 LS 60,000.00 120,000 0 400.00 800 920 YDPP 63.15 58,100 178,10023Pipe Rack For Lime Handling, Waste AshHandling and misc Mechanical PipingQuantities shown are totalfor 2 units23-25-75 Structure and Support Steel Est 330 TN 0.00 2,650.00 0 874,500 20.00 6,600 7,590 STST 87.33 662,800 1,537,30022 Foundations for support steel0 0021-23-15 ExcavationEst 1,292 CY0.00 0.00 0 0 0.20 258 297 EXFD 63.95 19,000 19,00021-17-25 BackfillEst 342 CY0.00 0.00 0 0 0.30 103 118 EXFD 63.95 7,500 7,50022-13-37 ConcreteEst 950 CY0.00 105.00 0 99,800 1.50 1,425 1,639 CONP 51.69 84,700 184,50022-25-35 ReinforcingEst 71 TN 0.00 1,150.00 0 81,900 20.00 1,425 1,639 REIN 61.48 100,800 182,70022-17-25 FormworkEst 9,500 SF 0.00 2.50 0 23,800 0.14 1,283 1,475 FORM 71.62 105,600 129,40022-15-25 Embedded Steel Est 4,750 LB 0.00 2.50 0 11,900 0.05 238 273 CARP 46.37 12,700 24,60022 Foundations for Misc. Support SteelQuantities shown are total for 2units0 0021-23-15 ExcavationEst 272 CY0.00 0.00 0 0 0.20 54 63 EXFD 63.95 4,000 4,00021-17-25 BackfillEst 72 CY0.00 0.00 0 0 0.30 22 25 EXFD 63.95 1,600 1,60022-13-37 ConcreteEst 200 CY0.00 105.00 0 21,000 1.50 300 345 CONP 51.69 17,800 38,80022-25-35 ReinforcingEst 15 TN 0.00 1,150.00 0 17,300 20.00 300 345 REIN 61.48 21,200 38,50022-17-25 FormworkEst 2,000 SF 0.00 2.50 0 5,000 0.14 270 311 FORM 71.62 22,200 27,20022-15-25 Embedded Steel Est 1,000 LB 0.00 2.50 0 2,500 0.05 50 58 CARP 46.37 2,700 5,200Page 2 of 14OG & EEstimate No.: 30228 A1Sooner Units 1 & 2Project No.: 11418-019Dry FGD SystemsDate: 12/11/2009Conceptual Cost EstimatePrepared by: MNOCost Type:Reviewed by: RKEst=EstimatedApproved by: PEFAllow.=AllowanceWage Rates Based on: 9NUR06C= ContractLabor Productivity = 1.15Q=Vendor QuoteCode ofAccountsItem DescriptionScope DefinitionCost TypeQuantityUnit ofMeasureUnit Equip.CostUnit MaterialCostTotal EquipmentCostTotal Material CostCost DevelopmentUnit Man-hours(Base)Total Man-hours(Base)Total Man-hours, Prod =1.15CrewCodeCrewWageRateTotal Construction& Erection CostTotal ProjectedCost23-25-75 Misc. Support Steel not included elsewhereQuantities shown are total for 2unitsEst 100 TN 0 2,650 0 265,000 20 2,000 2,300 STST 87.33 200,900 465,90023-17-23 Misc. GalleriesQuantities shown are total for 2unitsEst 3,000 SF 0.00 35.00 0 105,000 0.40 1,200 1,380 GALL 67.14 92,700 197,700Fabric Filter24,079,500 4,622,500 279,365 17,633,000 46,335,00031-57-15 Fabric Filter System Q 2 LT 9,912,416 0.00 19,824,800 080,500 161,000 185,150 MECH 61.53 11,392,300 31,217,10031-17-45 Fabric Filter Baghouse Air Compressor SystemQ 2 LT 2,027,372 0.00 4,054,700 0 17,900 35,800 41,170 MECH 61.53 2,533,200 6,587,90035-13-15 Fabric Filter Baghouse Compressor System PipingIncluded in air compressorsystempricingEst 2 LT 0.00 0.00 0 0 0 0 0 MECH 61.53 0 031-27-35 Fabric Filter Bypass DampersIncluded in Fabric Filter SystemPriceEst 2 LT 0.00 0.00 0 0 0 0 0 MECH 61.53 0 031-57-99 Hopper HeatersIncluded in Fabric Filter SystemPriceEst 2 LT 0.00 0.00 0 0 0 0 0 MECH 61.53 0 031-57-99 Vent FanIncluded in Fabric Filter SystemPriceEst 2 LT 0.00 0.00 0 0 0 0 0 MECH 61.53 0 031-25-35 Hoist & Trolley BeamIncluded in Fabric Filter SystemPriceEst 2 LT 0.00 0.00 0 0 0 0 0 MECH 61.53 0 036-13-23Insulation for Baghousesubcontract costEst 65,111 SF 0.00 30.00 0 1,953,300 0 0 0 DINS 52.16 0 1,953,30023-25-75 Penthouse steel for baghousesSupport steel, roof steel, girtsand purlins.Est 79 TN 0.00 2,650.00 0 209,300 35.00 2,765 3,179 STST 87.33 277,600 486,90024-41-25 Siding for baghouse penthouse insulated metal siding Est 12,960 SF 0.00 12 0 155,500 0.11 1,426 1,639 SDNG 63.02 103,300 258,80024-37-47 Roofing for baghouse penthouse standing seam type Est 5,751 SF 0.00 18 0 103,500 0.22 1,265 1,455 ROOF 45.55 66,300 169,80022-13-23 Concrete bottom floor for baghouse penthouseincludes metal decking andformworkEst 70 CY 210 0 14,800 7.5 527 606 CONP 51.69 31,300 46,10041-37-99 BuildingServices H&V and LightingEst 5,751 SF 0.00 22.00 0 126,500 0.20 1,150 1,323 WIRE 66.93 88,500 215,00031-41-77 Fire Protection for Penthouse Standpipe & hose stations Est 2 LS 60,000.00 120,000 400.00 800 920 MECH 61.53 56,600 176,60023-25-75 Bottom Enclosure steelSupport steel, girts and purlins.Total for Units 1&2Est 171 TN 0.00 2,650.00 0 453,900 20 3,426 3,939 STST 87.33 344,000 797,90041-37-99 BuildingServices H&V and LightingEst 19,880 SF 0.00 22.00 0 437,400 0.20 3,976 4,572 WIRE 66.93 306,000 743,40024-41-25 Siding for baghouse bottom enclosureinsulated metal siding, supportsteel and girts included inAlstom pricingEst 17,976 SF 0.00 12 0 215,700 0.11 1,977 2,274 SDNG 63.02 143,300 359,00031-41-77 Fire Protection for bottom enclosure Standpipe & hose stations Est 2 LS 40,000.00 0.00 80,000 0 300.00 600 690 MECH 61.53 42,500 122,500Fabric Filter System - Structural0Foundations for Fabric Filter BaghouseQuantities shown are total for 2units21-23-15 ExcavationEst 3,852 CY0.00 0.00 0 0.20 770 886 EXFD 63.95 56,700 56,70021-17-25 BackfillEst 252 CY0.00 0.00 0 0.30 76 87 EXFD 63.95 5,600 5,60022-13-37 ConcreteEst 3,600 CY0.00 105.00 0 378,000 1.50 5,400 6,210 CONP 51.69 321,000 699,00022-25-35 ReinforcingEst 324 TN 0.00 1,150.00 0 372,600 20.00 6,480 7,452 REIN 61.48 458,100 830,70022-17-25 FormworkEst 10,800 SF 0.00 2.50 0 27,000 0.14 1,458 1,677 FORM 71.62 120,100 147,10022-15-25 Embedded Steel Est 9.00 TN 0.00 5,000.00 45,000 120.00 1,080 1,242 CARP 46.37 57,600 102,600Support Steel and Access Gallery023-25-75 Support SteelIncluded in Baghouse equippriceQ 420 TN 0.00 0 0 0 25 10,500 12,075 STST 87.33 1,054,500 1,054,50023-17-23 Access GalleryQ 3,000 SF 0.00 35.00 0 105,000 0.40 1,200 1,380 GALL 67.14 92,700 197,70027-17-99 Touch-up painting Est 1 LT 0.00 25,000.00 0 25,000 1250.00 1,250 1,438 PNTR 56.92 81,800 106,8000Ash Recycling System - DFGDContractor's Scope6,843,000 0 69,460 4,273,900 11,116,900Page 3 of 14OG & EEstimate No.: 30228 A1Sooner Units 1 & 2Project No.: 11418-019Dry FGD SystemsDate: 12/11/2009Conceptual Cost EstimatePrepared by: MNOCost Type:Reviewed by: RKEst=EstimatedApproved by: PEFAllow.=AllowanceWage Rates Based on: 9NUR06C= ContractLabor Productivity = 1.15Q=Vendor QuoteCode ofAccountsItem DescriptionScope DefinitionCost TypeQuantityUnit ofMeasureUnit Equip.CostUnit MaterialCostTotal EquipmentCostTotal Material CostCost DevelopmentUnit Man-hours(Base)Total Man-hours(Base)Total Man-hours, Prod =1.15CrewCodeCrewWageRateTotal Construction& Erection CostTotal ProjectedCost31-45-99Ash Recycling System - Mechanical2 LT 3,421,528 6,843,00030200 60,400 69,460 MECH 61.53 4,273,900 11,116,90031-45-99 Recycle Ash Storage SiloIncluded in Ash RecyclingSystem PriceQ 0.00 0.00 0 0 0 0 0 MECH 61.53 0 031-45-99 Recycle Ash Silo Bin VentIncluded in Ash RecyclingSystem PriceQ 0.00 0.00 0 0 0 0 0 MECH 61.53 0 031-45-99 Recycle Ash Fluidizing Air BlowerIncluded in Ash RecyclingSystem PriceQ 0.00 0.00 0 0 0 0 0 MECH 61.53 0 031-45-99 Recycle Ash Fluidizing Air HeaterIncluded in Ash RecyclingSystem PriceQ 0.00 0.00 0 0 0 0 0 MECH 61.53 0 031-45-99 Recycle Ash Silo Discharge Rotary FeederIncluded in Ash RecyclingSystem PriceQ 0.00 0.00 0 0 0 0 0 MECH 61.53 0 031-45-99 Recycle Slurry Vibrating ScreenIncluded in Ash RecyclingSystem PriceQ 0.00 0.00 0 0 0 0 0 MECH 61.53 0 031-45-99 Recycle Ash Prep Area Sump TankIncluded in Ash RecyclingSystem PriceQ 0.00 0.00 0 0 0 0 0 MECH 61.53 0 031-45-99 Recycle Ash Prep Area Sump Tank AgitatorIncluded in Ash RecyclingSystem PriceQ 0.00 0.00 0 0 0 0 0 MECH 61.53 0 031-45-99 Recycle Ash Slurry Mix TankIncluded in Ash RecyclingSystem PriceQ 0.00 0.00 0 0 0 0 0 MECH 61.53 0 031-45-99 Recycle Ash Slurry Mix Tank AgitatorIncluded in Ash RecyclingSystem PriceQ 0.00 0.00 0 0 0 0 0 MECH 61.53 0 031-45-99 Recycle Slurry Storage TankIncluded in Ash RecyclingSystem PriceQ 0.00 0.00 0 0 0 0 0 MECH 61.53 0 031-45-99 Recycle Slurry Storage Tank AgitatorIncluded in Ash RecyclingSystem PriceQ 0.00 0.00 0 0 0 0 0 MECH 61.53 0 031-45-99 Recycle Slurry Feed PumpsIncluded in Ash RecyclingSystem PriceQ 0.00 0.00 0 0 0 0 0 MECH 61.53 0 0Ash RecyclingSystem - BOP Scope60,000 534,800 4,583 360,800 955,600Ash Reagent Recycle BuildingIncluded with Lime PreparationBuilding24-35Ash Handling Blower Building (25' x 50' x 25'H)Quantities shown are total for 2buildings, 1/unit22-13 Substructure021-23-15 ExcavationEst 214 CY0.00 0.00 0 0 0.20 43 49 EXFD 63.95 3,100 3,10021-17-25 BackfillEst 14 CY0.00 0.00 0 0 0.30 4 5 EXFD 63.95 300 30022-13-37 ConcreteEst 200 CY0.00 105.00 0 21,000 1.50 300 345 CONP 51.69 17,800 38,80022-25-35 ReinforcingEst 15 TN 0.00 1,150.00 0 17,300 20.00 300 345 REIN 61.48 21,200 38,50022-17-25 FormworkEst 800 SF 0.00 2.50 0 2,000 0.14 108 124 FORM 71.62 8,900 10,90022-15-25 Embedded Steel Est 1,600 LB 0.00 2.50 0 4,000 0.05 80 92 CARP 46.37 4,300 8,30024-35-25 Pre-engineered buildingIncludes H&V and LightingEst 2,500 SF 0.00 175.00 0 437,500 0.90 2,250 2,588 STST 87.33 226,000 663,50023-25-75 Additional Support Steel for Waste Ash Pipes outside of pipe rack Est 20 TN 0.00 2,650.00 0 53,000 25.00 500 575 STST 87.33 50,200 103,20031-41-77 Fire Protection Standpipe & hose stations Est 2 LS 30,000 60,000 200.00 400 460 YDPP 63.15 29,000 89,0000Waste Ash and Fly Ash HandlingSystem10,131,300 339,300 60,951 3,795,000 14,265,60033Waste Ash HandlingSystem - Mechanical026-13-15 Waste Ash siloConcrete silo - subcontractpriceQ 1 LT 1,550,000 0.00 1,550,000 00.00 0 0 CONP 51.69 0 1,550,00024-17-15 Elevator for waste ash silomaintenance elvator -subcontractpriceEst 1 LT 290,000 0.00 290,000 0 0 0 0 MECH 61.53 0 290,00022-13-27 Concrete pit for the elevator total for 2 silo elevators Est 10 CY 0 210.00 0 2,100 7.5 75 86 CONP 51.69 4,500 6,60041-99-99 Electrical work for the elevatorallowance Est 1 LT 0 20,000.00 0 20,000 175 175 201 WIRE 66.93 13,500 33,50033-13-45 Waste Handling SystsemIncludes blowers, ash valves,and ash pipingQ 1 LT 5,300,000 0.00 5,300,000 030,000 30,000 34,500 MECH 61.53 2,122,800 7,422,80033-13-45 Mechanical EquipmentEst 0 0.00 0 0 0 0 0 MECH 61.53 0 033-13-45 Mechanical BlowersIncluded in Waste HandlingSystem PriceEst 0 0.00 0 0 0 0 0 MECH 61.53 0 0Page 4 of 14OG & EEstimate No.: 30228 A1Sooner Units 1 & 2Project No.: 11418-019Dry FGD SystemsDate: 12/11/2009Conceptual Cost EstimatePrepared by: MNOCost Type:Reviewed by: RKEst=EstimatedApproved by: PEFAllow.=AllowanceWage Rates Based on: 9NUR06C= ContractLabor Productivity = 1.15Q=Vendor QuoteCode ofAccountsItem DescriptionScope DefinitionCost TypeQuantityUnit ofMeasureUnit Equip.CostUnit MaterialCostTotal EquipmentCostTotal Material CostCost DevelopmentUnit Man-hours(Base)Total Man-hours(Base)Total Man-hours, Prod =1.15CrewCodeCrewWageRateTotal Construction& Erection CostTotal ProjectedCost33-13-45Waste Ash Silo Unloading Equipment includingFluidizing BlowersIncluded in Waste HandlingSystem Handling PriceEst 0 0.00 0 0 0 0 0 MECH 61.53 0 033-13-45Waste Ash Vacuum Pipes from FF hoppers toFilter SeparatorsIncluded in Waste HandlingSystem Handling PriceEst 0 0.00 0 0 0 0 0 MECH 61.53 0 033-13-45 Motor Operated Butterfly ValvesIncluded in Waste HandlingSystem HandlingPriceEst 0 0.00 0 0 0 0 0 MECH 61.53 0 022-13-75 Fly Ash SiloField erected steel silo. Pricingincludes mechanical equipmentand ash pipingEst 75 TN 4,000 0.00 300,000 0 70 5,250 6,038 TANK 61.57 371,700 671,70033-13-45Mechanical equipment for ash handling system andsilo fly ash unloading equipmentEst 1 LT 2,500,000 0.00 2,500,000 0 10,000 10,000 11,500 MECH 61.53 707,600 3,207,600Foundations for Fly Ash Silo021-23-15 ExcavationEst 80 CY0.00 0.00 0 0.20 16 18 EXFD 63.95 1,200 1,20021-17-25 BackfillEst 30 CY0.00 0.00 0 0.30 9 10 EXFD 63.95 700 70022-13-37 ConcreteEst 50 CY0.00 105.00 0 5,300 1.50 75 86 CONP 51.69 4,500 9,80022-25-35 ReinforcingEst 5 TN 0.00 1,150.00 0 5,200 20.00 90 104 REIN 61.48 6,400 11,60022-17-25 FormworkEst 150 SF 0.00 2.50 0 400 0.14 20 23 FORM 71.62 1,700 2,10022-15-25 Embedded Steel Est 0.13 TN 0.00 5,000.00 600 120.00 15 17 CARP 46.37 800 1,40023-25-75 Support Steel for Fly Ash Storage Silo Est 50 TN 0.00 2,650.00 0 132,500 35.00 1,750 2,013 STST 87.33 175,800 308,30023-17-23 Access Gallery for fly ash silo Included with Misc Galleries. 0 SF 0 35 0 0 0.40 0 0 GALL 67.14 0 033-57-65 Truck ScaleEst 1 LT 125,000 0 125,000 0 900 900 1,035 MECH 61.53 63,700 188,70022-13-37 Concrete foundation and approach for truck scaleEst 350 CY0 210 0 73,500 7.50 2,625 3,019 CONP 51.69 156,000 229,50041-99-99 Electrical allowance for truck scaleEst 1 LT 0 15,000 0 15,000 200.00 200 230 WIRE 66.93 15,400 30,400Foundations for Waste Ash Silo021-23-15 ExcavationEst 176 CY0.00 0.00 0 0.20 35 40 EXFD 63.95 2,600 2,60021-17-25 BackfillEst 66 CY0.00 0.00 0 0.30 20 23 EXFD 63.95 1,500 1,50022-13-37 ConcreteEst 110 CY0.00 105.00 0 11,600 1.50 165 190 CONP 51.69 9,800 21,40022-25-35 ReinforcingEst 10 TN 0.00 1,150.00 0 11,400 20.00 198 228 REIN 61.48 14,000 25,40022-17-25 FormworkEst 330 SF 0.00 2.50 0 800 0.14 45 51 FORM 71.62 3,700 4,50022-15-25 Embedded Steel Est 0.28 TN 0.00 5,000.00 1,400 120.00 33 38 CARP 46.37 1,800 3,20023-25-75 Support Steel for Waste Ash Storage Silo concrete silo Est 0 TN 0.00 2,650.00 0 0 35.00 0 0 STST 87.33 0 023-17-53 Stair Tower for Waste Ash Silo Est 25 TN 2,650 0 66,300 0 25 625 719 STST 87.33 62,800 129,10023-17-23 Access Gallery for waste ash silo Est 1,700 SF 0 35 0 59,500 0.40 680 782 GALL 67.14 52,500 112,0000Flue Gas System5,558,000 14,067,000 338,089 22,838,000 42,463,000Spray Dryer Absorber Inlet Duct (from Existing IDFan Outlet)Quantities are total for 2 units023-15-35Ductwork Steel, including plate, stiffeners, internalbracing, turning vanes and walkway gratingEst 1,600 TN 0.00 3,250.00 0 5,200,000 60.00 96,000 110,400 FLDU 77.18 8,520,700 13,720,70036-13-57 Insulation & LaggingEst 152,000 SF 0.00 12.00 0 1,824,000 0.26 39,520 45,448 DINS 52.16 2,370,600 4,194,60031-33-15 Expansion JointsEst 3,200 LF 0.00 230.00 0 736,000 2.50 8,000 9,200 MECH 61.53 566,100 1,302,10031-27-35 Dampers Not Required44-21-99 Dry FGD Inlet Ductwork Instrumentation Est 4 LS 30,000.00 0.00 120,000 0 200 800 920 INEL 54.22 49,900 169,900Spray Dryer Absorber Outlet to Fabric Filter InletQuantities are total for 2 units023-15-35Ductwork Steel, including plate, stiffeners, internalbracing, turning vanes and walkway gratingincluded in DFGD equipmentsupply pricing36-13-57 Insulation & LaggingAllow 50,000 SF 0.00 12.00 0 600,000 0.26 13,000 14,950 DINS 52.16 779,800 1,379,80031-33-15 Expansion JointsMaterial price is included inDFGD contract costEst 275 LF 0.00 0.00 0 0 2.50 688 791 MECH 61.53 48,600 48,60044-21-99 Dry FGD Outlet Ductwork InstrumentationMaterial price is included inDFGD contract costEst 1 LS 0.00 0.00 0 0 200 200 230 INEL 54.22 12,500 12,50031-27-35 Dampers Not required Est 0 SF 450.00 0.00 0 0 3.00 0 0 MECH 61.53 0 0Fabric Filter Outlet Duct to Booster Fans andBooster ID Fans to existing chimney breechingQuantities are total for 2 units0Page 5 of 14OG & EEstimate No.: 30228 A1Sooner Units 1 & 2Project No.: 11418-019Dry FGD SystemsDate: 12/11/2009Conceptual Cost EstimatePrepared by: MNOCost Type:Reviewed by: RKEst=EstimatedApproved by: PEFAllow.=AllowanceWage Rates Based on: 9NUR06C= ContractLabor Productivity = 1.15Q=Vendor QuoteCode ofAccountsItem DescriptionScope DefinitionCost TypeQuantityUnit ofMeasureUnit Equip.CostUnit MaterialCostTotal EquipmentCostTotal Material CostCost DevelopmentUnit Man-hours(Base)Total Man-hours(Base)Total Man-hours, Prod =1.15CrewCodeCrewWageRateTotal Construction& Erection CostTotal ProjectedCost23-15-35Ductwork Steel, including plate, stiffeners, internalbracing, turning vanes and walkway gratingEst 560 TN 0.00 3,250.00 0 1,820,000 60.00 33,600 38,640 FLDU 77.18 2,982,200 4,802,20036-13-57 Insulation & LaggingEst 56,000 SF 0.00 12.00 0 672,000 0.26 14,560 16,744 DINS 52.16 873,400 1,545,40031-33-15 Expansion JointsEst 1,800 LF 0.00 230.00 0 414,000 2.50 4,500 5,175 MECH 61.53 318,400 732,40031-27-35 Dampers Not required Est 0 SF 450.00 0.00 0 0 2.50 0 0 MECH 61.53 0 044-21-99 Fabric Filter Outlet Ductwork Instrumentation Est 4 LS 30,000.00 0.00 120,000 0 200 800 920 INEL 54.22 49,900 169,900Booster ID FansQuantities are total for 2 units031-35-15 New Booster ID FansAxial fan, 2 x 50% per unit,882,450 cfm, includes fanauxiliaryequipmentEst 4 EA 775,000 0.00 3,100,000 03000.00 12,000 13,800 MECH 61.53 849,100 3,949,10041-43-35 Motors for Booster ID Fans 3300 HP Est 4 EA 247,000 0.00 988,000 01000.00 4,000 4,600 MECH 61.53 283,000 1,271,00031-25-35 Hoist & trolleys for Booster ID Fans 5-ton cap Est 4 EA 15,000 0.00 60,000 0 150.00 600 690 MECH 61.53 42,500 102,50036-13-23 Fan Insulation & Laggingtotal for two fansEst 6,000 SF 0.00 12.00 0 72,000 0.28 1,680 1,932 DINS 52.16 100,800 172,80031-27-35 Booster ID Fans Isolation DampersSingle Louver type damperassemblyEst 2,400 SF 450.00 0.00 1,080,000 0 2.50 6,000 6,900 MECH 61.53 424,600 1,504,600Flue Gas System - StructuralDuctwork Support Foundations Total for all ductwork for 2 units021-23-15 ExcavationEst 2,140 CY0.00 0.00 0 0.20 428 492 EXFD 63.95 31,500 31,50021-17-25 BackfillEst 140 CY0.00 0.00 0 0.30 42 48 EXFD 63.95 3,100 3,10022-13-37 ConcreteEst 2,000 CY0.00 105.00 0 210,000 1.50 3,000 3,450 CONP 51.69 178,300 388,30022-25-35 ReinforcingEst 150 TN 0.00 1,150.00 0 172,500 20.00 3,000 3,450 REIN 61.48 212,100 384,60022-17-25 FormworkEst 6,000 SF 0.00 2.50 0 15,000 0.14 810 932 FORM 71.62 66,700 81,70022-15-25 Embedded Steel Est 5.00 TN 0.00 5,000.00 25,000 120.00 600 690 CARP 46.37 32,000 57,00023-25-75 Structural Steel Duct SupportsEst 580 TN 0.00 2,650.00 0 1,537,000 35.00 20,300 23,345 STST 87.33 2,038,700 3,575,700ID Fan FoundationsQuantities are total for 2 units0021-23-15 ExcavationEst 2,033 CY0.00 0.00 0 0.20 407 468 EXFD 63.95 29,900 29,90021-17-25 BackfillEst 133 CY0.00 0.00 0 0.30 40 46 EXFD 63.95 2,900 2,90022-13-37 ConcreteEst 1,900 CY0.00 105.00 0 199,500 1.50 2,850 3,278 CONP 51.69 169,400 368,90022-25-35 ReinforcingEst 143 TN 0.00 1,150.00 0 163,900 20.00 2,850 3,278 REIN 61.48 201,500 365,40022-17-25 FormworkEst 15,200 SF 0.00 2.50 0 38,000 0.14 2,052 2,360 FORM 71.62 169,000 207,00022-15-25 Embedded Steel Est 9.50 TN 0.00 5,000.00 0 47,500 120.00 1,140 1,311 CARP 46.37 60,800 108,30023-17-23 Access Gallery for all inlet and outlet ductwork Est 3,000 SF 0 35.00 0 105,000 0.40 1,200 1,380 GALL 67.14 92,700 197,70041-37-43 Lightingfor accessgalleries and Booster Fan areaEst 6,000 SF 0.00 15.00 0 90,000 0.15 900 1,035 WIRE 66.93 69,300 159,300Stack CoatingAcid resistant coating - top50 ft of liner. Assumedchimney liner 20Ft dia x 500ft high61-23-35 Suspended Motorized Modular Platform Rental90 dayrental, each stackEst. 2 LT 45,000.00 0.00 90,000 0 300.00 600 690 CARP 46.37 32,000 122,00027-15-35Prep and clean top 50ft of two flues (inside only) towhite metal(SSPC-SP 5)Quantities shown are for 2stacks. Includes misc. repairsEst. 6,400 SF 0.00 0.00 0 0 1.33 8,512 9,789 PNTR 56.92 557,200 557,20027-13-99 Apply acid resistant coatingQuantities shown are for 2stacks.Est. 6,400 SF 0.00 16.50 0 105,600 1.33 8,512 9,789 PNTR 56.92 557,200 662,80061-17-43 TemporaryPower, Light and VentilationEst. 2 LT 0.00 10,000.00 0 20,000 400.00 800 920 WIRE 66.93 61,600 81,600Mechanical - Balance of Plant0 2,913,900 60,105 3,977,400 6,891,300PipingVacuum Conveying35-13-99Vacuum conveyingto lime siloEst LF 0.00 57.60 0 0 1.50 0 0 SPNG 67.64 0 0Makeup Water35-13-158" CS, SCH 40, includes fittings, undergroundRaw water to reagentprepEst 1,130 LF 0.00 130.20 0 147,100 1.88 2,124 2,443 YDPP 63.15 154,300 301,40035-13-156" CS, SCH 40, includes fittings, undergroundRaw water to reagentprepEst 120 LF 0.00 89.50 0 10,700 1.60 192 221 YDPP 63.15 13,900 24,60021-25-15 Excavation for Underground PipingEst 628 CY0.00 0.00 0 0 0.20 126 144 EXFD 63.95 9,200 9,20021-17-15 Beddingfor Underground PipingEst 94 CY0.00 40.00 0 3,800 0.30 28 32 EXFD 63.95 2,100 5,900Page 6 of 14OG & EEstimate No.: 30228 A1Sooner Units 1 & 2Project No.: 11418-019Dry FGD SystemsDate: 12/11/2009Conceptual Cost EstimatePrepared by: MNOCost Type:Reviewed by: RKEst=EstimatedApproved by: PEFAllow.=AllowanceWage Rates Based on: 9NUR06C= ContractLabor Productivity = 1.15Q=Vendor QuoteCode ofAccountsItem DescriptionScope DefinitionCost TypeQuantityUnit ofMeasureUnit Equip.CostUnit MaterialCostTotal EquipmentCostTotal Material CostCost DevelopmentUnit Man-hours(Base)Total Man-hours(Base)Total Man-hours, Prod =1.15CrewCodeCrewWageRateTotal Construction& Erection CostTotal ProjectedCost21-17-25 Backfill for Underground PipingEst 534 CY0.00 0.00 0 0 0.30 160 184 EXFD 63.95 11,800 11,80035-13-15 2.5" CS, SCH 40, includes fittings Slaker water and dilution water Est 320 LF 0.00 35.60 0 11,400 1.28 410 471 SPNG 67.64 31,900 43,30035-13-15 2.5" CS, SCH 80, includes fittings Slaker water and dilution water Est 320 LF 0.00 55.50 0 17,800 1.44 461 530 SPNG 67.64 35,800 53,60035-13-154" CS, SCH 40, includes fittings Recycle waterEst 1,190 LF 0.00 57.60 0 68,500 1.50 1,785 2,053 SPNG 67.64 138,800 207,30035-13-33Pipe Supports for MakeupWaterpipingEst 2.58 TN 0.00 2,650.00 0 6,800 40.00 103 119 STST 87.33 10,400 17,200Service Water35-13-15 6" CS, SCH 40, includes fittings, undergroundExtend existing service waterline to new lime unloadingareaEst 810 LF 0.00 89.50 0 72,500 1.60 1,296 1,490 YDPP 63.15 94,100 166,60035-13-15 3" CS, SCH 40, includes fittings, undergroundReagent prep building abd flyash silosEst 1,520 LF 0.00 48.80 0 74,200 1.37 2,082 2,395 YDPP 63.15 151,200 225,40021-25-15 Excavation for Underground PipingEst 1,294 CY0.00 0.00 0 0 0.20 259 298 EXFD 63.95 19,000 19,00021-17-15 Beddingfor Underground PipingEst 194 CY0.00 40.00 0 7,800 0.30 58 67 EXFD 63.95 4,300 12,10021-17-25 Backfill for Underground PipingEst 1,100 CY0.00 0.00 0 0 0.30 330 380 EXFD 63.95 24,300 24,30035-13-153" CS, SCH 40, includes fittings Absorbers(penthouse)Est 680 LF 0.00 48.80 0 33,200 1.37 932 1,071 SPNG 67.64 72,500 105,70035-15-15 2" CS, SCH 80, includes fittingsReagent prep building,absorbers (penthouse), fly ashsilosEst 600 LF 0.00 39.80 0 23,900 1.36 816 938 SPNG 67.64 63,500 87,40035-13-33Pipe Supports for Service WaterpipingEst 1.51 TN 0.00 2,650.00 0 4,000 40.00 60 69 STST 87.33 6,100 10,100Lime SlurryPipe35-13-15 2.5" CS, SCH 80, includes fittingsReagent prep to atomizer headtank in SDAEst 1,200 LF 0.00 55.50 0 66,600 1.44 1,728 1,987 SPNG 67.64 134,400 201,00035-13-33Pipe Supports for Service WaterpipingEst 1.76 TN 0.00 2,650.00 0 4,700 40.00 70 81 STST 87.33 7,100 11,800Ash Pipe35-13-99 10" Ashcolite, flangedSupports included with piperackEst 1,440 LF 0.00 165.00 0 237,600 1.75 2,520 2,898 YDPP 63.15 183,000 420,60035-13-33Pipe supports within buildingboundariesEst 10 EA 0.00 125.00 0 1,300 3.00 30 35 STST 87.33 3,000 4,300Recycle SlurryPipe35-13-15 6" CS, SCH 80, includes fittings, undergroundRecycle ash silo to atomizerhead tankEst 1,200 LF 0.00 135.20 0 162,200 1.94 2,328 2,677 YDPP 63.15 169,100 331,30035-13-33Pipe Supports for Recycle SlurrypipingEst 4.28 TN 0.00 2,650.00 0 11,400 40.00 171 197 STST 87.33 17,200 28,600SlurryReturn Pipe35-13-156" CS, SCH 80, includes fittings, undergroundSDA to reagentprepEst 1,200 LF 0.00 135.20 0 162,200 1.94 2,328 2,677 YDPP 63.15 169,100 331,30035-13-33Pipe Supports for Recycle SlurrypipingEst 4.28 TN 0.00 2,650.00 0 11,400 40.00 171 197 STST 87.33 17,200 28,600SumpDischarge / Drains35-13-15 2.5" CS, SCH 40, includes fittings Absorber and Prep Building Est 260 LF 0.00 35.60 0 9,300 1.28 333 383 SPNG 67.64 25,900 35,20035-13-154" CS, SCH 40, includes fittings ReagentprepbuildingEst 3,250 LF 0.00 57.60 0 187,200 1.50 4,875 5,606 SPNG 67.64 379,200 566,40035-13-33Pipe Supports for SumpDischarge and DrainsEst 5.19 TN 0.00 2,650.00 0 13,800 40.00 208 239 STST 87.33 20,900 34,70035-13-213" HDPE includes fittings Undeground. Absorber SumpsEst 580 LF 0.00 4.80 0 2,800 1.37 795 914 SPNG 67.64 61,800 64,60035-13-214" HDPE includes fittings FlyAsh Silos, Lime Silos Est 3,620 LF 0.00 4.80 0 17,400 1.48 5,358 6,161 SPNG 67.64 416,700 434,10021-25-15 Excavation for Underground PipingEst 1,556 CY0.00 0.00 0 0 0.20 311 358 EXFD 63.95 22,900 22,90021-17-15 Beddingfor Underground PipingEst 233 CY0.00 40.00 0 9,300 0.30 70 81 EXFD 63.95 5,100 14,40021-17-25 Backfill for Underground PipingEst 1,322 CY0.00 0.00 0 0 0.30 397 456 EXFD 63.95 29,200 29,200Fire Protection35-13-35 6" HDPE, includes fittingsExtend existing and new forAbsorber, Reagent Prep, FlyAsh Silos and Lime SilosEst 1,640 LF 0.00 8.50 0 13,900 0.60 984 1,132 SPNG 67.64 76,500 90,40021-25-15 Excavation for Underground PipingEst 759 CY0.00 0.00 0 0 0.20 152 175 EXFD 63.95 11,200 11,20021-17-15 Beddingfor Underground PipingEst 114 CY0.00 40.00 0 4,600 0.30 34 39 EXFD 63.95 2,500 7,10021-17-25 Backfill for Underground PipingEst 645 CY0.00 0.00 0 0 0.30 194 223 EXFD 63.95 14,200 14,20035-13-15 3" CS, SCH 40, includes fittingsAbsorber, Reagent Prep, FlyAsh Silos and Lime SilosEst 1,120 LF 0.00 48.80 0 54,700 1.37 1,534 1,765 SPNG 67.64 119,400 174,10035-13-33Pipe Supports for Fire ProtectionEst 1.44 TN 0.00 2,650.00 0 3,800 40.00 58 66 STST 87.33 5,800 9,600Service AirPage 7 of 14OG & EEstimate No.: 30228 A1Sooner Units 1 & 2Project No.: 11418-019Dry FGD SystemsDate: 12/11/2009Conceptual Cost EstimatePrepared by: MNOCost Type:Reviewed by: RKEst=EstimatedApproved by: PEFAllow.=AllowanceWage Rates Based on: 9NUR06C= ContractLabor Productivity = 1.15Q=Vendor QuoteCode ofAccountsItem DescriptionScope DefinitionCost TypeQuantityUnit ofMeasureUnit Equip.CostUnit MaterialCostTotal EquipmentCostTotal Material CostCost DevelopmentUnit Man-hours(Base)Total Man-hours(Base)Total Man-hours, Prod =1.15CrewCodeCrewWageRateTotal Construction& Erection CostTotal ProjectedCost35-13-15 3" CS, SCH 40, includes fittingsAbsorber, Reagent Prep, FlyAsh Silos and Lime SilosEst 2,980 LF 0.00 48.80 0 145,400 1.37 4,083 4,695 SPNG 67.64 317,600 463,00035-15-15 2" CS, SCH 80, includes fittingsReagent prep building,absorbers (penthouse), fly ashsilosEst 1,000 LF 0.00 39.80 0 39,800 1.36 1,360 1,564 SPNG 67.64 105,800 145,60035-13-33Pipe Supports for Service AirEst 4.89 TN 0.00 2,650.00 0 13,000 40.00 196 225 STST 87.33 19,700 32,700Instrument Air35-15-13 2" 304SS, SCH 80, weldedAbsorber, Reagent Prep, FlyAsh Silos and Lime SilosEst 2,300 LF 0.00 101.42 0 233,300 1.63 3,743 4,305 SPNG 67.64 291,200 524,50035-15-13 1.5" 304SS, SCH 80, welded FlyAsh Silos and Lime SilosEst 680 LF 0.00 73.37 0 49,900 1.51 1,028 1,182 SPNG 67.64 80,000 129,90035-15-13 1" 304SS, SCH 80, weldedAbsorber, Reagent Prep, FlyAsh Silos and Lime SilosEst 1,140 LF 0.00 44.22 0 50,400 1.46 1,664 1,913 SPNG 67.64 129,400 179,80035-13-33Pipe Supports for Instrument AirEst 8.81 TN 0.00 2,650.00 0 23,400 40.00 352 405 STST 87.33 35,400 58,800Valves31-41-47 HydrantsEst 4 EA 0.00 1,500.00 0 6,000 6.00 24 28 YDPP 63.15 1,700 7,70035-13-41 Valves with PIVS 6", CI Est 6 EA 0.00 575.00 0 3,500 6.00 36 41 YDPP 63.15 2,600 6,10035-15-411" CS BallEst 4 EA 0.00 150.00 0 600 3.00 12 14 SPNG 67.64 900 1,50035-15-412" Bronze, BallEst 4 EA 0.00 750.00 0 3,000 4.00 16 18 SPNG 67.64 1,200 4,20035-13-41 3" CS, Globe, welded Est 32 EA 0.00 1,800.00 0 57,600 4.00 128 147 SPNG 67.64 10,000 67,60035-13-41 6" CS Knifegate, welded Est 4 EA 0.00 3,200.00 0 12,800 8.00 32 37 SPNG 67.64 2,500 15,30035-13-41 8" CS Knifegate, welded Est 20 EA 0.00 4,800.00 0 96,000 10.00 200 230 SPNG 67.64 15,600 111,60035-13-41 12" CS Knifegate, welded Est 8 EA 0.00 7,200.00 0 57,600 14.00 112 129 SPNG 67.64 8,700 66,30035-15-41Small bore valves, CS wededl Allowance Est 1 LT 0.00 10,000.00 0 10,000 60.00 60 69 SPNG 67.64 4,700 14,70031-75-17 MakeupWaterpumps 1000gpm, 200 ft TDH Est 2 EA 0.00 30,000.00 0 60,000 40.00 80 92 MECH 61.53 5,700 65,70031-75-93 SumpPumps 440gpm, 220 TDH Est 8 EA 0.00 25,000.00 0 200,000 30.00 240 276 MECH 61.53 17,000 217,00031-17-45 Air compressors 250 SCFM, 100psigEst 2 EA 0.00 45,000.00 0 90,000 60.00 120 138 MECH 61.53 8,500 98,50031-17-65 Air receivers 1000 Gal Est 2 EA 0.00 7,000.00 0 14,000 20.00 40 46 MECH 61.53 2,800 16,80031-17-55 Air dryers250 net SCFM, 100psigEst 2 EA 0.00 15,000.00 0 30,000 30.00 60 69 MECH 61.53 4,200 34,20031-65-99 In-line electric water heaters(boilers)475 kW Est 2 EA 0.00 17,200.00 0 34,400 80.00 160 184 MECH 61.53 11,300 45,70041-99-99 Allowance for electrical work for the electric boiler Allow 2 EA 0.00 5,000.00 0 10,000 20.00 40 46 WIRE 66.93 3,100 13,10041Heat Tracing for Instrumentation Piping041-33-65Heat tracingcableAllow. 5,700 LF 0.00 10.35 0 59,000 0.05 285 328 WIRE 66.93 21,900 80,90036-15 Insulation for heat traced piping Assumed nominal 4" pipe size Allow. 5,976 SF 0.00 10.00 0 59,800 0.25 1,494 1,718 INSL 45.09 77,500 137,30041-33-65Power connector and other accessories includingthermostats for heat tracing (by zones)Allow. 104 LS 0.00 950.00 98,500 8.00 829 953 WIRE 66.93 63,800 162,3000Electrical - Auxiliary Power and Balanceof Plant Electrical Work16,124,300 5,615,000 266,631 20,195,800 41,935,10041 Auxiliary Power Modifications Quantities are total for Unit 1&241-51-15 Rserve Aux. Transformer230kV - 4.16kV, 34/45 MVA,3phaseEst 1 EA 544,000.00 0.00 544,000 0 1,500 1,500 1,725 EHEA 67.88 117,100 661,10041-51-15 Unit Aux. Transformers24kV - 4.16kV, 15/20 MVA, 3phaseEst 2 EA 490,000.00 0.00 980,000 0 1,200 2,400 2,760 EHEA 67.88 187,300 1,167,30041-51-15 Transformer, 480 V Substation4.16KV-480V,3phase,2000/2666KVAEst 4 EA 85,000.00 0.00 340,000 0 950.00 3,800 4,370 EHEA 67.88 296,600 636,60041-51-15 Transformer, 480 V Substation4.16KV-480V,3phase,1500/2000KVAEst 4 EA 77,000.00 0.00 308,000 0 950.00 3,800 4,370 EHEA 67.88 296,600 604,600Page 8 of 14OG & EEstimate No.: 30228 A1Sooner Units 1 & 2Project No.: 11418-019Dry FGD SystemsDate: 12/11/2009Conceptual Cost EstimatePrepared by: MNOCost Type:Reviewed by: RKEst=EstimatedApproved by: PEFAllow.=AllowanceWage Rates Based on: 9NUR06C= ContractLabor Productivity = 1.15Q=Vendor QuoteCode ofAccountsItem DescriptionScope DefinitionCost TypeQuantityUnit ofMeasureUnit Equip.CostUnit MaterialCostTotal EquipmentCostTotal Material CostCost DevelopmentUnit Man-hours(Base)Total Man-hours(Base)Total Man-hours, Prod =1.15CrewCodeCrewWageRateTotal Construction& Erection CostTotal ProjectedCost41-41-99 FGD/FF Power Control Centers (one for each unit)(30'x60') building, includes:Enclosure with HVAC andLighting/electric service4160V swgr480V swgrMCCsUPSBatteries / ChargersRoom/Area designated forDCSPhone JackEst 2 EA 2,103,000.00 0.00 4,206,000 0 500.00 1,000 1,150 EHEA 67.88 78,100 4,284,10023-17-23 Platforms around elevated PCCquantities are total for Unit 1&2PCCsEst 2,850 SF 35.00 0.00 99,800 0 0.40 1,140 1,311 GALL 84.98 111,400 211,20023-25-75 Support steel for PCC platforms Est 20 TN 2,650.00 0.00 52,900 0 60.00 1,197 1,377 STST 105.69 145,500 198,40041-41-99 UAT Power Control Centers (one for each unit).(15'x20') building, includes:Enclosure with HVAC andLighting/electric service4160V swgrEst 2 EA 300,000.00 0.00 600,000 0 200.00 400 460 EHEA 67.88 31,200 631,20023-25-75Auxiliary Steel Modifications for UAT PCC's to belocated on turbine floor of each unitEst 7 TN 2,650.00 0.00 18,600 0 60.00 420 483 STST 105.69 51,000 69,60041-13-15 5KV Cable Bus duct 3000A Est 14,700 FT 550.00 0.00 8,085,000 0 2.50 36,750 42,263 WIRE 85.64 3,619,400 11,704,40023-25-75 Support steel for cable bus duct Est 84 TN 0.00 2,650.00 0 222,600 16.00 1,344 1,546 STST 87.33 135,000 357,60043-21-15 Cable Bus Terminations 750 KCM Est 288 EA 0.00 100.00 0 28,800 3.00 864 994 WIRE 85.64 85,100 113,90041-47-25 Relay PanelsEst 6 EA 40,000.00 0.00 240,000 0 120.00 720 828 WIRE 85.64 70,900 310,90041-51-99 Lightingtransformers 45KVA, 480V, 3 Phase Low voltage XFMREst 16 EA 15,000.00 250.00 240,000 4,000 80.00 1,280 1,472 WIRE 85.64 126,100 370,10041-47-15 Lighting Distribution panel, 200A, 208-120V, 3 PhaseLow voltage panel Est 16 EA 10,000.00 200.00 160,000 3,200 60.00 960 1,104 WIRE 85.64 94,500 257,70022-13-17 Duct Bank- Swgr Bldg to Truck Scale24"x24", 4x4" cells (includesembedded conduit)Est 2,100 LF 0.00 125 0 262,500 1.60 3,360 3,864 ECND 64.88 250,700 513,20042-13-47 Cable Trays 36" Trays Est 2,100 LF 0.00 30.00 0 63,000 1.00 2,100 2,415 ECND 64.88 156,700 219,70042-13-47 Cable Trays 24" Control, & 24" Instrument Est 2,100 LF 0.00 25.00 0 1.00 2,100 2,415 ECND 64.88 156,700 156,70042-15-37 Conduits misc sizes Est 2,100 LF 0.00 10.00 0 21,000 0.35 735 845 ECND 64.88 54,800 75,800Miscellaneous Electrical System041-15-15 Cathodic Protection Allowance Allow. 2 LS 75,000.00 0.00 150,000 0 700.00 1,400 1,610 WIRE 85.64 137,900 287,90041-25-55 Upgrade Fire detection systemAllowance Allow. 2 LS 50,000.00 0.00 100,000 0 250.00 500 575 INEL 73.2 42,100 142,100CABLES43-21-15 Cables 5kV 3/C, 500 kcmil Est 9,000 LF 0.00 29.11 0 262,000 0.69 6,210 7,142 WIRE 85.64 611,600 873,60043-21-15 Cables 5kV 3/C, 250 kcmil Est 1,050 LF 0.00 16.77 0 17,600 0.69 725 833 WIRE 85.64 71,400 89,00043-21-15 Cables 5kV 3/C, #4/0 Est 6,300 LF 0.00 9.78 0 61,600 0.35 2,205 2,536 WIRE 85.64 217,200 278,80043-21-35 Cables 5kV Terminations Est 91 EA 0.00 50.00 0 4,600 1.25 114 131 WIRE 85.64 11,200 15,800480 V FGD Unit Substation FGD (SDA, FabricFilter)43-17-15Power Feeder Cable, 600 V, from Unit Sub FGD toMCCsPower Feed to all MCC's (1/C750 MCM)Est 31,500 LF 0.00 9.82 0 309,300 0.18 5,670 6,521 WIRE 85.64 558,400 867,70043-17-15 Power Cable, 600 V(to equipment)3/C, #10 Est 21,000 LF 0.00 0.87 0 18,300 0.06 1,260 1,449 WIRE 85.64 124,100 142,40043-17-15 Power Cable, 600 V(to equipment)3/C, #6 Est 18,900 LF 0.00 1.92 0 36,300 0.10 1,890 2,174 WIRE 85.64 186,100 222,400Page 9 of 14OG & EEstimate No.: 30228 A1Sooner Units 1 & 2Project No.: 11418-019Dry FGD SystemsDate: 12/11/2009Conceptual Cost EstimatePrepared by: MNOCost Type:Reviewed by: RKEst=EstimatedApproved by: PEFAllow.=AllowanceWage Rates Based on: 9NUR06C= ContractLabor Productivity = 1.15Q=Vendor QuoteCode ofAccountsItem DescriptionScope DefinitionCost TypeQuantityUnit ofMeasureUnit Equip.CostUnit MaterialCostTotal EquipmentCostTotal Material CostCost DevelopmentUnit Man-hours(Base)Total Man-hours(Base)Total Man-hours, Prod =1.15CrewCodeCrewWageRateTotal Construction& Erection CostTotal ProjectedCost43-17-15 Power Cable, 600 V(to equipment)3/C, #4 Est 7,770 LF 0.00 2.55 0 19,800 0.35 2,720 3,127 WIRE 85.64 267,800 287,60043-17-15 Power Cable, 600 V(to equipment)3/C, #2 Est 1,890 LF 0.00 4.40 0 8,300 0.35 662 761 WIRE 85.64 65,100 73,40043-17-15 Power Cable, 600 V(to equipment)3/C, #1/0 Est 2,100 LF 0.00 6.33 0 13,300 0.52 1,092 1,256 WIRE 85.64 107,500 120,80043-17-15 Power Cable, 600 V(to equipment)3/C, #4/0 Est 2,730 LF 0.00 13.35 0 36,400 0.52 1,420 1,633 WIRE 85.64 139,800 176,20043-17-15 Power Cable, 600 V(to equipment)3/C, 350KCMILEst 2,100 LF 0.00 17.98 0 37,800 0.69 1,449 1,666 WIRE 85.64 142,700 180,50043-17-15 Power Cable, 600 V(to equipment)3/C, 500KCMILEst 2,100 LF 0.00 26.41 0 55,500 0.69 1,449 1,666 WIRE 85.64 142,700 198,20043-17-15 Power Cable, 600 V(for VFD's)4/C, #10 SHLD Est 2,100 LF 0.00 1.20 0 2,500 0.07 147 169 WIRE 85.64 14,500 17,00043-17-15 Power Cable, 600 V(for VFD's)4/C, #6 SHLD Est 840 LF 0.00 2.70 0 2,300 0.10 84 97 WIRE 85.64 8,300 10,60043-17-15 Power Cable, 600 V(for VFD's)4/C, #4 SHLD Est 630 LF 0.00 3.65 0 2,300 0.35 221 254 WIRE 85.64 21,700 24,00043-17-15 Power Cable, 600 V(for VFD's)3/C, 350KCMIL, SHLDEst 2,100 LF 0.00 16.52 0 34,700 0.69 1,449 1,666 WIRE 85.64 142,700 177,40043-13-17 Control Cable, 600V5/C, #10 Est 6,300 LF 0.00 1.30 0 8,200 0.08 504 580 WIRE 85.64 49,600 57,80043-13-17 Control Cable, 600V2/C, #14 Est 31,500 LF 0.00 0.37 0 11,700 0.03 945 1,087 WIRE 85.64 93,100 104,80043-13-17 Control Cable, 600V3/C, #14 Est 14,700 LF 0.00 0.42 0 6,200 0.03 441 507 WIRE 85.64 43,400 49,60043-13-17 Control Cable, 600V5/C, #14 Est 6,300 LF 0.00 0.68 0 4,300 0.03 189 217 WIRE 85.64 18,600 22,90043-13-17 Control Cable, 600V7/C, #14 Est 2,100 LF 0.00 0.95 0 2,000 0.04 84 97 WIRE 85.64 8,300 10,30043-13-17 Control Cable, 600V9/C, #14 Est 2,100 LF 0.00 1.17 0 2,500 0.05 105 121 WIRE 85.64 10,300 12,80043-17-35 Power & Control Cable TerminationsPower: 600, Control:1200Est 3,780 EA 0.00 1.00 0 3,800 0.30 1,134 1,304 WIRE 85.64 111,700 115,50043-13-13 Instrumentation Cable, 300V2pr, #16 TW SHLD Est 63,000 LF 0.00 0.32 0 20,200 0.03 2,016 2,318 WIRE 85.64 198,500 218,70043-13-13 Instrumentation Cable, 300V2 tr, #16 TW SHLD Est 14,700 LF 0.00 0.43 0 6,300 0.03 470 541 WIRE 85.64 46,300 52,60043-13-13 Instrumentation Cable, 300V2pr, #16 SHLD typeEEst 14,700 LF 0.00 0.35 0 5,100 0.03 470 541 WIRE 85.64 46,300 51,40043-13-33 Fiber Optic Cable 2 strand Est 2,100 LF 0.00 0.50 0 1,100 0.03 63 72 WIRE 85.64 6,200 7,30043-13-33 Fiber Optic Cable 6 strand Est 5,250 LF 0.00 0.96 0 5,000 0.03 158 181 WIRE 85.64 15,500 20,50043-13-33 Fiber Optic Cable 12 strand Est 1,260 LF 0.00 1.46 0 1,800 0.03 38 43 WIRE 85.64 3,700 5,50043-13-33 Fiber Optic Cable 24 strand Est 2,730 LF 0.00 2.21 0 6,000 0.05 137 157 WIRE 85.64 13,400 19,40043-13-99 Profibus DP Cable Est 8,400 LF 0.00 1.50 0 12,600 0.05 420 483 WIRE 85.64 41,400 54,00043-13-27 Cat 5EEst 3,150 LF 0.00 1.40 0 4,400 0.05 158 181 WIRE 85.64 15,500 19,90043-13-43 Instrumentation Cable TerminationsEst 6,300 EA 0.00 1.00 0 6,300 0.25 1,575 1,811 WIRE 85.64 155,100 161,40042-17-15 Misc. Junction Boxes & Pull BoxesEst 2 LT 0.00 154,000.00 0 308,000 900.00 1,800 2,070 WIRE 85.64 177,300 485,30042-13-47 Cable Trays36" Trays Est 8,400 LF 0.00 30.00 0 252,000 1.00 8,400 9,660 ECND 64.88 626,700 878,70042-13-47 Cable Trays24" Control, & 24" InstrumentEst 12,600 LF 0.00 25.00 0 1.00 12,600 14,490 ECND 64.88 940,100 940,10042-15-37 Conduits misc sizes Est 73,500 LF 0.00 10.00 0 735,000 0.35 25,725 29,584 ECND 64.88 1,919,400 2,654,40041-31-15 GroundingIncludes ground grid, rods,bolted connections & cadwelds.Future installation onlyEst 2 LT 0.00 50,000.00 0 100,000 800.00 1,600 1,840 WIRE 85.64 157,600 257,60041-17-25 PA / Page PartyExtension SystemAllow. 2 LT 0.00 20,000.00 0 40,000 300.00 600 690 WIRE 85.64 59,100 99,10041-17-35 Data COM Extension SystemAllow. 2 LT 0.00 5,000.00 0 10,000 120.00 240 276 WIRE 85.64 23,600 33,60041-17-35 Telephone Extension SystemAllow. 2 LT 0.00 5,000.00 0 10,000 140.00 280 322 WIRE 85.64 27,600 37,60041-53-17 SecuritySystemAllow. 2 LT 0.00 100,000.00 0 200,000 600.00 1,200 1,380 WIRE 85.64 118,200 318,200480 V Lime/Ash Handling Unit Sub (LimeHandling, Reagent Prep, Ash Handl Area)43-17-15 Power Cable, 600 V(to equipment)3/C, #10 Est 18,900 LF 0.00 0.87 0 16,400 0.06 1,134 1,304 WIRE 85.64 111,700 128,10043-17-15 Power Cable, 600 V(to equipment)3/C, #6 Est 18,900 LF 0.00 1.92 0 36,300 0.10 1,890 2,174 WIRE 85.64 186,100 222,40043-17-15 Power Cable, 600 V(to equipment)3/C, #4 Est 6,300 LF 0.00 2.55 0 16,100 0.35 2,205 2,536 WIRE 85.64 217,200 233,30043-17-15 Power Cable, 600 V(to equipment)3/C, #1/0 Est 2,100 LF 0.00 6.33 0 13,300 0.52 1,092 1,256 WIRE 85.64 107,500 120,80043-17-15 Power Cable, 600 V(to equipment)3/C, #4/0 Est 2,310 LF 0.00 11.53 0 26,600 0.52 1,201 1,381 WIRE 85.64 118,300 144,90043-17-15 Power Cable, 600 V(to equipment)3/C, 350KCMILEst 2,100 LF 0.00 17.98 0 37,800 0.69 1,449 1,666 WIRE 85.64 142,700 180,50043-17-15 Power Cable, 600 V(to equipment)3/C, 500KCMILEst 6,300 LF 0.00 26.41 0 166,400 0.69 4,347 4,999 WIRE 85.64 428,100 594,50043-17-15 Power Cable, 600V4/C, #10 SHLD Est 2,100 LF 0.00 1.20 0 2,500 0.07 147 169 WIRE 85.64 14,500 17,00043-17-15 Power Cable, 600 V 4/C, #6 SHLD Est 1,260 LF 0.00 2.70 0 3,400 0.10 126 145 WIRE 85.64 12,400 15,80043-17-15 Power Cable, 600 V 3/C, 350KCMIL, SHLDEst 1,260 LF 0.00 17.98 0 22,700 0.69 869 1,000 WIRE 85.64 85,600 108,30043-17-15 Control Cable, 600V2/C, #10 Est 12,600 LF 0.00 0.70 0 8,800 0.03 378 435 WIRE 85.64 37,200 46,00043-17-15 Control Cable, 600V7/C, #10 Est 5,250 LF 0.00 1.60 0 8,400 0.12 630 725 WIRE 85.64 62,000 70,40043-17-15 Control Cable, 600V2/C, #14 Est 29,400 LF 0.00 0.37 0 10,900 0.03 882 1,014 WIRE 85.64 86,900 97,80043-17-15 Control Cable, 600V3/C, #14 Est 10,500 LF 0.00 0.42 0 4,400 0.03 315 362 WIRE 85.64 31,000 35,40043-17-15 Control Cable, 600V5/C, #14 Est 9,450 LF 0.00 0.68 0 6,400 0.03 284 326 WIRE 85.64 27,900 34,30043-17-15 Control Cable, 600V7/C, #14 Est 2,100 LF 0.00 0.95 0 2,000 0.04 84 97 WIRE 85.64 8,300 10,30043-17-35 Power & Control Cable TerminationsPower: 510, Control: 1000Est 3,171 EA 0.00 1.00 0 3,200 0.30 951 1,094 WIRE 85.64 93,700 96,90043-13-13 Instrumentation Cable, 300V1pr, #16 TW SHLD Est 10,500 LF 0.00 0.18 0 1,900 0.03 315 362 WIRE 85.64 31,000 32,90043-13-13 Instrumentation Cable, 300V1 tr, #16 TW SHLD Est 2,100 LF 0.00 0.29 0 600 0.03 63 72 WIRE 85.64 6,200 6,80043-13-13 Instrumentation Cable, 300V2pr, #16 TW SHLD Est 21,000 LF 0.00 0.32 0 6,700 0.03 630 725 WIRE 85.64 62,000 68,70043-13-13 Instrumentation Cable, 300V2 tr, #16 TW SHLD Est 4,200 LF 0.00 0.43 0 1,800 0.03 126 145 WIRE 85.64 12,400 14,20043-13-13 Instrumentation Cable, 300V8pr, #16 TW SHLD Est 4,200 LF 0.00 0.86 0 3,600 0.10 420 483 WIRE 85.64 41,400 45,00043-13-13 Instrumentation Cable, 300V2pr, #16 SHLD typeEEst 12,600 LF 0.00 0.35 0 4,400 0.03 403 464 WIRE 85.64 39,700 44,10043-13-33 Fiber Optic Cable 2 strand Est 2,100 LF 0.00 0.50 0 1,100 0.03 63 72 WIRE 85.64 6,200 7,30043-13-33 Fiber Optic Cable 6 strand Est 5,250 LF 0.00 0.96 0 5,000 0.03 158 181 WIRE 85.64 15,500 20,50043-13-33 Fiber Optic Cable 12 strand Est 1,260 LF 0.00 1.46 0 1,800 0.03 38 43 WIRE 85.64 3,700 5,500Page 10 of 14OG & EEstimate No.: 30228 A1Sooner Units 1 & 2Project No.: 11418-019Dry FGD SystemsDate: 12/11/2009Conceptual Cost EstimatePrepared by: MNOCost Type:Reviewed by: RKEst=EstimatedApproved by: PEFAllow.=AllowanceWage Rates Based on: 9NUR06C= ContractLabor Productivity = 1.15Q=Vendor QuoteCode ofAccountsItem DescriptionScope DefinitionCost TypeQuantityUnit ofMeasureUnit Equip.CostUnit MaterialCostTotal EquipmentCostTotal Material CostCost DevelopmentUnit Man-hours(Base)Total Man-hours(Base)Total Man-hours, Prod =1.15CrewCodeCrewWageRateTotal Construction& Erection CostTotal ProjectedCost43-13-33 Fiber Optic Cable 24 strand Est 2,730 LF 0.00 2.21 0 6,000 0.05 137 157 WIRE 85.64 13,400 19,40043-13-99 Profibus DP Cable Est 8,400 LF 0.00 1.50 0 12,600 0.05 420 483 WIRE 85.64 41,400 54,00043-13-27 Cat 5EEst 3,150 LF 0.00 1.40 0 4,400 0.05 158 181 WIRE 85.64 15,500 19,90043-13-43 Instrumentation Cable TerminationsEst 6,300 EA 0.00 1.00 0 6,300 0.25 1,575 1,811 WIRE 85.64 155,100 161,40042-17-15 Misc. Junction Boxes & Pull BoxesEst 2 LT 0.00 100,000.00 0 200,000 600.00 1,200 1,380 WIRE 85.64 118,200 318,20042-13-47 Cable Trays36" Trays Est 8,400 LF 0.00 30.00 0 252,000 1.00 8,400 9,660 ECND 64.88 626,700 878,70042-13-47 Cable Trays24" Control, & 24" InstrumentEst 12,600 LF 0.00 25.00 0 315,000 1.00 12,600 14,490 ECND 64.88 940,100 1,255,10042-15-37 Conduits misc sizes Est 52,500 LF 0.00 10.00 0 525,000 0.35 18,375 21,131 ECND 64.88 1,371,000 1,896,00041-31-15 GroundingIncludes ground grid, rods,bolted connections & cadwelds.Future installation onlyEst 2 LT 0.00 50,000.00 0 100,000 800.00 1,600 1,840 WIRE 85.64 157,600 257,60041-17-25 PA / Page PartyExtension SystemEst 2 LT 0.00 20,000.00 0 40,000 300.00 600 690 WIRE 85.64 59,100 99,10041-17-35 Data COM Extension SystemEst 2 LT 0.00 5,000.00 0 10,000 120.00 240 276 WIRE 85.64 23,600 33,60041-17-35 Telephone Extension SystemEst 2 LT 0.00 5,000.00 0 10,000 140.00 280 322 WIRE 85.64 27,600 37,60041-53-17 LightningProtection Est 2 LT 0.00 30,000.00 0 60,000 300.00 600 690 WIRE 85.64 59,100 119,100Electrical Aux Power Structural Work0Foundations for FGD/FF PCC'sQuantities shown are total for 2buildings, 1/unit21-23-15 ExcavationEst 963 CY0.00 0.00 0 0 0.20 193 221 EXFD 63.95 14,200 14,20021-17-25 BackfillEst 63 CY0.00 0.00 0 0 0.30 19 22 EXFD 63.95 1,400 1,40022-13-37 ConcreteEst 900 CY0.00 105.00 0 94,500 1.50 1,350 1,553 CONP 51.69 80,200 174,70022-25-35 ReinforcingEst 68 TN 0.00 1,150.00 0 77,600 20.00 1,350 1,553 REIN 61.48 95,400 173,00022-17-25 FormworkEst 3,600 SF 0.00 2.50 0 9,000 0.14 486 559 FORM 71.62 40,000 49,00022-15-25 Embedded Steel Est 7,200 LB 0.00 2.50 0 18,000 0.05 360 414 CARP 46.37 19,200 37,20022-13-67 Transformer Firewalls2700 SF Est 100 CY0.00 225.00 0 22,500 12.00 1,200 1,380 CONP 74.7 103,100 125,600Transformer FoundationsTotal for UAT and RAT withcontainments0 0021-23-15 ExcavationEst 621 CY0.00 0.00 0 0 0.20 124 143 EXFD 81.96 11,700 11,70021-17-25 BackfillEst 41 CY0 0.30 12 14 EXFD 81.96 1,100 1,10022-13-37 ConcreteEst 580 CY0.00 105.00 0 60,900 1.50 870 1,001 CONP 74.7 74,700 135,60022-25-35 ReinforcingEst 44 TN 0.00 1,150.00 0 50,000 20.00 870 1,001 REIN 79.19 79,200 129,20022-17-25 FormworkEst 2,320 SF 0.00 2.50 0 5,800 0.14 313 360 FORM 90.9 32,700 38,50022-15-25 Embedded SteelEst 2,900 LB 0.00 2.50 0 7,300 0.06 174 200 CARP 64.41 12,900 20,20023-25-75 Structural SteelBasin Gallery Steel forcontainments4.50 TN 0.00 2,650.00 0 11,900 25.00 113 129 STST 105.69 13,700 25,60023-17-23 1 1/4" Grating(Galv)Basin Grating750 SF 0.00 18.00 0 13,500 0.20 150 173 GALL 84.98 14,700 28,200Controls & Instrumentation4,125,000 75,000 16,388 888,500 5,088,50044-13-15 DCS 4500 I/OpointsEst 1 LS 2,925,000.00 0.00 2,925,000 0 6,750 6,750 7,763 INEL 54.22 420,900 3,345,90071-55-45 DCS - Vendor Field Support200 mandays@$1500/dayEst 200 DAYS 1,500.00 0.00 300,000 0 0.00 0 0 INEL 54.22 0 300,00044-24-43 LocallyMounted InstrumentsEst 300 EA 3,000.00 0.00 900,000 0 20 6,000 6,900 INEL 54.22 374,100 1,274,10044-17-15 Instrument Racks included with instruments35-15-13 Instrument TubingAllow 1 LT 0.00 75,000 0 75,000 1,500 1,500 1,725 INEL 54.22 93,500 168,500Modifications / Installation of CEM systemNot required EstCivil Work0 1,482,700 26,717 2,114,700 3,597,40021Laydown AreaApprox 4 Acre21-13-25Cut and stripTopsoil strippingEst38720 CY0.00 0.00 0 0 0.010 0.030 1,162 1,336 ETWK 152.54 203,800 203,80021-13-45Topsoil storage stockpile assumes on site stockpilingEst38720 CY0.00 0.00 0 0 0.010 0.010 387 445 ETWK 152.54 67,900 67,90021-51-27Geotextile membrane10 oz/syEst19360 SY0.00 1.80 0 34,800 0.010 0.010 194 223 LAND 30.15 6,700 41,50021-57-55Aggregate surfacing4" thick over entire areaEst19360 SY0.00 5.65 0 109,400 0.010 0.020 387 445 BCSE 82.08 36,500 145,90021-47-25Grass seedingover stockplie areaEst4 ACRE0.00 1,000 0 4,000 0.010 60 240 276 LAND 30.15 8,300 12,30021-41-65 Silt FenceTotal for stockplie and laydownareaEst 1,820 LF 0.00 1 0 1,800 0.02 36 42 LAND 30.15 1,300 3,10021-43-25Fencingwith one 3-strand barbed wire unitFabric,posts on 10ft centersEst 1,760 LF 0.00 40 0 70,400 0.28 493 567 LAND 30.15 17,100 87,50021-43-45Gates 50ft wide double swingEst 2 EA 0.00 3,500.00 0 7,000 40 80 92 LAND 30.15 2,800 9,80021Restoration of Laydown AreaEst0 ACRE0.00 15.00 0 0 35 0 0 ETWK 152.54 0 021-21-25Remove and dispose of aggregateEst2,215 CY0.00 0.00 0 0 0.010 0.007 16 18 BCSE 82.08 1,500 1,50011-21-99Removal of Geotextile membraneEst19360 SY0.00 0.00 0 0 0.010 0.003 58 67 LAND 30.15 2,000 2,00021-23-15Earthwork to restore - CutEst2,462 CY0.00 0.00 0 0 0.010 0.030 74 85 EXFD 63.95 5,400 5,40021-23-45Earthwork to restore - Fill Est2,462 CY0.00 0.00 0 0 0.010 0.050 123 142 EXFD 63.95 9,100 9,10021-23-45Place topsoil -previouslystockpiledEst70000 CY0.00 0.00 0 0 0.010 0.050 3,500 4,025 EXFD 63.95 257,400 257,40021-47-25Grass seeding- mulch and fertilizerEst4 ACRE0.00 1,500 0 6,000 0.010 90 360 414 LAND 30.15 12,500 18,50021DFGD AreaApprox 4 Acre21-13-25Cut and stripTopsoil strippingEst43560 CY0.00 0.00 0 0 0.010 0.030 1,307 1,503 ETWK 152.54 229,200 229,20021-13-45Topsoil storage stockpile assumes on site stockpilingEst43560 CY0.00 0.00 0 0 0.010 0.010 436 501 ETWK 152.54 76,400 76,40021-51-27Geotextile membrane10 oz/syEst21780 SY0.00 1.80 0 39,200 0.010 0.010 218 250 LAND 30.15 7,600 46,800Page 11 of 14OG & EEstimate No.: 30228 A1Sooner Units 1 & 2Project No.: 11418-019Dry FGD SystemsDate: 12/11/2009Conceptual Cost EstimatePrepared by: MNOCost Type:Reviewed by: RKEst=EstimatedApproved by: PEFAllow.=AllowanceWage Rates Based on: 9NUR06C= ContractLabor Productivity = 1.15Q=Vendor QuoteCode ofAccountsItem DescriptionScope DefinitionCost TypeQuantityUnit ofMeasureUnit Equip.CostUnit MaterialCostTotal EquipmentCostTotal Material CostCost DevelopmentUnit Man-hours(Base)Total Man-hours(Base)Total Man-hours, Prod =1.15CrewCodeCrewWageRateTotal Construction& Erection CostTotal ProjectedCost21-57-55Aggregate surfacing4" thick over entire areaEst24200 SY0.00 5.65 0 136,700 0.010 0.020 484 557 BCSE 82.08 45,700 182,400Plant Drainage21-25-15ExcavationEst600 CY0.00 0.00 0 0 0.010 0.200 120 138 EXFD 63.95 8,800 8,80021-57-55Crushed rock surfacing12" Est 240 CY0.00 54.00 0 13,000 0.14 34 39 BCSE 82.08 3,200 16,200Storm Sewer22-23-654ft ManholesEst 6 EA 0.00 1,575.00 0 9,500 20.00 120 138 YDPP 63.15 8,700 18,20022-23-656ft ManholesEst 5 EA 0.00 3,000.00 0 15,000 30.00 150 173 YDPP 63.15 10,900 25,90022-23-6524"x24" Catch Basin 3 ft deepEst 10 EA 0.00 500.00 0 5,000 6.00 60 69 YDPP 63.15 4,400 9,40035-13-3518" CHDPEEst 750 LF 0.00 30.00 0 22,500 0.30 225 259 YDPP 63.15 16,300 38,80035-13-3524" CHDPEEst 750 LF 0.00 40.00 0 30,000 0.40 300 345 YDPP 63.15 21,800 51,80035-13-3536" CHDPEEst 750 LF 0.00 70.00 0 52,500 0.65 488 561 YDPP 63.15 35,400 87,90021OilyWater Sewer System22-23-654ft ManholesEst 7 EA 0.00 1,575.00 0 11,000 20.00 140 161 YDPP 63.15 10,200 21,20035-13-236" CISPEst 1,650 LF 0.00 28.00 0 46,200 1.05 1,733 1,992 YDPP 63.15 125,800 172,00035-13-236" Post indicator valve Est 6 EA 0.00 450.00 0 2,700 6.00 36 41 YDPP 63.15 2,600 5,30031-93-53Oil Water Separator with Lift Station 3,000gal Est 1 EA 0.00 100,000.00 0 100,000 1130.00 1,130 1,300 YDPP 63.15 82,100 182,10021SanitarySewer22-23-654ft ManholesEst 7 EA 0.00 1,575.00 0 11,000 20.00 140 161 YDPP 63.15 10,200 21,20022-23-65CleanoutsEst 5 EA 0.00 690.00 0 3,500 8.00 40 46 YDPP 63.15 2,900 6,40035-13-236" CISPEst 1,600 LF 0.00 28.00 0 44,800 1.05 1,680 1,932 YDPP 63.15 122,000 166,80021-25-15 Excavationfor all drainage and sewerpipingEst 2,222 CY 0.00 0.00 0 0 0.010 0.200 444 511 EXFD 63.95 32,700 32,70021-17-15 Bedding / backfillfor all drainage and sewerpipingEst 556 CY 0.00 40.00 0 22,200 0.010 0.300 167 192 EXFD 63.95 12,300 34,500Interior Plant Roads and Surfacing21-13-25Cut and stripTopsoil strippingEst2,889 CY0.00 0.00 0 0 0.010 0.030 87 100 ETWK 152.54 15,200 15,20021-13-25CutEst722 CY0.00 0.00 0 0 0.010 0.030 22 25 ETWK 152.54 3,800 3,80021-17-55FillEst722 CY0.00 0.00 0 0 0.010 0.050 36 42 ETWK 152.54 6,300 6,30021-51-27Geotextile membrane10 oz/syEst8,667 SY0.00 1.80 0 15,600 0.010 0.010 87 100 LAND 30.15 3,000 18,60021-57-55Aggregate surfacing6" thick over entire areaEst8,667 SY0.00 8.50 0 73,700 0.010 0.020 173 199 BCSE 82.08 16,400 90,10021-57-35Concrete road 9" thick, 24ft W x 2600 L Est1,733 CY0.00 17.52 0 30,400 0.29 503 578 PBIT 64.44 37,300 67,70022-25-35 ReinforcingEst 173 TN 0.00 1,150.00 0 199,300 20.00 3,467 3,987 REIN 79.19 315,700 515,00022-17-25 FormworkEst 5,200 SF 0.00 2.50 0 13,000 0.14 702 807 FORM 90.9 73,400 86,40021-57-55 Contractor Trailer Area SurfacingIncludes:9" aggregate surfacing12" subgradeprepEst 14520 SY 0.00 22.48 0 326,400 0.10 1,452 1,670 BCSE 82.08 137,100 463,50021-51-27Geotextile membrane - entire area10 oz/syEst14520 SY0.00 1.80 0 26,100 0.010 0.010 145 167 LAND 30.15 5,000 31,100Removal and Relocation of ExistingEquipment and Infrastructure0 859,300 16,890 1,188,300 2,047,600Miscellaneous Pipe Relocation - UndergroundQuantities are total for Units1&235-13-1514" CS, SCH 40, includes fittings Fuel oil and chemical drainsEst 938 LF 0.00 259.50 0 243,400 2.94 2,758 3,171 YDPP 63.15 200,300 443,70035-13-15 12" CS, SCH 40, includes fittingsChemical drains and servicewaterEst 375 LF 0.00 246.30 0 92,400 2.88 1,080 1,242 YDPP 63.15 78,400 170,80035-13-158" CS, SCH 40, includes fittings Oil drains Est 375 LF 0.00 89.50 0 33,600 1.60 600 690 YDPP 63.15 43,600 77,20035-13-156" CS, SCH 40, includes fittings Fuel oil and service waterEst 563 LF 0.00 130.20 0 73,300 1.88 1,058 1,217 YDPP 63.15 76,900 150,20021-25-15 Excavation for Underground PipingEst 834 CY0.00 0.00 0 0 0.20 167 192 EXFD 63.95 12,300 12,30021-17-15 Beddingfor Underground PipingEst 125 CY0.00 40.00 0 5,000 0.30 38 43 EXFD 63.95 2,800 7,80021-17-25 Backfill for Underground PipingEst 709 CY0.00 0.00 0 0 0.30 213 244 EXFD 63.95 15,600 15,600Miscellaneous Pipe Relocation - Above GroundQuantities are total for Units1&2Allow. 1 LT 0.00 200,000 0 200,000 3000.00 3,000 3,450 WIRE 66.93 230,900 430,90035-13-1512" CS, SCH 40, includes fittings Ash water, Unit 1&2 Est 250 LF 0.00 246.30 0 61,600 2.88 720 828 YDPP 63.15 52,300 113,90035-13-1510" CS, SCH 40, includes fittings Ash waterEst 250 LF 0.00 196.80 0 49,200 2.32 580 667 YDPP 63.15 42,100 91,30035-13-158" Ashcolite, flanged Ash sluice line Est 500 LF 0.00 145.20 0 72,600 1.54 770 886 YDPP 63.15 55,900 128,50035-13-154" CS, SCH 40, includes fittings Service waterEst 250 LF 0.00 57.60 0 14,400 1.50 375 431 YDPP 63.15 27,200 41,60035-13-33Pipe Supports for relocatedpipingEst 5.22 TN 0.00 2,650.00 0 13,800 40.00 209 240 STST 87.33 21,000 34,800Miscellaneous Structures Building Demolition Unit 111-26-99 DuctworkEst 120 TN 0.00 0 0 0 15.00 1,800 2,070 WRKG 91.68 189,800 189,80011-23-99 SteelEst 25 TN 0.00 0 0 0 12.00 300 345 WRKG 91.68 31,600 31,60011-22-99 ConcreteAssumed existing foundationsto be left inplaceMiscellaneous Structures Building Demolition Unit 2Page 12 of 14OG & EEstimate No.: 30228 A1Sooner Units 1 & 2Project No.: 11418-019Dry FGD SystemsDate: 12/11/2009Conceptual Cost EstimatePrepared by: MNOCost Type:Reviewed by: RKEst=EstimatedApproved by: PEFAllow.=AllowanceWage Rates Based on: 9NUR06C= ContractLabor Productivity = 1.15Q=Vendor QuoteCode ofAccountsItem DescriptionScope DefinitionCost TypeQuantityUnit ofMeasureUnit Equip.CostUnit MaterialCostTotal EquipmentCostTotal Material CostCost DevelopmentUnit Man-hours(Base)Total Man-hours(Base)Total Man-hours, Prod =1.15CrewCodeCrewWageRateTotal Construction& Erection CostTotal ProjectedCost11-26-99 DuctworkEst 60 TN 0.00 0 0 0 15.00 900 1,035 WRKG 91.68 94,900 94,90011-23-99 SteelEst 10 TN 0.00 0 0 0 12.00 120 138 WRKG 91.68 12,700 12,70011-22-99 ConcreteAssumed existing foundationsto be left inplace:Sub-Total of Equipment Material andLabor Costs113,383,200 38,719,000 1,647,446 109,453,400 261,555,600Other Costs61,016,90081-13-45Additional Crane Rental Allowance4.00 %04,378,136 4,378,13661-27-25 Mobilization/Demobilization Est 2.00 %2,189,068 2,189,10061-23-35 ScaffoldingEst 2.50 %967,9752,736,335 3,704,30061-17-43Temporary Facilities and Construction Utilities (Elect,Water, etc.) During Construction1.00 %01,094,534 1,094,500Allowance for Premium Time Labor Five (5) days perweek Ten (10) hours per day.Est 1 LS061-21-45Cost due to overtime inefficiencyworking5x10's8.00 %143,256 66 9,518,000 9,518,00061-21-65Per Diem Expense@$10/HR10 hr17,907,025 17,907,00091-13-15 BOP Contractor's General & Administrative CostsBased on BOP Materials &Labor Costs at 5% (not incl.Equipment Costs )Est 5.00 %1,935,9505,472,670 7,408,60091-15-25 BOP Contractor's ProfitBased on BOP Materials &Labor Costs at 10% (not incl.Equipment Costs )Est 10.00 %3,871,90010,945,340 14,817,240Total Equipment, Material and LaborCosts113,383,200 45,494,800 1,790,700 163,694,500 322,572,500Spare Parts, Special Tools andConsumables794,00081-27-75 Mandatory Spare Parts (first year of operation) 0.00 % 00 081-25-35 Special ToolsIncludedw\Equipment Costs81-25-25Consumables(0.5% of Equipment/Material Cost)0.5 % 567,000 227,000794,000Freight, Duties, Taxes, Etc.1,936,00071-27-35 Freight-ExWorks To SiteFor material costs only. Freightfor Equipment included withequipment costs.5 %1,935,9501,936,00071-47-45Taxes - Sales/Use/VAT/Business/Etc. Not Included0Total Direct Costs113,950,200 47,657,800 163,694,500 325,302,500Total Indirect Costs0 048,090,10071-13-15Engineering/ Procurement6.50 %21,144,700 21,144,70071-23-15Construction Management2.00 %6,506,100 6,506,10071-45-57Start-up& CommissioningCraft Support2.00 %3,273,900 3,273,90071-53-15Operator Training& Manuals0.55 %900,300 900,30071-21-15Owner's Cost5.00 %16,265,125 16,265,125Page 13 of 14OG & EEstimate No.: 30228 A1Sooner Units 1 & 2Project No.: 11418-019Dry FGD SystemsDate: 12/11/2009Conceptual Cost EstimatePrepared by: MNOCost Type:Reviewed by: RKEst=EstimatedApproved by: PEFAllow.=AllowanceWage Rates Based on: 9NUR06C= ContractLabor Productivity = 1.15Q=Vendor QuoteCode ofAccountsItem DescriptionScope DefinitionCost TypeQuantityUnit ofMeasureUnit Equip.CostUnit MaterialCostTotal EquipmentCostTotal Material CostCost DevelopmentUnit Man-hours(Base)Total Man-hours(Base)Total Man-hours, Prod =1.15CrewCodeCrewWageRateTotal Construction& Erection CostTotal ProjectedCostTotal Project Cost without Escalation /Contingency373,392,60095-95-95Escalation46,602,900Equipment.00%11,964,80011,964,800Material.00%5,718,9005,718,900Labor.00%23,244,600 23,244,600Indirects.00%5,674,600 5,674,60093-93-93Contingency13.970 %58,673,400Total Project Cost with Escalation /Contingency478,668,90097-97-97Bond Cost1.00 %4,786,70097-97-97Interest DuringConstruction(AFUDC)8.66 %101,133,800Total Project Cost584,589,400123456789101112131415161718192021222324252627282930313233343536Page 14 of 14

# OG&E

Muskogee Units 4&5 DFGD System

Cost Estimate Account Summary Date: 12/23/2009

Account Description Cost

Dry FGD System $86,741,200

Fabric Filter $45,872,900

Ash Recycling System - DFGD

Contractor's Scope $12,102,900

Waste Ash and Fly Ash Handling

System $14,311,500

Flue Gas System $52,238,200

Mechanical - Balance of Plant $6,201,400

Electrical - Auxiliary Power and

Balance of Plant Electrical Work $37,923,600

Controls & Instrumentation $5,088,500

Civil Work $3,597,400

Removal and Relocation of Existing

Equipment and Infrastructure $4,134,800

Other Costs $66,931,700

Total Indirect Costs $49,601,900

Escalation $63,277,100

Contingency $63,104,100

Bond Cost $5,111,300

Interest During Construction

(AFUDC) $118,148,300

Total Project Cost $634,386,800

Page 1 of 1OG & EEstimate No.: 30352 AMuskogee Units 4 & 5Project No.: 11418-019Dry FGD SystemsDate: 12/23/2009Conceptual Cost EstimatePrepared by: MNOCost Type:Reviewed by: RKEst=EstimatedApproved by: PEFAllow.=AllowanceWage Rates Based on: 9NUR06C= ContractLabor Productivity = 1.15Q=Vendor QuoteCode ofAccountsItem DescriptionScope DefinitionCost TypeQuantityUnit ofMeasureUnit Equip.CostUnit MaterialCostTotal EquipmentCostTotal Material CostUnit Man-hours(Base)Total Man-hours(Base)Total Man-hours, Prod =1.15CrewCodeCrewWageRateTotal Construction& Erection CostTotal ProjectedCostDryFGD System46,462,100 8,387,700 503,589 31,891,400 86,741,20031-45-25 Dry FGD SystemQ 2 LT 15,917,133 0.00 31,834,300 0 136,400 272,800 313,720 MECH 61.53 19,303,200 51,137,50031-45-35Reagent Handling/ PreparationEst0 0031-45-35 Reagent Handling / Preparation - Mechanical Q 2 LT 3,969,614 0.00 7,939,200 0 33600 67,200 77,280 MECH 61.53 4,755,000 12,694,20026-13-99Lime Storage Silo with piping for pneumaticunloading (truck)Concrete Silo - SubcontractpriceQ 1 LT 3,200,000 0.00 3,200,000 0 0 0 0 MECH 61.53 0 3,200,00024-17-15 Elevator for lime silofour person rack and pinionmaintenance elevator -subcontract price includes laborEst 1 LT 290,000 0.00 290,000 0 0 0 0 MECH 61.53 0 290,00022-13-27 Concrete pit for the elevator Est 10 CY 0 210.00 0 2,100 7.5 75 86 CONP 51.69 4,500 6,60041-99-99 Electrical work for the elevatorallowance Est 1 LT 0 20,000.00 0 20,000 175 175 201 WIRE 66.93 13,500 33,50033-43-15 Pneumatic lime transfer equipment/pipingincluding blowers, piping, andvalvesQ 1 EA 400,000 0.00 400,000 0 3500 3,500 4,025 MECH 61.53 247,700 647,70023-17-23 Access GalleryEst 2,000 SF 0.00 35.00 0 70,000 0.40 800 920 GALL 67.14 61,800 131,8000DryFGD System - Civil / Structural Work0Foundations for SDA's Quantities are total for 2 units21-53-13 Piles 16" dia X 60' deep, auger castEst 14,400 LF 0.00 12.65 0 182,200 0.35 5,040 0 PILE 86.18 0 182,20021-23-15 ExcavationEst 1,498 CY0.00 0.00 0 0 0.20 300 345 EXFD 63.95 22,000 22,00021-17-25 BackfillEst 98 CY0.00 0.00 0 0 0.30 29 34 EXFD 63.95 2,200 2,20022-13-37 ConcreteEst 1,400 CY0.00 105.00 0 147,000 1.50 2,100 2,415 CONP 51.69 124,800 271,80022-25-35 ReinforcingEst 126 TN 0.00 1,150.00 0 144,900 20.00 2,520 2,898 REIN 61.48 178,200 323,10022-17-25 FormworkEst 4,200 SF 0.00 2.50 0 10,500 0.14 567 652 FORM 71.62 46,700 57,20022-15-25 Embedded steel Est 3.50 TN 0.00 5,000.00 0 17,500 120.00 420 483 CARP 46.37 22,400 39,900SDA SuperstructureQuantities are total for 2units023-25-75 Common Penthouse for SDA'ssupport steel, roof steel, girtsand purlinsEst 152 TN 0.00 2,650.00 0 402,500 35.00 5,316 6,113 STST 87.33 533,800 936,30024-37-43 SDA Roof Insulationbetween penthouse floor andSDA roof total for 2 SDAsEst 12,070 SF 0.00 15.00 0 181,100 0.30 3,621 4,164 ROOF 45.55 189,700 370,80024-37-47 Roofing for common SDA Penthouse standing seam type. Est 8,100 SF 0.00 18 0 145,800 0.22 1,782 2,049 ROOF 45.55 93,300 239,10024-41-25 Siding for common SDA Penthouse insulated metal siding Est 16,200 SF 0.00 12 0 194,400 0.11 1,782 2,049 SDNG 63.02 129,100 323,50036-13-23 Shell Insulation subcontract cost Est 61,688 SF 30.00 0 1,850,600 0 0 0 DINS 52.16 0 1,850,60022-13-23 Concrete bottom floor for common SDA Penthouseincludes metal decking andformworkEst 99 CY 210 0 20,800 7.5 743 854 CONP 51.69 44,100 64,90041-37-99 Common Penthouse BuildingServices H&V and LightingEst 8,100 SF 0.00 30.00 0 243,000 0.30 2,430 2,795 WIRE 66.93 187,000 430,00031-41-77 Fire Protection for Penthouse Standpipe & hose stations. Est 2 LS 80,000 160,000 500.00 1,000 1,150 MECH 61.53 70,800 230,80024-17-15 ElevatorFor SDA - four person rack andpinion elevator. Suncontractprice includes laborEst 1 LT 290,000 0.00 290,000 0 0.00 0 0 MECH 61.53 0 290,00022-13-37 Concrete pit for the elevator Est 10 CY 0 210.00 0 2,100 7.5 75 86 CONP 51.69 4,500 6,60041-99-99 Electrical work for the elevatorallowance Est 1 LT 0 20,000.00 0 20,000 175 175 201 WIRE 66.93 13,500 33,500Page 1 of 14OG & EEstimate No.: 30352 AMuskogee Units 4 & 5Project No.: 11418-019Dry FGD SystemsDate: 12/23/2009Conceptual Cost EstimatePrepared by: MNOCost Type:Reviewed by: RKEst=EstimatedApproved by: PEFAllow.=AllowanceWage Rates Based on: 9NUR06C= ContractLabor Productivity = 1.15Q=Vendor QuoteCode ofAccountsItem DescriptionScope DefinitionCost TypeQuantityUnit ofMeasureUnit Equip.CostUnit MaterialCostTotal EquipmentCostTotal Material CostUnit Man-hours(Base)Total Man-hours(Base)Total Man-hours, Prod =1.15CrewCodeCrewWageRateTotal Construction& Erection CostTotal ProjectedCostSDA - Support Steel and Access Gallery23-25-75 Support Steel Included in DFGD equip. Est 300 TN 0 0 0 0 20 6,000 6,900 STST 87.33 602,600 602,60023-17-23 Walkwayfrom U1 SDA's to U2 SDA's Est 20 TN 0 0 0 0 35 700 805 STST 87.33 70,300 70,30023-17-23 Access GalleryEst 1,500 SF 0.00 35.00 0 52,500 0.40 600 690 GALL 67.14 46,300 98,80027-17-99 Touch-up painting Est 2 LT 0.00 45,000.00 0 90,000 1800.00 3,600 4,140 PNTR 56.92 235,600 325,600Reagent Handling / Preparation- Civil / StructuralWorkOne common for both units0Foundations for Lime Storage Silo21-53-13 Piles 16" dia X 60' deep, auger castEst 4,200 LF 0.00 12.65 0 53,100 0.35 1,470 0 PILE 86.18 0 53,10021-23-15 ExcavationEst 210 CY0.00 0.00 0 0 0.20 42 48 EXFD 63.95 3,100 3,10021-17-25 BackfillEst 60 CY0.00 0.00 0 0 0.30 18 21 EXFD 63.95 1,300 1,30022-13-37 ConcreteEst 150 CY0.00 105.00 0 15,800 1.50 225 259 CONP 51.69 13,400 29,20022-25-35 ReinforcingEst 14 TN 0.00 1,150.00 0 15,500 20.00 270 311 REIN 61.48 19,100 34,60022-17-25 FormworkEst 450 SF 0.00 2.50 0 1,100 0.14 61 70 FORM 71.62 5,000 6,10022-15-25 Embedded steel Est 0.38 TN 0.00 5,000.00 0 1,900 120.00 45 52 CARP 46.37 2,400 4,30023-25-75 Support Steel for lime Storage Silo Not required - concrete silo23-17-23 GalleriesEst 1,800 SF 0.00 35.00 0 63,000 0.40 720 828 GALL 67.14 55,600 118,60023-17-53 Stair Tower for Lime Storage SiloEst 120 TN 2,650 0 318,000 0 25 3,000 3,450 STST 87.33 301,300 619,30031-41-77 Fire Protection Standpipe & hose stations Est 1 LS 60,000.00 60,000 0 400.00 400 460 YDPP 63.15 29,000 89,000Lime Preparation / Recycle Building (55' x 100' x125'H)Quantities shown are total for 2buildings, 1/unit22 Substructure021-53-13 Piles 16" dia X 60' deep, auger castEst 9,600 LF 0.00 12.65 0 121,400 0.35 3,360 0 PILE 86.18 0 121,40021-23-15 ExcavationEst 1,284 CY0.00 0 0 0.20 257 295 EXFD 63.95 18,900 18,90021-17-25 BackfillEst 84 CY0.00 0 0 0.30 25 29 EXFD 63.95 1,900 1,90022-13-37 ConcreteEst 1,200 CY105.00 0 126,000 1.50 1,800 2,070 CONP 51.69 107,000 233,00022-25-35 ReinforcingEst 90 TN 1,150.00 0 103,500 20.00 1,800 2,070 REIN 61.48 127,300 230,80022-17-25 FormworkEst 3,600 SF 2.50 0 9,000 0.14 486 559 FORM 71.62 40,000 49,00022-15-25 Embedded steel Est 3.00 TN 5,000.00 0 15,000 120.00 360 414 CARP 46.37 19,200 34,200Superstructure23-25-75Structural SteelEst900 TN 26500 2,384,400 16 14,396 16,556 STST 87.33 1,445,800 3,830,20024-41-25Insulated Metal SidingEst80,000 SF 120 960,000 0.11 8,800 10,120 SDNG 63.02 637,800 1,597,80024-15-15RollingOverhead Doorone for each buildingEst640 SF 270 17,300 0.25 160 184 CARP 46.37 8,500 25,80023-23-23Metal Roof DeckingEst11,000 SF 2.70 29,700 0.06 660 759 STST 87.33 66,300 96,00024-37-43Rigid Roof Insulation, 2" ThickEst11,000 SF 2.40 26,400 0.015 165 190 ROOF 45.55 8,600 35,00024-37-17Cant Strips, TreatedEst620 LF 1.320 800 0.035 22 25 ROOF 45.55 1,100 1,90024-37-73Roofing(4-PlyTar & Gravel)Est11,000 SF 1.550 17,100 0.04 440 506 ROOF 45.55 23,000 40,10022-13-43Lightweight Concrete Fill 1"Est247 CY1000 24,700 1.3 321 369 ROOF 45.55 16,800 41,50024-37-27Roof FlashingEst620 LF 14.450 9,000 0.12 74 86 ROOF 45.55 3,900 12,90035-13-31Roof DrainsEst2 LT 200000 40,000 250 500 575 PLMB 47.74 27,500 67,50035-13-31Floor DrainsEst2 LT 250000 50,000 300 600 690 PLMB 47.74 32,900 82,90022-13-23 Floor Slabsincludes metal decking andformworkEst 101 CY 210 0 21,200 7.5 756 870 CONP 51.69 45,000 66,20022-13-23 Floor FinishesEst8,250 SF 2.50 20,600 0.05 413 474 CONP 51.69 24,500 45,10024-25-25Louvers/Windows/DoorsEst8,000 SF 400 320,000 0.5 4,000 4,600 CONP 51.69 237,800 557,80034-41-99Roof VentilatorsEst8 EA 150000 120,000 24 192 221 HVAC 51.91 11,500 131,50023-17-23Galleries & LandingsEst800 SF 450 36,000 0.4 320 368 GALL 67.14 24,700 60,70034-55-99H&VEst11,000 SF 16.70 183,300 0.17 1,833 2,108 HVAC 51.91 109,400 292,70041-37-99Electrical Service & LightingEst11,000 SF 20.00 220,000 0.20 2,200 2,530 WIRE 66.93 169,300 389,30031-41-77 Fire Protection Standpipe & hose stations Est 2 LS 60,000.00 120,000 0 400.00 800 920 YDPP 63.15 58,100 178,10023Pipe Rack For Lime Handling, Waste AshHandling and misc Mechanical PipingQuantities shown are totalfor 2 units23-25-75 Structure and Support Steel Est 300 TN 0.00 2,650.00 0 795,000 20.00 6,000 6,900 STST 87.33 602,600 1,397,60022 Foundations for support steel0 0021-53-13 Piles 16" dia X 60' deep, auger castEst 6,000 LF 0.00 12.65 0 75,900 0.35 2,100 0 PILE 86.18 0 75,90021-23-15 ExcavationEst 884 CY0.00 0.00 0 0 0.20 177 203 EXFD 63.95 13,000 13,00021-17-25 BackfillEst 234 CY0.00 0.00 0 0 0.30 70 81 EXFD 63.95 5,200 5,20022-13-37 ConcreteEst 650 CY0.00 105.00 0 68,300 1.50 975 1,121 CONP 51.69 58,000 126,30022-25-35 ReinforcingEst 49 TN 0.00 1,150.00 0 56,100 20.00 975 1,121 REIN 61.48 68,900 125,00022-17-25 FormworkEst 6,500 SF 0.00 2.50 0 16,300 0.14 878 1,009 FORM 71.62 72,300 88,60022-15-25 Embedded Steel Est 3,250 LB 0.00 2.50 0 8,100 0.05 163 187 CARP 46.37 8,700 16,80022 Foundations for Misc. Support SteelQuantities shown are total for 2units0 0021-23-15 ExcavationEst 272 CY0.00 0.00 0 0 0.20 54 63 EXFD 63.95 4,000 4,00021-17-25 BackfillEst 72 CY0.00 0.00 0 0 0.30 22 25 EXFD 63.95 1,600 1,600Page 2 of 14OG & EEstimate No.: 30352 AMuskogee Units 4 & 5Project No.: 11418-019Dry FGD SystemsDate: 12/23/2009Conceptual Cost EstimatePrepared by: MNOCost Type:Reviewed by: RKEst=EstimatedApproved by: PEFAllow.=AllowanceWage Rates Based on: 9NUR06C= ContractLabor Productivity = 1.15Q=Vendor QuoteCode ofAccountsItem DescriptionScope DefinitionCost TypeQuantityUnit ofMeasureUnit Equip.CostUnit MaterialCostTotal EquipmentCostTotal Material CostUnit Man-hours(Base)Total Man-hours(Base)Total Man-hours, Prod =1.15CrewCodeCrewWageRateTotal Construction& Erection CostTotal ProjectedCost22-13-37 ConcreteEst 200 CY0.00 105.00 0 21,000 1.50 300 345 CONP 51.69 17,800 38,80022-25-35 ReinforcingEst 15 TN 0.00 1,150.00 0 17,300 20.00 300 345 REIN 61.48 21,200 38,50022-17-25 FormworkEst 2,000 SF 0.00 2.50 0 5,000 0.14 270 311 FORM 71.62 22,200 27,20022-15-25 Embedded Steel Est 1,000 LB 0.00 2.50 0 2,500 0.05 50 58 CARP 46.37 2,700 5,20023-25-75 Misc. Support Steel not included elsewhereQuantities shown are total for 2unitsEst 100 TN 0 2,650 0 265,000 20 2,000 2,300 STST 87.33 200,900 465,90023-17-23 Misc. GalleriesQuantities shown are total for 2unitsEst 3,000 SF 0.00 35.00 0 105,000 0.40 1,200 1,380 GALL 67.14 92,700 197,700Fabric Filter24,079,500 4,500,100 273,513 17,293,300 45,872,90031-57-15 Fabric Filter System Q 2 LT 9,912,416 0.00 19,824,800 0 80,500 161,000 185,150 MECH 61.53 11,392,300 31,217,10031-17-45 Fabric Filter Baghouse Air Compressor SystemQ 2 LT 2,027,372 0.00 4,054,700 0 17,900 35,800 41,170 MECH 61.53 2,533,200 6,587,90035-13-15 Fabric Filter Baghouse Compressor System PipingIncluded in air compressorsystempricingEst 2 LT 0.00 0.00 0 0 0 0 0 MECH 61.53 0 031-27-35 Fabric Filter Bypass DampersIncluded in Fabric Filter SystemPriceEst 2 LT 0.00 0.00 0 0 0 0 0 MECH 61.53 0 031-57-99 Hopper HeatersIncluded in Fabric Filter SystemPriceEst 2 LT 0.00 0.00 0 0 0 0 0 MECH 61.53 0 031-57-99 Vent FanIncluded in Fabric Filter SystemPriceEst 2 LT 0.00 0.00 0 0 0 0 0 MECH 61.53 0 031-25-35 Hoist & Trolley BeamIncluded in Fabric Filter SystemPriceEst 2 LT 0.00 0.00 0 0 0 0 0 MECH 61.53 0 036-13-23Insulation for Baghousesubcontract costEst 65,111 SF 0.00 30.00 0 1,953,300 0 0 0 DINS 52.16 0 1,953,30023-25-75 Penthouse steel for baghousesSupport steel, roof steel, girtsand purlins.Est 79 TN 0.00 2,650.00 0 209,300 35.00 2,765 3,179 STST 87.33 277,600 486,90024-41-25 Siding for baghouse penthouse insulated metal siding Est 12,960 SF 0.00 12 0 155,500 0.11 1,426 1,639 SDNG 63.02 103,300 258,80024-37-47 Roofing for baghouse penthouse standing seam type Est 5,751 SF 0.00 18 0 103,500 0.22 1,265 1,455 ROOF 45.55 66,300 169,80022-13-23 Concrete bottom floor for baghouse penthouseincludes metal decking andformworkEst 70 CY 210 0 14,800 7.5 527 606 CONP 51.69 31,300 46,10041-37-99 BuildingServices H&V and LightingEst 5,751 SF 0.00 22.00 0 126,500 0.20 1,150 1,323 WIRE 66.93 88,500 215,00031-41-77 Fire Protection for Penthouse Standpipe & hose stations Est 2 LS 60,000.00 120,000 400.00 800 920 MECH 61.53 56,600 176,60023-25-75 Bottom Enclosure steelSupport steel, girts and purlins.Total for Units 1&2Est 171 TN 0.00 2,650.00 0 453,900 20 3,426 3,939 STST 87.33 344,000 797,90041-37-99 BuildingServices H&V and LightingEst 19,880 SF 0.00 22.00 0 437,400 0.20 3,976 4,572 WIRE 66.93 306,000 743,40024-41-25 Siding for baghouse bottom enclosureinsulated metal siding, supportsteel and girts included inAlstom pricingEst 17,976 SF 0.00 12 0 215,700 0.11 1,977 2,274 SDNG 63.02 143,300 359,00031-41-77 Fire Protection for bottom enclosure Standpipe & hose stations Est 2 LS 40,000.00 0.00 80,000 0 300.00 600 690 MECH 61.53 42,500 122,500Fabric Filter System - Structural0Foundations for Fabric Filter BaghouseQuantities shown are total for 2units21-53-13 Piles 16" dia X 60' deep, auger castEst 12,000 LF 0.00 12.65 0 151,800 0.35 4,200 0 PILE 86.18 0 151,80021-23-15 ExcavationEst 2,568 CY0.00 0.00 0 0.20 514 591 EXFD 63.95 37,800 37,80021-17-25 BackfillEst 168 CY0.00 0.00 0 0.30 50 58 EXFD 63.95 3,700 3,70022-13-37 ConcreteEst 2,400 CY0.00 105.00 0 252,000 1.50 3,600 4,140 CONP 51.69 214,000 466,00022-25-35 ReinforcingEst 216 TN 0.00 1,150.00 0 248,400 20.00 4,320 4,968 REIN 61.48 305,400 553,80022-17-25 FormworkEst 7,200 SF 0.00 2.50 0 18,000 0.14 972 1,118 FORM 71.62 80,100 98,10022-15-25 Embedded Steel Est 6.00 TN 0.00 5,000.00 30,000 120.00 720 828 CARP 46.37 38,400 68,400Support Steel and Access Gallery023-25-75 Support SteelIncluded in Baghouse equippriceQ 420 TN 0.00 0 0 0 25 10,500 12,075 STST 87.33 1,054,500 1,054,50023-17-23 Access GalleryQ 3,000 SF 0.00 35.00 0 105,000 0.40 1,200 1,380 GALL 67.14 92,700 197,70027-17-99 Touch-up painting Est 1 LT 0.00 25,000.00 0 25,000 1250.00 1,250 1,438 PNTR 56.92 81,800 106,800Page 3 of 14OG & EEstimate No.: 30352 AMuskogee Units 4 & 5Project No.: 11418-019Dry FGD SystemsDate: 12/23/2009Conceptual Cost EstimatePrepared by: MNOCost Type:Reviewed by: RKEst=EstimatedApproved by: PEFAllow.=AllowanceWage Rates Based on: 9NUR06C= ContractLabor Productivity = 1.15Q=Vendor QuoteCode ofAccountsItem DescriptionScope DefinitionCost TypeQuantityUnit ofMeasureUnit Equip.CostUnit MaterialCostTotal EquipmentCostTotal Material CostUnit Man-hours(Base)Total Man-hours(Base)Total Man-hours, Prod =1.15CrewCodeCrewWageRateTotal Construction& Erection CostTotal ProjectedCost0Ash Recycling System - DFGDContractor's Scope6,843,000 0 69,460 4,273,900 11,116,90031-45-99Ash Recycling System - Mechanical2 LT 3,421,528 6,843,000 30200 60,400 69,460 MECH 61.53 4,273,900 11,116,90031-45-99 Recycle Ash Storage SiloIncluded in Ash RecyclingSystem PriceQ 0.00 0.00 0 0 0 0 0 MECH 61.53 0 031-45-99 Recycle Ash Silo Bin VentIncluded in Ash RecyclingSystem PriceQ 0.00 0.00 0 0 0 0 0 MECH 61.53 0 031-45-99 Recycle Ash Fluidizing Air BlowerIncluded in Ash RecyclingSystem PriceQ 0.00 0.00 0 0 0 0 0 MECH 61.53 0 031-45-99 Recycle Ash Fluidizing Air HeaterIncluded in Ash RecyclingSystem PriceQ 0.00 0.00 0 0 0 0 0 MECH 61.53 0 031-45-99 Recycle Ash Silo Discharge Rotary FeederIncluded in Ash RecyclingSystem PriceQ 0.00 0.00 0 0 0 0 0 MECH 61.53 0 031-45-99 Recycle Slurry Vibrating ScreenIncluded in Ash RecyclingSystem PriceQ 0.00 0.00 0 0 0 0 0 MECH 61.53 0 031-45-99 Recycle Ash Prep Area Sump TankIncluded in Ash RecyclingSystem PriceQ 0.00 0.00 0 0 0 0 0 MECH 61.53 0 031-45-99 Recycle Ash Prep Area Sump Tank AgitatorIncluded in Ash RecyclingSystem PriceQ 0.00 0.00 0 0 0 0 0 MECH 61.53 0 031-45-99 Recycle Ash Slurry Mix TankIncluded in Ash RecyclingSystem PriceQ 0.00 0.00 0 0 0 0 0 MECH 61.53 0 031-45-99 Recycle Ash Slurry Mix Tank AgitatorIncluded in Ash RecyclingSystem PriceQ 0.00 0.00 0 0 0 0 0 MECH 61.53 0 031-45-99 Recycle Slurry Storage TankIncluded in Ash RecyclingSystem PriceQ 0.00 0.00 0 0 0 0 0 MECH 61.53 0 031-45-99 Recycle Slurry Storage Tank AgitatorIncluded in Ash RecyclingSystem PriceQ 0.00 0.00 0 0 0 0 0 MECH 61.53 0 031-45-99 Recycle Slurry Feed PumpsIncluded in Ash RecyclingSystem PriceQ 0.00 0.00 0 0 0 0 0 MECH 61.53 0 0Ash RecyclingSystem - BOP Scope60,000 565,200 4,583 360,800 986,000Ash Reagent Recycle BuildingIncluded with Lime PreparationBuilding24-35Ash Handling Blower Building (25' x 50' x 25'H)Quantities shown are total for 2buildings, 1/unit22-13 Substructure021-53-13 Piles 16" dia X 60' deep, auger castEst 2,400 LF 0.00 12.65 0 30,400 0.35 840 0 PILE 86.18 0 30,40021-23-15 ExcavationEst 214 CY0.00 0.00 0 0 0.20 43 49 EXFD 63.95 3,100 3,10021-17-25 BackfillEst 14 CY0.00 0.00 0 0 0.30 4 5 EXFD 63.95 300 30022-13-37 ConcreteEst 200 CY0.00 105.00 0 21,000 1.50 300 345 CONP 51.69 17,800 38,80022-25-35 ReinforcingEst 15 TN 0.00 1,150.00 0 17,300 20.00 300 345 REIN 61.48 21,200 38,50022-17-25 FormworkEst 800 SF 0.00 2.50 0 2,000 0.14 108 124 FORM 71.62 8,900 10,90022-15-25 Embedded Steel Est 1,600 LB 0.00 2.50 0 4,000 0.05 80 92 CARP 46.37 4,300 8,30024-35-25 Pre-engineered buildingIncludes H&V and LightingEst 2,500 SF 0.00 175.00 0 437,500 0.90 2,250 2,588 STST 87.33 226,000 663,50023-25-75 Additional Support Steel for Waste Ash Pipes outside of pipe rack Est 20 TN 0.00 2,650.00 0 53,000 25.00 500 575 STST 87.33 50,200 103,20031-41-77 Fire Protection Standpipe & hose stations Est 2 LS 30,000 60,000 200.00 400 460 YDPP 63.15 29,000 89,0000Waste Ash and Fly Ash HandlingSystem10,131,300 391,700 60,847 3,788,500 14,311,50033Waste Ash HandlingSystem - Mechanical026-13-15 Waste Ash siloConcrete silo - subcontractpriceQ 1 LT 1,550,000 0.00 1,550,000 0 0.00 0 0 CONP 51.69 0 1,550,00024-17-15 Elevator for waste ash silomaintenance elvator -subcontractpriceEst 1 LT 290,000 0.00 290,000 0 0 0 0 MECH 61.53 0 290,00022-13-27 Concrete pit for the elevator total for 2 silo elevators Est 10 CY 0 210.00 0 2,100 7.5 75 86 CONP 51.69 4,500 6,60041-99-99 Electrical work for the elevatorallowance Est 1 LT 0 20,000.00 0 20,000 175 175 201 WIRE 66.93 13,500 33,50033-13-45 Waste Handling SystsemIncludes blowers, ash valves,and ash pipingQ 1 LT 5,300,000 0.00 5,300,000 0 30,000 30,000 34,500 MECH 61.53 2,122,800 7,422,800Page 4 of 14OG & EEstimate No.: 30352 AMuskogee Units 4 & 5Project No.: 11418-019Dry FGD SystemsDate: 12/23/2009Conceptual Cost EstimatePrepared by: MNOCost Type:Reviewed by: RKEst=EstimatedApproved by: PEFAllow.=AllowanceWage Rates Based on: 9NUR06C= ContractLabor Productivity = 1.15Q=Vendor QuoteCode ofAccountsItem DescriptionScope DefinitionCost TypeQuantityUnit ofMeasureUnit Equip.CostUnit MaterialCostTotal EquipmentCostTotal Material CostUnit Man-hours(Base)Total Man-hours(Base)Total Man-hours, Prod =1.15CrewCodeCrewWageRateTotal Construction& Erection CostTotal ProjectedCost33-13-45 Mechanical EquipmentEst 0 0.00 0 0 0 0 0 MECH 61.53 0 033-13-45 Mechanical BlowersIncluded in Waste HandlingSystem PriceEst 0 0.00 0 0 0 0 0 MECH 61.53 0 033-13-45Waste Ash Silo Unloading Equipment includingFluidizing BlowersIncluded in Waste HandlingSystem Handling PriceEst 0 0.00 0 0 0 0 0 MECH 61.53 0 033-13-45Waste Ash Vacuum Pipes from FF hoppers toFilter SeparatorsIncluded in Waste HandlingSystem Handling PriceEst 0 0.00 0 0 0 0 0 MECH 61.53 0 033-13-45 Motor Operated Butterfly ValvesIncluded in Waste HandlingSystem HandlingPriceEst 0 0.00 0 0 0 0 0 MECH 61.53 0 022-13-75 Fly Ash SiloField erected steel silo. Pricingincludes mechanical equipmentand ash pipingEst 75 TN 4,000 0.00 300,000 0 70 5,250 6,038 TANK 61.57 371,700 671,70033-13-45Mechanical equipment for ash handling system andsilo fly ash unloading equipmentEst 1 LT 2,500,000 0.00 2,500,000 0 10,000 10,000 11,500 MECH 61.53 707,600 3,207,600Foundations for Fly Ash Silo021-53-13 Piles 16" dia X 60' deep, auger castEst 1,200 LF 0.00 12.65 0 15,200 0.35 420 0 PILE 86.18 0 15,20021-23-15 ExcavationEst 64 CY0.00 0.00 0 0.20 13 15 EXFD 63.95 900 90021-17-25 BackfillEst 24 CY0.00 0.00 0 0.30 7 8 EXFD 63.95 500 50022-13-37 ConcreteEst 40 CY0.00 105.00 0 4,200 1.50 60 69 CONP 51.69 3,600 7,80022-25-35 ReinforcingEst 4 TN 0.00 1,150.00 0 4,100 20.00 72 83 REIN 61.48 5,100 9,20022-17-25 FormworkEst 120 SF 0.00 2.50 0 300 0.14 16 19 FORM 71.62 1,300 1,60022-15-25 Embedded Steel Est 0.10 TN 0.00 5,000.00 500 120.00 12 14 CARP 46.37 600 1,10023-25-75 Support Steel for Fly Ash Storage Silo Est 50 TN 0.00 2,650.00 0 132,500 35.00 1,750 2,013 STST 87.33 175,800 308,30023-17-23 Access Gallery for fly ash silo Included with Misc Galleries. 0 SF 0 35 0 0 0.40 0 0 GALL 67.14 0 033-57-65 Truck ScaleEst 1 LT 125,000 0 125,000 0 900 900 1,035 MECH 61.53 63,700 188,70021-53-13 Piles 16" dia X 60' deep, auger castEst 900 LF 0.00 12.65 0 11,400 0.35 315 0 PILE 86.18 0 11,40022-13-37 Concrete foundation and approach for truck scaleEst 350 CY0 210 0 73,500 7.50 2,625 3,019 CONP 51.69 156,000 229,50041-99-99 Electrical allowance for truck scaleEst 1 LT 0 15,000 0 15,000 200.00 200 230 WIRE 66.93 15,400 30,400Foundations for Waste Ash Silo021-53-13 Piles 16" dia X 60' deep, auger castEst 2,400 LF 0.00 12.65 0 30,400 0.35 840 0 PILE 86.18 0 30,40021-23-15 ExcavationEst 160 CY0.00 0.00 0 0.20 32 37 EXFD 63.95 2,400 2,40021-17-25 BackfillEst 60 CY0.00 0.00 0 0.30 18 21 EXFD 63.95 1,300 1,30022-13-37 ConcreteEst 100 CY0.00 105.00 0 10,500 1.50 150 173 CONP 51.69 8,900 19,40022-25-35 ReinforcingEst 9 TN 0.00 1,150.00 0 10,400 20.00 180 207 REIN 61.48 12,700 23,10022-17-25 FormworkEst 300 SF 0.00 2.50 0 800 0.14 41 47 FORM 71.62 3,300 4,10022-15-25 Embedded Steel Est 0.25 TN 0.00 5,000.00 1,300 120.00 30 35 CARP 46.37 1,600 2,90023-25-75 Support Steel for Waste Ash Storage Silo concrete silo Est 0 TN 0.00 2,650.00 0 0 35.00 0 0 STST 87.33 0 023-17-53 Stair Tower for Waste Ash Silo Est 25 TN 2,650 0 66,300 0 25 625 719 STST 87.33 62,800 129,10023-17-23 Access Gallery for waste ash silo Est 1,700 SF 0 35 0 59,500 0.40 680 782 GALL 67.14 52,500 112,0000Flue Gas System5,810,000 18,243,400 399,371 28,184,800 52,238,200Spray Dryer Absorber Inlet Duct (from Existing IDFan Outlet)Quantities are total for 2 units023-15-35Ductwork Steel, including plate, stiffeners, internalbracing, turning vanes and walkway gratingEst 480 TN 0.00 3,250.00 0 1,560,000 60.00 28,800 33,120 FLDU 77.18 2,556,200 4,116,20036-13-57 Insulation & LaggingEst 47,000 SF 0.00 12.00 0 564,000 0.26 12,220 14,053 DINS 52.16 733,000 1,297,00031-33-15 Expansion JointsEst 1,300 LF 0.00 230.00 0 299,000 2.50 3,250 3,738 MECH 61.53 230,000 529,00031-27-35 Dampers Not Required44-21-99 Dry FGD Inlet Ductwork Instrumentation Est 4 LS 30,000.00 0.00 120,000 0 200 800 920 INEL 54.22 49,900 169,900Spray Dryer Absorber Outlet to Fabric Filter InletQuantities are total for 2 units023-15-35Ductwork Steel, including plate, stiffeners, internalbracing, turning vanes and walkway gratingEst 240 TN 0.00 3,250.00 0 780,000 60.00 14,400 16,560 FLDU 77.18 1,278,100 2,058,10036-13-57 Insulation & LaggingAllow 23,000 SF 0.00 12.00 0 276,000 0.26 5,980 6,877 DINS 52.16 358,700 634,70031-33-15 Expansion JointsEst 900 LF 0.00 0.00 0 0 2.50 2,250 2,588 MECH 61.53 159,200 159,20044-21-99 Dry FGD Outlet Ductwork Instrumentation Est 2 LS 30,000.00 0.00 60,000 0 200 400 460 INEL 54.22 24,900 84,90031-27-35 Dampers Not required Est 0 SF 450.00 0.00 0 0 3.00 0 0 MECH 61.53 0 0Page 5 of 14OG & EEstimate No.: 30352 AMuskogee Units 4 & 5Project No.: 11418-019Dry FGD SystemsDate: 12/23/2009Conceptual Cost EstimatePrepared by: MNOCost Type:Reviewed by: RKEst=EstimatedApproved by: PEFAllow.=AllowanceWage Rates Based on: 9NUR06C= ContractLabor Productivity = 1.15Q=Vendor QuoteCode ofAccountsItem DescriptionScope DefinitionCost TypeQuantityUnit ofMeasureUnit Equip.CostUnit MaterialCostTotal EquipmentCostTotal Material CostUnit Man-hours(Base)Total Man-hours(Base)Total Man-hours, Prod =1.15CrewCodeCrewWageRateTotal Construction& Erection CostTotal ProjectedCostFabric Filter Outlet Duct to Booster Fans andBooster ID Fans to existing chimney breechingQuantities are total for 2 units023-15-35Ductwork Steel, including plate, stiffeners, internalbracing, turning vanes and walkway gratingEst 1,650 TN 0.00 3,250.00 0 5,362,500 60.00 99,000 113,850 FLDU 77.18 8,786,900 14,149,40036-13-57 Insulation & LaggingEst 159,000 SF 0.00 12.00 0 1,908,000 0.26 41,340 47,541 DINS 52.16 2,479,700 4,387,70031-33-15 Expansion JointsEst 5,200 LF 0.00 230.00 0 1,196,000 2.50 13,000 14,950 MECH 61.53 919,900 2,115,90031-27-35 Dampers Not required Est 0 SF 450.00 0.00 0 0 2.50 0 0 MECH 61.53 0 044-21-99 Fabric Filter Outlet Ductwork Instrumentation Est 4 LS 30,000.00 0.00 120,000 0 200 800 920 INEL 54.22 49,900 169,900Booster ID FansQuantities are total for 2 units031-35-15 New Booster ID FansAxial fan, 2 x 50% per unit,882,450 cfm, includes fanauxiliaryequipmentEst 4 EA 775,000 0.00 3,100,000 0 3000.00 12,000 13,800 MECH 61.53 849,100 3,949,10041-43-35 Motors for Booster ID Fans 3500 HP Est 4 EA 250,000 0.00 1,000,000 0 1000.00 4,000 4,600 MECH 61.53 283,000 1,283,00031-25-35 Hoist & trolleys for Booster ID Fans 5-ton cap Est 4 EA 15,000 0.00 60,000 0 150.00 600 690 MECH 61.53 42,500 102,50036-13-23 Fan Insulation & Laggingtotal for two fansEst 6,000 SF 0.00 12.00 0 72,000 0.28 1,680 1,932 DINS 52.16 100,800 172,80031-27-35 Booster ID Fans Isolation DampersSingle Louver type damperassemblyEst 2,800 SF 450.00 0.00 1,260,000 0 2.50 7,000 8,050 MECH 61.53 495,300 1,755,300Flue Gas System - StructuralDuctwork Support Foundations Total for all ductwork for 2 units021-53-13 Piles 16" dia X 60' deep, auger castEst 21,600 LF 0.00 12.65 0 273,200 0.35 7,560 0 PILE 86.18 0 273,20021-23-15 ExcavationEst 2,140 CY0.00 0.00 0 0.20 428 492 EXFD 63.95 31,500 31,50021-17-25 BackfillEst 140 CY0.00 0.00 0 0.30 42 48 EXFD 63.95 3,100 3,10022-13-37 ConcreteEst 2,000 CY0.00 105.00 0 210,000 1.50 3,000 3,450 CONP 51.69 178,300 388,30022-25-35 ReinforcingEst 150 TN 0.00 1,150.00 0 172,500 20.00 3,000 3,450 REIN 61.48 212,100 384,60022-17-25 FormworkEst 6,000 SF 0.00 2.50 0 15,000 0.14 810 932 FORM 71.62 66,700 81,70022-15-25 Embedded Steel Est 5.00 TN 0.00 5,000.00 25,000 120.00 600 690 CARP 46.37 32,000 57,00023-25-75 Structural Steel Duct SupportsEst 1,800 TN 0.00 2,650.00 0 4,770,000 35.00 63,000 72,450 STST 87.33 6,327,100 11,097,100Booster ID Fan FoundationsQuantities are total for 2 units0021-53-13 Piles 16" dia X 60' deep, auger castEst 3,000 LF 0.00 12.65 0 38,000 0.35 1,050 0 PILE 86.18 0 38,00021-23-15 ExcavationEst 1,819 CY0.00 0.00 0 0.20 364 418 EXFD 63.95 26,800 26,80021-17-25 BackfillEst 119 CY0.00 0.00 0 0.30 36 41 EXFD 63.95 2,600 2,60022-13-37 ConcreteEst 1,700 CY0.00 105.00 0 178,500 1.50 2,550 2,933 CONP 51.69 151,600 330,10022-25-35 ReinforcingEst 128 TN 0.00 1,150.00 0 146,600 20.00 2,550 2,933 REIN 61.48 180,300 326,90022-17-25 FormworkEst 13,600 SF 0.00 2.50 0 34,000 0.14 1,836 2,111 FORM 71.62 151,200 185,20022-15-25 Embedded Steel Est 8.50 TN 0.00 5,000.00 0 42,500 120.00 1,020 1,173 CARP 46.37 54,400 96,90023-17-23 Access Gallery for all inlet and outlet ductwork Est 3,000 SF 0 35.00 0 105,000 0.40 1,200 1,380 GALL 67.14 92,700 197,70041-37-43 Lightingfor accessgalleries and Booster Fan areaEst 6,000 SF 0.00 15.00 0 90,000 0.15 900 1,035 WIRE 66.93 69,300 159,300Stack CoatingAcid resistant coating - top50 ft of liner. Assumedchimney liner 20Ft dia x 500ft high61-23-35 Suspended Motorized Modular Platform Rental90 dayrental, each stackEst. 2 LT 45,000.00 0.00 90,000 0 300.00 600 690 CARP 46.37 32,000 122,00027-15-35Prep and clean top 50ft of two flues (inside only) towhite metal(SSPC-SP 5)Quantities shown are for 2stacks. Includes misc. repairsEst. 6,400 SF 0.00 0.00 0 0 1.33 8,512 9,789 PNTR 56.92 557,200 557,20027-13-99 Apply acid resistant coatingQuantities shown are for 2stacks.Est. 6,400 SF 0.00 16.50 0 105,600 1.33 8,512 9,789 PNTR 56.92 557,200 662,80061-17-43 TemporaryPower, Light and VentilationEst. 2 LT 0.00 10,000.00 0 20,000 400.00 800 920 WIRE 66.93 61,600 81,600Mechanical - Balance of Plant0 2,590,000 54,625 3,611,400 6,201,400PipingVacuum Conveying35-13-99Vacuum conveyingto lime siloEst 0 LF 0.00 57.60 0 0 1.50 0 0 SPNG 67.64 0 0Page 6 of 14OG & EEstimate No.: 30352 AMuskogee Units 4 & 5Project No.: 11418-019Dry FGD SystemsDate: 12/23/2009Conceptual Cost EstimatePrepared by: MNOCost Type:Reviewed by: RKEst=EstimatedApproved by: PEFAllow.=AllowanceWage Rates Based on: 9NUR06C= ContractLabor Productivity = 1.15Q=Vendor QuoteCode ofAccountsItem DescriptionScope DefinitionCost TypeQuantityUnit ofMeasureUnit Equip.CostUnit MaterialCostTotal EquipmentCostTotal Material CostUnit Man-hours(Base)Total Man-hours(Base)Total Man-hours, Prod =1.15CrewCodeCrewWageRateTotal Construction& Erection CostTotal ProjectedCostMakeup Water35-13-158" CS, SCH 40, includes fittings, undergroundRaw water to reagentprepEst 1,160 LF 0.00 130.20 0 151,000 1.88 2,181 2,508 YDPP 63.15 158,400 309,40021-25-15 Excavation for Underground PipingEst 644 CY0.00 0.00 0 0 0.20 129 148 EXFD 63.95 9,500 9,50021-17-15 Beddingfor Underground PipingEst 97 CY0.00 40.00 0 3,900 0.30 29 33 EXFD 63.95 2,100 6,00021-17-25 Backfill for Underground PipingEst 548 CY0.00 0.00 0 0 0.30 164 189 EXFD 63.95 12,100 12,10035-13-156" CS, SCH 40, includes fittings, undergroundRaw water to reagentprepEst 900 LF 0.00 89.50 0 80,600 1.60 1,440 1,656 YDPP 63.15 104,600 185,20035-13-15 2.5" CS, SCH 40, includes fittings Slaker water and dilution water Est 320 LF 0.00 35.60 0 11,400 1.28 410 471 SPNG 67.64 31,900 43,30035-13-15 2.5" CS, SCH 80, includes fittings Slaker water and dilution water Est 320 LF 0.00 55.50 0 17,800 1.44 461 530 SPNG 67.64 35,800 53,60035-13-154" CS, SCH 80, includes fittings Recycle waterEst 720 LF 0.00 57.60 0 41,500 1.81 1,303 1,499 SPNG 67.64 101,400 142,90035-13-33Pipe Supports for MakeupWaterpipingEst 4.00 TN 0.00 2,650.00 0 10,600 40.00 160 184 STST 87.33 16,100 26,700Service Water35-13-15 6" CS, SCH 40, includes fittings, undergroundExtend existing service waterline to new lime unloadingareaEst 30 LF 0.00 89.50 0 2,700 1.60 48 55 YDPP 63.15 3,500 6,20035-13-15 3" CS, SCH 40, includes fittings, undergroundReagent prep building abd flyash silosEst 50 LF 0.00 48.80 0 2,400 1.37 69 79 YDPP 63.15 5,000 7,40021-25-15 Excavation for Underground PipingEst 44 CY0.00 0.00 0 0 0.20 9 10 EXFD 63.95 700 70021-17-15 Beddingfor Underground PipingEst 7 CY0.00 40.00 0 300 0.30 2 2 EXFD 63.95 100 40021-17-25 Backfill for Underground PipingEst 38 CY0.00 0.00 0 0 0.30 11 13 EXFD 63.95 800 80035-13-153" CS, SCH 40, includes fittings Absorbers(penthouse)Est 680 LF 0.00 48.80 0 33,200 1.37 932 1,071 SPNG 67.64 72,500 105,70035-15-15 2" CS, SCH 80, includes fittingsReagent prep building,absorbers (penthouse), fly ashsilosEst 600 LF 0.00 39.80 0 23,900 1.36 816 938 SPNG 67.64 63,500 87,40035-13-33Pipe Supports for Service WaterpipingEst 1.51 TN 0.00 2,650.00 0 4,000 40.00 60 69 STST 87.33 6,100 10,100Lime SlurryPipe35-13-15 2.5" CS, SCH 80, includes fittingsReagent prep to atomizer headtank in SDAEst 1,410 LF 0.00 55.50 0 78,300 1.44 2,030 2,335 SPNG 67.64 157,900 236,20035-13-33Pipe Supports for Service WaterpipingEst 2.07 TN 0.00 2,650.00 0 5,500 40.00 83 95 STST 87.33 8,300 13,800Ash Pipe35-13-99 10" Ashcolite, flangedSupports included with piperackEst 1,440 LF 0.00 165.00 0 237,600 1.75 2,520 2,898 YDPP 63.15 183,000 420,60035-13-33Pipe supports within buildingboundariesEst 10 EA 0.00 125.00 0 1,300 3.00 30 35 STST 87.33 3,000 4,300Recycle SlurryPipe35-13-15 6" CS, SCH 80, includes fittings, undergroundRecycle ash silo to atomizerhead tankEst 1,410 LF 0.00 135.20 0 190,600 1.94 2,735 3,146 YDPP 63.15 198,700 389,30035-13-33Pipe Supports for Recycle SlurrypipingEst 5.03 TN 0.00 2,650.00 0 13,300 40.00 201 232 STST 87.33 20,200 33,500SlurryReturn Pipe35-13-156" CS, SCH 80, includes fittings, undergroundSDA to reagentprepEst 1,410 LF 0.00 135.20 0 190,600 1.94 2,735 3,146 YDPP 63.15 198,700 389,30035-13-33Pipe Supports for Recycle SlurrypipingEst 5.03 TN 0.00 2,650.00 0 13,300 40.00 201 232 STST 87.33 20,200 33,500SumpDischarge / Drains35-13-15 2.5" CS, SCH 40, includes fittings Absorber and Prep Building Est 260 LF 0.00 35.60 0 9,300 1.28 333 383 SPNG 67.64 25,900 35,20035-13-153" CS, SCH 40, includes fittings ReagentprepbuildingEst 130 LF 0.00 48.80 0 6,300 1.37 178 205 SPNG 67.64 13,900 20,20035-13-154" CS, SCH 40, includes fittings ReagentprepbuildingEst 770 LF 0.00 57.60 0 44,400 1.50 1,155 1,328 SPNG 67.64 89,800 134,20035-13-33Pipe Supports for SumpDischarge and DrainsEst 1.42 TN 0.00 2,650.00 0 3,800 40.00 57 65 STST 87.33 5,700 9,50035-13-213" HDPE includes fittings Undeground. Absorber SumpsEst 3,460 LF 0.00 4.80 0 16,600 1.37 4,740 5,451 SPNG 67.64 368,700 385,30035-13-214" HDPE includes fittings FlyAsh Silos, Lime Silos Est 2,720 LF 0.00 4.80 0 13,100 1.48 4,026 4,629 SPNG 67.64 313,100 326,20021-25-15 Excavation for Underground PipingEst 2,289 CY0.00 0.00 0 0 0.20 458 526 EXFD 63.95 33,700 33,70021-17-15 Beddingfor Underground PipingEst 343 CY0.00 40.00 0 13,700 0.30 103 118 EXFD 63.95 7,600 21,30021-17-25 Backfill for Underground PipingEst 1,946 CY0.00 0.00 0 0 0.30 584 671 EXFD 63.95 42,900 42,900Fire Protection35-13-35 6" HDPE, includes fittingsExtend existing and new forAbsorber, Reagent Prep, FlyAsh Silos and Lime SilosEst 1,660 LF 0.00 8.50 0 14,100 0.60 996 1,145 SPNG 67.64 77,500 91,60021-25-15 Excavation for Underground PipingEst 769 CY0.00 0.00 0 0 0.20 154 177 EXFD 63.95 11,300 11,30021-17-15 Beddingfor Underground PipingEst 115 CY0.00 40.00 0 4,600 0.30 35 40 EXFD 63.95 2,500 7,10021-17-25 Backfill for Underground PipingEst 653 CY0.00 0.00 0 0 0.30 196 225 EXFD 63.95 14,400 14,400Page 7 of 14OG & EEstimate No.: 30352 AMuskogee Units 4 & 5Project No.: 11418-019Dry FGD SystemsDate: 12/23/2009Conceptual Cost EstimatePrepared by: MNOCost Type:Reviewed by: RKEst=EstimatedApproved by: PEFAllow.=AllowanceWage Rates Based on: 9NUR06C= ContractLabor Productivity = 1.15Q=Vendor QuoteCode ofAccountsItem DescriptionScope DefinitionCost TypeQuantityUnit ofMeasureUnit Equip.CostUnit MaterialCostTotal EquipmentCostTotal Material CostUnit Man-hours(Base)Total Man-hours(Base)Total Man-hours, Prod =1.15CrewCodeCrewWageRateTotal Construction& Erection CostTotal ProjectedCost35-13-15 3" CS, SCH 40, includes fittingsAbsorber, Reagent Prep, FlyAsh Silos and Lime SilosEst 1,120 LF 0.00 48.80 0 54,700 1.37 1,534 1,765 SPNG 67.64 119,400 174,10035-13-33Pipe Supports for Fire ProtectionEst 1.44 TN 0.00 2,650.00 0 3,800 40.00 58 66 STST 87.33 5,800 9,600Service Air35-13-15 3" CS, SCH 40, includes fittingsAbsorber, Reagent Prep, FlyAsh Silos and Lime SilosEst 2,280 LF 0.00 48.80 0 111,300 1.37 3,124 3,592 SPNG 67.64 243,000 354,30035-15-15 2" CS, SCH 80, includes fittingsReagent prep building,absorbers (penthouse), fly ashsilosEst 1,000 LF 0.00 39.80 0 39,800 1.36 1,360 1,564 SPNG 67.64 105,800 145,60035-13-33Pipe Supports for Service AirEst 3.99 TN 0.00 2,650.00 0 10,600 40.00 160 184 STST 87.33 16,000 26,600Instrument Air35-15-13 2" 304SS, SCH 80, weldedAbsorber, Reagent Prep, FlyAsh Silos and Lime SilosEst 1,810 LF 0.00 101.42 0 183,600 1.63 2,946 3,388 SPNG 67.64 229,100 412,70035-15-13 1.5" 304SS, SCH 80, welded FlyAsh Silos and Lime SilosEst 470 LF 0.00 73.37 0 34,500 1.51 711 817 SPNG 67.64 55,300 89,80035-15-13 1" 304SS, SCH 80, weldedAbsorber, Reagent Prep, FlyAsh Silos and Lime SilosEst 1,140 LF 0.00 44.22 0 50,400 1.46 1,664 1,913 SPNG 67.64 129,400 179,80035-13-33Pipe Supports for Instrument AirEst 7.09 TN 0.00 2,650.00 0 18,800 40.00 284 326 STST 87.33 28,500 47,300Valves31-41-47 HydrantsEst 4 EA 0.00 1,500.00 0 6,000 6.00 24 28 YDPP 63.15 1,700 7,70035-13-41 Valves with PIVS 6", CI Est 6 EA 0.00 575.00 0 3,500 6.00 36 41 YDPP 63.15 2,600 6,10035-15-411" CS BallEst 4 EA 0.00 150.00 0 600 3.00 12 14 SPNG 67.64 900 1,50035-15-412" Bronze, BallEst 4 EA 0.00 750.00 0 3,000 4.00 16 18 SPNG 67.64 1,200 4,20035-13-41 3" CS, Globe, welded Est 32 EA 0.00 1,800.00 0 57,600 4.00 128 147 SPNG 67.64 10,000 67,60035-13-41 6" CS Knifegate, welded Est 4 EA 0.00 3,200.00 0 12,800 8.00 32 37 SPNG 67.64 2,500 15,30035-13-41 8" CS Knifegate, welded Est 20 EA 0.00 4,800.00 0 96,000 10.00 200 230 SPNG 67.64 15,600 111,60035-13-41 12" CS Knifegate, welded Est 8 EA 0.00 7,200.00 0 57,600 14.00 112 129 SPNG 67.64 8,700 66,30035-15-41Small bore valves, CS wededl Allowance Est 1 LT 0.00 10,000.00 0 10,000 60.00 60 69 SPNG 67.64 4,700 14,70031-75-93 SumpPumps 440gpm, 220 TDH Est 8 EA 0.00 25,000.00 0 200,000 30.00 240 276 MECH 61.53 17,000 217,00031-17-45 Air compressors 250 SCFM, 100psigEst 2 EA 0.00 45,000.00 0 90,000 60.00 120 138 MECH 61.53 8,500 98,50031-17-65 Air receivers 1000 Gal Est 2 EA 0.00 7,000.00 0 14,000 20.00 40 46 MECH 61.53 2,800 16,80031-17-55 Air dryers250 net SCFM, 100psigEst 2 EA 0.00 15,000.00 0 30,000 30.00 60 69 MECH 61.53 4,200 34,20031-65-99 In-line electric water heaters(boilers)475 kW Est 2 EA 0.00 17,200.00 0 34,400 80.00 160 184 MECH 61.53 11,300 45,70041-99-99 Allowance for electrical work for the electric boiler Allow 2 EA 0.00 5,000.00 0 10,000 20.00 40 46 WIRE 66.93 3,100 13,10041Heat Tracing for Instrumentation Piping041-33-65Heat tracingcableAllow. 5,700 LF 0.00 10.35 0 59,000 0.05 285 328 WIRE 66.93 21,900 80,90036-15 Insulation for heat traced piping Assumed nominal 4" pipe size Allow. 5,976 SF 0.00 10.00 0 59,800 0.25 1,494 1,718 INSL 45.09 77,500 137,30041-33-65Power connector and other accessories includingthermostats for heat tracing (by zones)Allow. 104 LS 0.00 950.00 98,500 8.00 829 953 WIRE 66.93 63,800 162,3000Electrical - Auxiliary Power and Balanceof Plant Electrical Work13,592,400 5,414,900 250,133 18,916,300 37,923,60041 Auxiliary Power Modifications Quantities are total for Unit 1&241-51-15 Rserve Aux. Transformer230kV - 4.16kV, 34/45 MVA,3phaseEst 1 EA 544,000.00 0.00 544,000 0 1,500 1,500 1,725 EHEA 67.88 117,100 661,10041-51-15 Unit Aux. Transformers24kV - 4.16kV, 15/20 MVA, 3phaseEst 2 EA 490,000.00 0.00 980,000 0 1,200 2,400 2,760 EHEA 67.88 187,300 1,167,30041-51-15 Transformer, 480 V Substation4.16KV-480V,3phase,2000/2666KVAEst 4 EA 85,000.00 0.00 340,000 0 950.00 3,800 4,370 EHEA 67.88 296,600 636,60041-51-15 Transformer, 480 V Substation4.16KV-480V,3phase,1500/2000KVAEst 4 EA 77,000.00 0.00 308,000 0 950.00 3,800 4,370 EHEA 67.88 296,600 604,600Page 8 of 14OG & EEstimate No.: 30352 AMuskogee Units 4 & 5Project No.: 11418-019Dry FGD SystemsDate: 12/23/2009Conceptual Cost EstimatePrepared by: MNOCost Type:Reviewed by: RKEst=EstimatedApproved by: PEFAllow.=AllowanceWage Rates Based on: 9NUR06C= ContractLabor Productivity = 1.15Q=Vendor QuoteCode ofAccountsItem DescriptionScope DefinitionCost TypeQuantityUnit ofMeasureUnit Equip.CostUnit MaterialCostTotal EquipmentCostTotal Material CostUnit Man-hours(Base)Total Man-hours(Base)Total Man-hours, Prod =1.15CrewCodeCrewWageRateTotal Construction& Erection CostTotal ProjectedCost41-41-99FGD/FF Power Control Centers (one for each unit -stacked)(30'x60') building, includes:Enclosure with HVAC andLighting/electric service4160V swgr480V swgrMCCsUPSBatteries / ChargersRoom/Area designated forDCSPhone JackEst 2 EA 2,103,000.00 0.00 4,206,000 0 500.00 1,000 1,150 EHEA 67.88 78,100 4,284,10023-17-23 Platforms around elevated PCCquantities are total for Unit 1&2PCCsEst 2,850 SF 35.00 0.00 99,800 0 0.40 1,140 1,311 GALL 84.98 111,400 211,20023-25-75 Support steel for PCC platforms Est 40 TN 2,650.00 0.00 106,000 0 60.00 2,400 2,760 STST 105.69 291,700 397,70041-41-99 UAT Power Control Centers (one for each unit).(15'x20') building, includes:Enclosure with HVAC andLighting/electric service4160V swgrEst 2 EA 300,000.00 0.00 600,000 0 200.00 400 460 EHEA 67.88 31,200 631,20023-25-75Auxiliary Steel Modifications for UAT PCC's to belocated on turbine floor of each unitEst 7 TN 2,650.00 0.00 18,600 0 60.00 420 483 STST 105.69 51,000 69,60041-13-15 5KV Cable Bus duct 3000A Est 10,000 FT 550.00 0.00 5,500,000 0 2.50 25,000 28,750 WIRE 85.64 2,462,200 7,962,20023-25-75 Support steel for cable bus duct Est 84 TN 0.00 2,650.00 0 222,600 16.00 1,344 1,546 STST 87.33 135,000 357,60043-21-15 Cable Bus Terminations 750 KCM Est 288 EA 0.00 100.00 0 28,800 3.00 864 994 WIRE 85.64 85,100 113,90041-47-25 Relay PanelsEst 6 EA 40,000.00 0.00 240,000 0 120.00 720 828 WIRE 85.64 70,900 310,90041-51-99 Lightingtransformers 45KVA, 480V, 3 Phase Low voltage XFMREst 16 EA 15,000.00 250.00 240,000 4,000 80.00 1,280 1,472 WIRE 85.64 126,100 370,10041-47-15 Lighting Distribution panel, 200A, 208-120V, 3 PhaseLow voltage panel Est 16 EA 10,000.00 200.00 160,000 3,200 60.00 960 1,104 WIRE 85.64 94,500 257,70022-13-17 Duct Bank- Swgr Bldg to Truck Scale24"x24", 4x4" cells (includesembedded conduit)Est 900 LF 0.00 125 0 112,500 1.60 1,440 1,656 ECND 64.88 107,400 219,90042-13-47 Cable Trays 36" Trays Est 2,100 LF 0.00 30.00 0 63,000 1.00 2,100 2,415 ECND 64.88 156,700 219,70042-13-47 Cable Trays 24" Control, & 24" Instrument Est 2,100 LF 0.00 25.00 0 1.00 2,100 2,415 ECND 64.88 156,700 156,70042-15-37 Conduits misc sizes Est 2,100 LF 0.00 10.00 0 21,000 0.35 735 845 ECND 64.88 54,800 75,800Miscellaneous Electrical System041-15-15 Cathodic Protection Allowance Allow. 2 LS 75,000.00 0.00 150,000 0 700.00 1,400 1,610 WIRE 85.64 137,900 287,90041-25-55 Upgrade Fire detection systemAllowance Allow. 2 LS 50,000.00 0.00 100,000 0 250.00 500 575 INEL 73.2 42,100 142,100CABLES43-21-15 Cables 5kV 3/C, 500 kcmil Est 9,000 LF 0.00 29.11 0 262,000 0.69 6,210 7,142 WIRE 85.64 611,600 873,60043-21-15 Cables 5kV 3/C, 250 kcmil Est 1,050 LF 0.00 16.77 0 17,600 0.69 725 833 WIRE 85.64 71,400 89,00043-21-15 Cables 5kV 3/C, #4/0 Est 6,300 LF 0.00 9.78 0 61,600 0.35 2,205 2,536 WIRE 85.64 217,200 278,80043-21-35 Cables 5kV Terminations Est 91 EA 0.00 50.00 0 4,600 1.25 114 131 WIRE 85.64 11,200 15,800480 V FGD Unit Substation FGD (SDA, FabricFilter)43-17-15Power Feeder Cable, 600 V, from Unit Sub FGD toMCCsPower Feed to all MCC's (1/C750 MCM)Est 31,500 LF 0.00 9.82 0 309,300 0.18 5,670 6,521 WIRE 85.64 558,400 867,70043-17-15 Power Cable, 600 V(to equipment)3/C, #10 Est 21,000 LF 0.00 0.87 0 18,300 0.06 1,260 1,449 WIRE 85.64 124,100 142,40043-17-15 Power Cable, 600 V(to equipment)3/C, #6 Est 18,900 LF 0.00 1.92 0 36,300 0.10 1,890 2,174 WIRE 85.64 186,100 222,400Page 9 of 14OG & EEstimate No.: 30352 AMuskogee Units 4 & 5Project No.: 11418-019Dry FGD SystemsDate: 12/23/2009Conceptual Cost EstimatePrepared by: MNOCost Type:Reviewed by: RKEst=EstimatedApproved by: PEFAllow.=AllowanceWage Rates Based on: 9NUR06C= ContractLabor Productivity = 1.15Q=Vendor QuoteCode ofAccountsItem DescriptionScope DefinitionCost TypeQuantityUnit ofMeasureUnit Equip.CostUnit MaterialCostTotal EquipmentCostTotal Material CostUnit Man-hours(Base)Total Man-hours(Base)Total Man-hours, Prod =1.15CrewCodeCrewWageRateTotal Construction& Erection CostTotal ProjectedCost43-17-15 Power Cable, 600 V(to equipment)3/C, #4 Est 7,770 LF 0.00 2.55 0 19,800 0.35 2,720 3,127 WIRE 85.64 267,800 287,60043-17-15 Power Cable, 600 V(to equipment)3/C, #2 Est 1,890 LF 0.00 4.40 0 8,300 0.35 662 761 WIRE 85.64 65,100 73,40043-17-15 Power Cable, 600 V(to equipment)3/C, #1/0 Est 2,100 LF 0.00 6.33 0 13,300 0.52 1,092 1,256 WIRE 85.64 107,500 120,80043-17-15 Power Cable, 600 V(to equipment)3/C, #4/0 Est 2,730 LF 0.00 13.35 0 36,400 0.52 1,420 1,633 WIRE 85.64 139,800 176,20043-17-15 Power Cable, 600 V(to equipment)3/C, 350KCMILEst 2,100 LF 0.00 17.98 0 37,800 0.69 1,449 1,666 WIRE 85.64 142,700 180,50043-17-15 Power Cable, 600 V(to equipment)3/C, 500KCMILEst 2,100 LF 0.00 26.41 0 55,500 0.69 1,449 1,666 WIRE 85.64 142,700 198,20043-17-15 Power Cable, 600 V(for VFD's)4/C, #10 SHLD Est 2,100 LF 0.00 1.20 0 2,500 0.07 147 169 WIRE 85.64 14,500 17,00043-17-15 Power Cable, 600 V(for VFD's)4/C, #6 SHLD Est 840 LF 0.00 2.70 0 2,300 0.10 84 97 WIRE 85.64 8,300 10,60043-17-15 Power Cable, 600 V(for VFD's)4/C, #4 SHLD Est 630 LF 0.00 3.65 0 2,300 0.35 221 254 WIRE 85.64 21,700 24,00043-17-15 Power Cable, 600 V(for VFD's)3/C, 350KCMIL, SHLDEst 2,100 LF 0.00 16.52 0 34,700 0.69 1,449 1,666 WIRE 85.64 142,700 177,40043-13-17 Control Cable, 600V5/C, #10 Est 6,300 LF 0.00 1.30 0 8,200 0.08 504 580 WIRE 85.64 49,600 57,80043-13-17 Control Cable, 600V2/C, #14 Est 31,500 LF 0.00 0.37 0 11,700 0.03 945 1,087 WIRE 85.64 93,100 104,80043-13-17 Control Cable, 600V3/C, #14 Est 14,700 LF 0.00 0.42 0 6,200 0.03 441 507 WIRE 85.64 43,400 49,60043-13-17 Control Cable, 600V5/C, #14 Est 6,300 LF 0.00 0.68 0 4,300 0.03 189 217 WIRE 85.64 18,600 22,90043-13-17 Control Cable, 600V7/C, #14 Est 2,100 LF 0.00 0.95 0 2,000 0.04 84 97 WIRE 85.64 8,300 10,30043-13-17 Control Cable, 600V9/C, #14 Est 2,100 LF 0.00 1.17 0 2,500 0.05 105 121 WIRE 85.64 10,300 12,80043-17-35 Power & Control Cable TerminationsPower: 600, Control:1200Est 3,780 EA 0.00 1.00 0 3,800 0.30 1,134 1,304 WIRE 85.64 111,700 115,50043-13-13 Instrumentation Cable, 300V2pr, #16 TW SHLD Est 63,000 LF 0.00 0.32 0 20,200 0.03 2,016 2,318 WIRE 85.64 198,500 218,70043-13-13 Instrumentation Cable, 300V2 tr, #16 TW SHLD Est 14,700 LF 0.00 0.43 0 6,300 0.03 470 541 WIRE 85.64 46,300 52,60043-13-13 Instrumentation Cable, 300V2pr, #16 SHLD typeEEst 14,700 LF 0.00 0.35 0 5,100 0.03 470 541 WIRE 85.64 46,300 51,40043-13-33 Fiber Optic Cable 2 strand Est 2,100 LF 0.00 0.50 0 1,100 0.03 63 72 WIRE 85.64 6,200 7,30043-13-33 Fiber Optic Cable 6 strand Est 5,250 LF 0.00 0.96 0 5,000 0.03 158 181 WIRE 85.64 15,500 20,50043-13-33 Fiber Optic Cable 12 strand Est 1,260 LF 0.00 1.46 0 1,800 0.03 38 43 WIRE 85.64 3,700 5,50043-13-33 Fiber Optic Cable 24 strand Est 2,730 LF 0.00 2.21 0 6,000 0.05 137 157 WIRE 85.64 13,400 19,40043-13-99 Profibus DP Cable Est 8,400 LF 0.00 1.50 0 12,600 0.05 420 483 WIRE 85.64 41,400 54,00043-13-27 Cat 5EEst 3,150 LF 0.00 1.40 0 4,400 0.05 158 181 WIRE 85.64 15,500 19,90043-13-43 Instrumentation Cable TerminationsEst 6,300 EA 0.00 1.00 0 6,300 0.25 1,575 1,811 WIRE 85.64 155,100 161,40042-17-15 Misc. Junction Boxes & Pull BoxesEst 2 LT 0.00 154,000.00 0 308,000 900.00 1,800 2,070 WIRE 85.64 177,300 485,30042-13-47 Cable Trays36" Trays Est 8,400 LF 0.00 30.00 0 252,000 1.00 8,400 9,660 ECND 64.88 626,700 878,70042-13-47 Cable Trays24" Control, & 24" InstrumentEst 12,600 LF 0.00 25.00 0 1.00 12,600 14,490 ECND 64.88 940,100 940,10042-15-37 Conduits misc sizes Est 73,500 LF 0.00 10.00 0 735,000 0.35 25,725 29,584 ECND 64.88 1,919,400 2,654,40041-31-15 GroundingIncludes ground grid, rods,bolted connections & cadwelds.Future installation onlyEst 2 LT 0.00 50,000.00 0 100,000 800.00 1,600 1,840 WIRE 85.64 157,600 257,60041-17-25 PA / Page PartyExtension SystemAllow. 2 LT 0.00 20,000.00 0 40,000 300.00 600 690 WIRE 85.64 59,100 99,10041-17-35 Data COM Extension SystemAllow. 2 LT 0.00 5,000.00 0 10,000 120.00 240 276 WIRE 85.64 23,600 33,60041-17-35 Telephone Extension SystemAllow. 2 LT 0.00 5,000.00 0 10,000 140.00 280 322 WIRE 85.64 27,600 37,60041-53-17 SecuritySystemAllow. 2 LT 0.00 100,000.00 0 200,000 600.00 1,200 1,380 WIRE 85.64 118,200 318,200480 V Lime/Ash Handling Unit Sub (LimeHandling, Reagent Prep, Ash Handl Area)43-17-15 Power Cable, 600 V(to equipment)3/C, #10 Est 18,900 LF 0.00 0.87 0 16,400 0.06 1,134 1,304 WIRE 85.64 111,700 128,10043-17-15 Power Cable, 600 V(to equipment)3/C, #6 Est 18,900 LF 0.00 1.92 0 36,300 0.10 1,890 2,174 WIRE 85.64 186,100 222,40043-17-15 Power Cable, 600 V(to equipment)3/C, #4 Est 6,300 LF 0.00 2.55 0 16,100 0.35 2,205 2,536 WIRE 85.64 217,200 233,30043-17-15 Power Cable, 600 V(to equipment)3/C, #1/0 Est 2,100 LF 0.00 6.33 0 13,300 0.52 1,092 1,256 WIRE 85.64 107,500 120,80043-17-15 Power Cable, 600 V(to equipment)3/C, #4/0 Est 2,310 LF 0.00 11.53 0 26,600 0.52 1,201 1,381 WIRE 85.64 118,300 144,90043-17-15 Power Cable, 600 V(to equipment)3/C, 350KCMILEst 2,100 LF 0.00 17.98 0 37,800 0.69 1,449 1,666 WIRE 85.64 142,700 180,50043-17-15 Power Cable, 600 V(to equipment)3/C, 500KCMILEst 6,300 LF 0.00 26.41 0 166,400 0.69 4,347 4,999 WIRE 85.64 428,100 594,50043-17-15 Power Cable, 600V4/C, #10 SHLD Est 2,100 LF 0.00 1.20 0 2,500 0.07 147 169 WIRE 85.64 14,500 17,00043-17-15 Power Cable, 600 V 4/C, #6 SHLD Est 1,260 LF 0.00 2.70 0 3,400 0.10 126 145 WIRE 85.64 12,400 15,80043-17-15 Power Cable, 600 V 3/C, 350KCMIL, SHLDEst 1,260 LF 0.00 17.98 0 22,700 0.69 869 1,000 WIRE 85.64 85,600 108,30043-17-15 Control Cable, 600V2/C, #10 Est 12,600 LF 0.00 0.70 0 8,800 0.03 378 435 WIRE 85.64 37,200 46,00043-17-15 Control Cable, 600V7/C, #10 Est 5,250 LF 0.00 1.60 0 8,400 0.12 630 725 WIRE 85.64 62,000 70,40043-17-15 Control Cable, 600V2/C, #14 Est 29,400 LF 0.00 0.37 0 10,900 0.03 882 1,014 WIRE 85.64 86,900 97,80043-17-15 Control Cable, 600V3/C, #14 Est 10,500 LF 0.00 0.42 0 4,400 0.03 315 362 WIRE 85.64 31,000 35,40043-17-15 Control Cable, 600V5/C, #14 Est 9,450 LF 0.00 0.68 0 6,400 0.03 284 326 WIRE 85.64 27,900 34,30043-17-15 Control Cable, 600V7/C, #14 Est 2,100 LF 0.00 0.95 0 2,000 0.04 84 97 WIRE 85.64 8,300 10,30043-17-35 Power & Control Cable TerminationsPower: 510, Control: 1000Est 3,171 EA 0.00 1.00 0 3,200 0.30 951 1,094 WIRE 85.64 93,700 96,90043-13-13 Instrumentation Cable, 300V1pr, #16 TW SHLD Est 10,500 LF 0.00 0.18 0 1,900 0.03 315 362 WIRE 85.64 31,000 32,90043-13-13 Instrumentation Cable, 300V1 tr, #16 TW SHLD Est 2,100 LF 0.00 0.29 0 600 0.03 63 72 WIRE 85.64 6,200 6,80043-13-13 Instrumentation Cable, 300V2pr, #16 TW SHLD Est 21,000 LF 0.00 0.32 0 6,700 0.03 630 725 WIRE 85.64 62,000 68,70043-13-13 Instrumentation Cable, 300V2 tr, #16 TW SHLD Est 4,200 LF 0.00 0.43 0 1,800 0.03 126 145 WIRE 85.64 12,400 14,20043-13-13 Instrumentation Cable, 300V8pr, #16 TW SHLD Est 4,200 LF 0.00 0.86 0 3,600 0.10 420 483 WIRE 85.64 41,400 45,00043-13-13 Instrumentation Cable, 300V2pr, #16 SHLD typeEEst 12,600 LF 0.00 0.35 0 4,400 0.03 403 464 WIRE 85.64 39,700 44,10043-13-33 Fiber Optic Cable 2 strand Est 2,100 LF 0.00 0.50 0 1,100 0.03 63 72 WIRE 85.64 6,200 7,30043-13-33 Fiber Optic Cable 6 strand Est 5,250 LF 0.00 0.96 0 5,000 0.03 158 181 WIRE 85.64 15,500 20,50043-13-33 Fiber Optic Cable 12 strand Est 1,260 LF 0.00 1.46 0 1,800 0.03 38 43 WIRE 85.64 3,700 5,500Page 10 of 14OG & EEstimate No.: 30352 AMuskogee Units 4 & 5Project No.: 11418-019Dry FGD SystemsDate: 12/23/2009Conceptual Cost EstimatePrepared by: MNOCost Type:Reviewed by: RKEst=EstimatedApproved by: PEFAllow.=AllowanceWage Rates Based on: 9NUR06C= ContractLabor Productivity = 1.15Q=Vendor QuoteCode ofAccountsItem DescriptionScope DefinitionCost TypeQuantityUnit ofMeasureUnit Equip.CostUnit MaterialCostTotal EquipmentCostTotal Material CostUnit Man-hours(Base)Total Man-hours(Base)Total Man-hours, Prod =1.15CrewCodeCrewWageRateTotal Construction& Erection CostTotal ProjectedCost43-13-33 Fiber Optic Cable 24 strand Est 2,730 LF 0.00 2.21 0 6,000 0.05 137 157 WIRE 85.64 13,400 19,40043-13-99 Profibus DP Cable Est 8,400 LF 0.00 1.50 0 12,600 0.05 420 483 WIRE 85.64 41,400 54,00043-13-27 Cat 5EEst 3,150 LF 0.00 1.40 0 4,400 0.05 158 181 WIRE 85.64 15,500 19,90043-13-43 Instrumentation Cable TerminationsEst 6,300 EA 0.00 1.00 0 6,300 0.25 1,575 1,811 WIRE 85.64 155,100 161,40042-17-15 Misc. Junction Boxes & Pull BoxesEst 2 LT 0.00 100,000.00 0 200,000 600.00 1,200 1,380 WIRE 85.64 118,200 318,20042-13-47 Cable Trays36" Trays Est 8,400 LF 0.00 30.00 0 252,000 1.00 8,400 9,660 ECND 64.88 626,700 878,70042-13-47 Cable Trays24" Control, & 24" InstrumentEst 12,600 LF 0.00 25.00 0 315,000 1.00 12,600 14,490 ECND 64.88 940,100 1,255,10042-15-37 Conduits misc sizes Est 52,500 LF 0.00 10.00 0 525,000 0.35 18,375 21,131 ECND 64.88 1,371,000 1,896,00041-31-15 GroundingIncludes ground grid, rods,bolted connections & cadwelds.Future installation onlyEst 2 LT 0.00 50,000.00 0 100,000 800.00 1,600 1,840 WIRE 85.64 157,600 257,60041-17-25 PA / Page PartyExtension SystemEst 2 LT 0.00 20,000.00 0 40,000 300.00 600 690 WIRE 85.64 59,100 99,10041-17-35 Data COM Extension SystemEst 2 LT 0.00 5,000.00 0 10,000 120.00 240 276 WIRE 85.64 23,600 33,60041-17-35 Telephone Extension SystemEst 2 LT 0.00 5,000.00 0 10,000 140.00 280 322 WIRE 85.64 27,600 37,60041-53-17 LightningProtection Est 2 LT 0.00 30,000.00 0 60,000 300.00 600 690 WIRE 85.64 59,100 119,100Electrical Aux Power Structural Work0Foundations for FGD/FF PCC'sQuantities shown are forstacked Unit 1&2 PCC's21-53-13 Piles 16" dia X 60' deep, auger castEst 1,200 LF 0.00 12.65 0 15,200 0.35 420 0 PILE 86.18 0 15,20021-23-15 ExcavationEst 482 CY0.00 0.00 0 0 0.20 96 111 EXFD 63.95 7,100 7,10021-17-25 BackfillEst 32 CY0.00 0.00 0 0 0.30 9 11 EXFD 63.95 700 70022-13-37 ConcreteEst 450 CY0.00 105.00 0 47,300 1.50 675 776 CONP 51.69 40,100 87,40022-25-35 ReinforcingEst 34 TN 0.00 1,150.00 0 38,800 20.00 675 776 REIN 61.48 47,700 86,50022-17-25 FormworkEst 1,800 SF 0.00 2.50 0 4,500 0.14 243 279 FORM 71.62 20,000 24,50022-15-25 Embedded Steel Est 3,600 LB 0.00 2.50 0 9,000 0.05 180 207 CARP 46.37 9,600 18,60022-13-67 Transformer Firewalls2700 SF Est 100 CY0.00 225.00 0 22,500 12.00 1,200 1,380 CONP 74.7 103,100 125,600Transformer FoundationsTotal for UAT and RAT withcontainments0 0021-53-13 Piles 16" dia X 60' deep, auger castEst 2,700 LF 0.00 12.65 0 34,200 0.35 945 0 PILE 86.18 0 34,20021-23-15 ExcavationEst 621 CY0.00 0.00 0 0 0.20 124 143 EXFD 81.96 11,700 11,70021-17-25 BackfillEst 41 CY0 0.30 12 14 EXFD 81.96 1,100 1,10022-13-37 ConcreteEst 580 CY0.00 105.00 0 60,900 1.50 870 1,001 CONP 74.7 74,700 135,60022-25-35 ReinforcingEst 44 TN 0.00 1,150.00 0 50,000 20.00 870 1,001 REIN 79.19 79,200 129,20022-17-25 FormworkEst 2,320 SF 0.00 2.50 0 5,800 0.14 313 360 FORM 90.9 32,700 38,50022-15-25 Embedded SteelEst 2,900 LB 0.00 2.50 0 7,300 0.06 174 200 CARP 64.41 12,900 20,20023-25-75 Structural SteelBasin Gallery Steel forcontainments4.50 TN 0.00 2,650.00 0 11,900 25.00 113 129 STST 105.69 13,700 25,60023-17-23 1 1/4" Grating(Galv)Basin Grating750 SF 0.00 18.00 0 13,500 0.20 150 173 GALL 84.98 14,700 28,200Controls & Instrumentation4,125,000 75,000 16,388 888,500 5,088,50044-13-15 DCS 4500 I/OpointsEst 1 LS 2,925,000.00 0.00 2,925,000 0 6,750 6,750 7,763 INEL 54.22 420,900 3,345,90071-55-45 DCS - Vendor Field Support200 mandays@$1500/dayEst 200 DAYS 1,500.00 0.00 300,000 0 0.00 0 0 INEL 54.22 0 300,00044-24-43 LocallyMounted InstrumentsEst 300 EA 3,000.00 0.00 900,000 0 20 6,000 6,900 INEL 54.22 374,100 1,274,10044-17-15 Instrument Racks included with instruments35-15-13 Instrument TubingAllow 1 LT 0.00 75,000 0 75,000 1,500 1,500 1,725 INEL 54.22 93,500 168,500Modifications / Installation of CEM systemNot required EstCivil Work0 1,482,700 26,717 2,114,700 3,597,40021Laydown AreaApprox 4 Acre21-13-25Cut and stripTopsoil strippingEst38720 CY0.00 0.00 0 0 0.030 1,162 1,336 ETWK 152.54 203,800 203,80021-13-45Topsoil storage stockpile assumes on site stockpilingEst38720 CY0.00 0.00 0 0 0.010 387 445 ETWK 152.54 67,900 67,90021-51-27Geotextile membrane10 oz/syEst19360 SY0.00 1.80 0 34,800 0.010 194 223 LAND 30.15 6,700 41,50021-57-55Aggregate surfacing4" thick over entire areaEst19360 SY0.00 5.65 0 109,400 0.020 387 445 BCSE 82.08 36,500 145,90021-47-25Grass seedingover stockplie areaEst4 ACRE0.00 1,000 0 4,000 60 240 276 LAND 30.15 8,300 12,30021-41-65 Silt FenceTotal for stockplie and laydownareaEst 1,820 LF 0.00 1 0 1,800 0.02 36 42 LAND 30.15 1,300 3,10021-43-25Fencingwith one 3-strand barbed wire unitFabric,posts on 10ft centersEst 1,760 LF 0.00 40 0 70,400 0.28 493 567 LAND 30.15 17,100 87,50021-43-45Gates 50ft wide double swingEst 2 EA 0.00 3,500.00 0 7,000 40 80 92 LAND 30.15 2,800 9,80021Restoration of Laydown AreaEst0 ACRE0.00 15.00 0 0 35 0 0 ETWK 152.54 0 021-21-25Remove and dispose of aggregateEst2,215 CY0.00 0.00 0 0 0.007 16 18 BCSE 82.08 1,500 1,50011-21-99Removal of Geotextile membraneEst19360 SY0.00 0.00 0 0 0.003 58 67 LAND 30.15 2,000 2,00021-23-15Earthwork to restore - CutEst2,462 CY0.00 0.00 0 0 0.030 74 85 EXFD 63.95 5,400 5,40021-23-45Earthwork to restore - Fill Est2,462 CY0.00 0.00 0 0 0.050 123 142 EXFD 63.95 9,100 9,10021-23-45Place topsoil -previouslystockpiledEst70000 CY0.00 0.00 0 0 0.050 3,500 4,025 EXFD 63.95 257,400 257,40021-47-25Grass seeding- mulch and fertilizerEst4 ACRE0.00 1,500 0 6,000 90 360 414 LAND 30.15 12,500 18,50021DFGD AreaApprox 4 Acre21-13-25Cut and stripTopsoil strippingEst43560 CY0.00 0.00 0 0 0.030 1,307 1,503 ETWK 152.54 229,200 229,200Page 11 of 14OG & EEstimate No.: 30352 AMuskogee Units 4 & 5Project No.: 11418-019Dry FGD SystemsDate: 12/23/2009Conceptual Cost EstimatePrepared by: MNOCost Type:Reviewed by: RKEst=EstimatedApproved by: PEFAllow.=AllowanceWage Rates Based on: 9NUR06C= ContractLabor Productivity = 1.15Q=Vendor QuoteCode ofAccountsItem DescriptionScope DefinitionCost TypeQuantityUnit ofMeasureUnit Equip.CostUnit MaterialCostTotal EquipmentCostTotal Material CostUnit Man-hours(Base)Total Man-hours(Base)Total Man-hours, Prod =1.15CrewCodeCrewWageRateTotal Construction& Erection CostTotal ProjectedCost21-13-45Topsoil storage stockpile assumes on site stockpilingEst43560 CY0.00 0.00 0 0 0.010 436 501 ETWK 152.54 76,400 76,40021-51-27Geotextile membrane10 oz/syEst21780 SY0.00 1.80 0 39,200 0.010 218 250 LAND 30.15 7,600 46,80021-57-55Aggregate surfacing4" thick over entire areaEst24200 SY0.00 5.65 0 136,700 0.020 484 557 BCSE 82.08 45,700 182,400Plant Drainage21-25-15ExcavationEst600 CY0.00 0.00 0 0 0.200 120 138 EXFD 63.95 8,800 8,80021-57-55Crushed rock surfacing12" Est 240 CY0.00 54.00 0 13,000 0.14 34 39 BCSE 82.08 3,200 16,200Storm Sewer22-23-654ft ManholesEst 6 EA 0.00 1,575.00 0 9,500 20.00 120 138 YDPP 63.15 8,700 18,20022-23-656ft ManholesEst 5 EA 0.00 3,000.00 0 15,000 30.00 150 173 YDPP 63.15 10,900 25,90022-23-6524"x24" Catch Basin 3 ft deepEst 10 EA 0.00 500.00 0 5,000 6.00 60 69 YDPP 63.15 4,400 9,40035-13-3518" CHDPEEst 750 LF 0.00 30.00 0 22,500 0.30 225 259 YDPP 63.15 16,300 38,80035-13-3524" CHDPEEst 750 LF 0.00 40.00 0 30,000 0.40 300 345 YDPP 63.15 21,800 51,80035-13-3536" CHDPEEst 750 LF 0.00 70.00 0 52,500 0.65 488 561 YDPP 63.15 35,400 87,90021OilyWater Sewer System22-23-654ft ManholesEst 7 EA 0.00 1,575.00 0 11,000 20.00 140 161 YDPP 63.15 10,200 21,20035-13-236" CISPEst 1,650 LF 0.00 28.00 0 46,200 1.05 1,733 1,992 YDPP 63.15 125,800 172,00035-13-236" Post indicator valve Est 6 EA 0.00 450.00 0 2,700 6.00 36 41 YDPP 63.15 2,600 5,30031-93-53Oil Water Separator with Lift Station 3,000gal Est 1 EA 0.00 100,000.00 0 100,000 1130.00 1,130 1,300 YDPP 63.15 82,100 182,10021SanitarySewer22-23-654ft ManholesEst 7 EA 0.00 1,575.00 0 11,000 20.00 140 161 YDPP 63.15 10,200 21,20022-23-65CleanoutsEst 5 EA 0.00 690.00 0 3,500 8.00 40 46 YDPP 63.15 2,900 6,40035-13-236" CISPEst 1,600 LF 0.00 28.00 0 44,800 1.05 1,680 1,932 YDPP 63.15 122,000 166,80021-25-15 Excavationfor all drainage and sewerpipingEst 2,222 CY 0.00 0.00 0 0 0.200 444 511 EXFD 63.95 32,700 32,70021-17-15 Bedding / backfillfor all drainage and sewerpipingEst 556 CY 0.00 40.00 0 22,200 0.300 167 192 EXFD 63.95 12,300 34,500Interior Plant Roads and Surfacing21-13-25Cut and stripTopsoil strippingEst2,889 CY0.00 0.00 0 0 0.030 87 100 ETWK 152.54 15,200 15,20021-13-25CutEst722 CY0.00 0.00 0 0 0.030 22 25 ETWK 152.54 3,800 3,80021-17-55FillEst722 CY0.00 0.00 0 0 0.050 36 42 ETWK 152.54 6,300 6,30021-51-27Geotextile membrane10 oz/syEst8,667 SY0.00 1.80 0 15,600 0.010 87 100 LAND 30.15 3,000 18,60021-57-55Aggregate surfacing6" thick over entire areaEst8,667 SY0.00 8.50 0 73,700 0.020 173 199 BCSE 82.08 16,400 90,10021-57-35Concrete road 9" thick, 24ft W x 2600 L Est1,733 CY0.00 17.52 0 30,400 0.29 503 578 PBIT 64.44 37,300 67,70022-25-35 ReinforcingEst 173 TN 0.00 1,150.00 0 199,300 20.00 3,467 3,987 REIN 79.19 315,700 515,00022-17-25 FormworkEst 5,200 SF 0.00 2.50 0 13,000 0.14 702 807 FORM 90.9 73,400 86,40021-57-55 Contractor Trailer Area SurfacingIncludes:9" aggregate surfacing12" subgradeprepEst 14520 SY 0.00 22.48 0 326,400 0.10 1,452 1,670 BCSE 82.08 137,100 463,50021-51-27Geotextile membrane - entire area10 oz/syEst14520 SY0.00 1.80 0 26,100 0.010 145 167 LAND 30.15 5,000 31,100Removal and Relocation of ExistingEquipment and Infrastructure0 1,086,300 46,703 3,048,500 4,134,800Miscellaneous Pipe Relocation - UndergroundQuantities are total for Units1&235-13-1514" CS, SCH 40, includes fittings Fuel oil and chemical drainsEst 938 LF 0.00 259.50 0 243,400 2.94 2,758 3,171 YDPP 63.15 200,300 443,70035-13-15 12" CS, SCH 40, includes fittingsChemical drains and servicewaterEst 375 LF 0.00 246.30 0 92,400 2.88 1,080 1,242 YDPP 63.15 78,400 170,80035-13-158" CS, SCH 40, includes fittings Oil drains Est 375 LF 0.00 89.50 0 33,600 1.60 600 690 YDPP 63.15 43,600 77,20035-13-156" CS, SCH 40, includes fittings Fuel oil and service waterEst 563 LF 0.00 130.20 0 73,300 1.88 1,058 1,217 YDPP 63.15 76,900 150,20021-25-15 Excavation for Underground PipingEst 834 CY0.00 0.00 0 0 0.20 167 192 EXFD 63.95 12,300 12,30021-17-15 Beddingfor Underground PipingEst 125 CY0.00 40.00 0 5,000 0.30 38 43 EXFD 63.95 2,800 7,80021-17-25 Backfill for Underground PipingEst 709 CY0.00 0.00 0 0 0.30 213 244 EXFD 63.95 15,600 15,600Miscellaneous Pipe Relocation - Above GroundQuantities are total for Units1&2Allow. 1 LT 0.00 200,000 0 200,000 3000.00 3,000 3,450 WIRE 66.93 230,900 430,90035-13-1512" CS, SCH 40, includes fittings Ash water, Unit 1&2 Est 250 LF 0.00 246.30 0 61,600 2.88 720 828 YDPP 63.15 52,300 113,90035-13-1510" CS, SCH 40, includes fittings Ash waterEst 250 LF 0.00 196.80 0 49,200 2.32 580 667 YDPP 63.15 42,100 91,30035-13-158" Ashcolite, flanged Ash sluice line Est 500 LF 0.00 145.20 0 72,600 1.54 770 886 YDPP 63.15 55,900 128,50035-13-154" CS, SCH 40, includes fittings Service waterEst 250 LF 0.00 57.60 0 14,400 1.50 375 431 YDPP 63.15 27,200 41,60035-13-33Pipe Supports for relocatedpipingEst 5.22 TN 0.00 2,650.00 0 13,800 40.00 209 240 STST 87.33 21,000 34,800Miscellaneous Structures Demolition/Relocation Unit 4New Foundations for Relocated ID Fans2 fans total Est0021-53-13 Piles 16" dia X 60' deep, auger castEst 1,500 LF 0.00 12.65 0 19,000 0.35 525 0 PILE 86.18 0 19,00021-23-15 ExcavationEst 250 CY0.00 0.00 0 0.20 50 58 EXFD 63.95 3,700 3,70022-13-37 ConcreteEst 400 CY0.00 105.00 0 42,000 1.50 600 690 CONP 51.69 35,700 77,70022-25-35 ReinforcingEst 30 TN 0.00 1,150.00 0 34,500 20.00 600 690 REIN 61.48 42,400 76,90022-17-25 FormworkEst 3,200 SF 0.00 2.50 0 8,000 0.14 432 497 FORM 71.62 35,600 43,600Page 12 of 14OG & EEstimate No.: 30352 AMuskogee Units 4 & 5Project No.: 11418-019Dry FGD SystemsDate: 12/23/2009Conceptual Cost EstimatePrepared by: MNOCost Type:Reviewed by: RKEst=EstimatedApproved by: PEFAllow.=AllowanceWage Rates Based on: 9NUR06C= ContractLabor Productivity = 1.15Q=Vendor QuoteCode ofAccountsItem DescriptionScope DefinitionCost TypeQuantityUnit ofMeasureUnit Equip.CostUnit MaterialCostTotal EquipmentCostTotal Material CostUnit Man-hours(Base)Total Man-hours(Base)Total Man-hours, Prod =1.15CrewCodeCrewWageRateTotal Construction& Erection CostTotal ProjectedCost22-15-25 Embedded Steel Est 2.00 TN 0.00 5,000.00 0 10,000 120.00 240 276 CARP 46.37 12,800 22,80011628 Relocate ID FansRemove from existing location,install in new location includingall fan auxiliariesEst 2 EA 0 0.00 0 0 3750.00 7,500 8,625 MECH 61.53 530,700 530,70011-26-99 DuctworkEst 120 TN 0.00 0 0 0 15.00 1,800 2,070 WRKG 91.68 189,800 189,80011-23-99 SteelEst 25 TN 0.00 0 0 0 12.00 300 345 WRKG 91.68 31,600 31,600Miscellaneous Structures Demolition/Relocation Unit 5New Foundations for Relocated ID Fans2 fans total Est 2 EA 0 0.00 0 0 3000.00 6,000 6,900 MECH 61.53 424,600 424,60021-53-13 Piles 16" dia X 60' deep, auger castEst 1,500 LF 0.00 12.65 0 19,000 0.35 525 0 PILE 86.18 0 19,00021-23-15 ExcavationEst 250 CY0.00 0.00 0 0.20 50 58 EXFD 63.95 3,700 3,70022-13-37 ConcreteEst 400 CY0.00 105.00 0 42,000 1.50 600 690 CONP 51.69 35,700 77,70022-25-35 ReinforcingEst 30 TN 0.00 1,150.00 0 34,500 20.00 600 690 REIN 61.48 42,400 76,90022-17-25 FormworkEst 3,200 SF 0.00 2.50 0 8,000 0.14 432 497 FORM 71.62 35,600 43,60022-15-25 Embedded Steel Est 2.00 TN 0.00 5,000.00 0 10,000 120.00 240 276 CARP 46.37 12,800 22,80011628 Relocate ID FansRemove from existing location,install in new location includingall fan auxiliariesEst 2 EA 0 0.00 0 0 3750.00 7,500 8,625 MECH 61.53 530,700 530,70011-26-99 DuctworkEst 120 TN 0.00 0 0 0 15.00 1,800 2,070 WRKG 91.68 189,800 189,80011-23-99 SteelEst 25 TN 0.00 0 0 0 12.00 300 345 WRKG 91.68 31,600 31,600:Sub-Total of Equipment Material andLabor Costs111,103,300 42,737,000 1,705,929 114,372,100 268,212,400Other Costs63,987,80081-13-45Additional Crane Rental Allowance4.00 %0 4,574,884 4,574,88461-27-25 Mobilization/Demobilization Est 2.00 %2,287,442 2,287,40061-23-35 ScaffoldingEst 2.50 %1,068,425 2,859,303 3,927,70061-17-43Temporary Facilities and Construction Utilities (Elect,Water, etc.) During Construction1.00 %0 1,143,721 1,143,700Allowance for Premium Time Labor Five (5) days perweek Ten (10) hours per day.Est 1 LS061-21-45Cost due to overtime inefficiencyworking5x10's8.00 %148,342 67 9,945,000 9,945,00061-21-65Per Diem Expense@$10/HR10 hr18,542,712 18,542,70091-13-15 BOP Contractor's General & Administrative CostsBased on BOP Materials &Labor Costs at 5% (not incl.Equipment Costs )Est 5.00 %2,136,850 5,718,605 7,855,50091-15-25 BOP Contractor's ProfitBased on BOP Materials &Labor Costs at 10% (not incl.Equipment Costs )Est 10.00 %4,273,700 11,437,210 15,710,910Total Equipment, Material and LaborCosts111,103,300 50,216,000 1,854,300 170,881,000 332,200,200Spare Parts, Special Tools andConsumables807,00081-27-75 Mandatory Spare Parts (first year of operation) 0.00 % 00 081-25-35 Special ToolsIncludedw\Equipment Costs81-25-25Consumables(0.5% of Equipment/Material Cost)0.5 % 556,000 251,000807,000Freight, Duties, Taxes, Etc.2,136,900Page 13 of 14OG & EEstimate No.: 30352 AMuskogee Units 4 & 5Project No.: 11418-019Dry FGD SystemsDate: 12/23/2009Conceptual Cost EstimatePrepared by: MNOCost Type:Reviewed by: RKEst=EstimatedApproved by: PEFAllow.=AllowanceWage Rates Based on: 9NUR06C= ContractLabor Productivity = 1.15Q=Vendor QuoteCode ofAccountsItem DescriptionScope DefinitionCost TypeQuantityUnit ofMeasureUnit Equip.CostUnit MaterialCostTotal EquipmentCostTotal Material CostUnit Man-hours(Base)Total Man-hours(Base)Total Man-hours, Prod =1.15CrewCodeCrewWageRateTotal Construction& Erection CostTotal ProjectedCost71-27-35 Freight-ExWorks To SiteFor material costs only. Freightfor Equipment included withequipment costs.5 %2,136,8502,136,90071-47-45Taxes - Sales/Use/VAT/Business/Etc. Not Included0Total Direct Costs111,659,300 52,603,900 170,881,000 335,144,100Total Indirect Costs0 049,601,90071-13-15Engineering/ Procurement6.50 %21,784,400 21,784,40071-23-15Construction Management2.00 %6,702,900 6,702,90071-45-57Start-up& CommissioningCraft Support2.00 %3,417,600 3,417,60071-53-15Operator Training& Manuals0.55 %939,800 939,80071-21-15Owner's Cost5.00 %16,757,205 16,757,205Total Project Cost without Escalation /Contingency384,746,00095-95-95Escalation63,277,100Equipment16,190,60016,190,600Material8,942,7008,942,700Labor31,100,300 31,100,300Indirects7,043,500 7,043,50093-93-93Contingency14.085 %63,104,100Total Project Cost with Escalation /Contingency511,127,20097-97-97Bond Cost1.00 %5,111,30097-97-97Interest DuringConstruction(AFUDC)8.66 %118,148,300Total Project Cost634,386,800Page 14 of 14

# S OONER 

# U NITS 

# 1&2

M USKOGEE 

# U NITS 

# 4 & 5



# D RY 

# FGD

D ESIGN AND 

# C OST 

# E STIMATE 

# B ASIS 

# D OCUMENT

D ECEMBER 

# 28, 2009

P ROJECT 

# 11418-019



# P REPARED BY

# Sooner 1 & 2 & Muskogee 4 & 5 12/28/09

D ESIGN 

# B ASIS 

# D OCUMENT 

# Project 11418-019



# C ONTENTS



# S ECTION 

# P AGE



# i

Design Basis for Dry FGD 

# 1. S OONER 

# P LANT 

# L OCATION AND 

# T RANSPORTATION 

# A CCESS 

# ........................................................1

1.1 W EATHER 

# C ONDITIONS 

# ..................................................................................................................1

2. F UEL 

# C HARACTERISTICS 

# .................................................................................................................2

2.1 M AIN 

# F UEL



# ............................................................................................................................... ......2

3. W ATER 

# S UPPLY



# ............................................................................................................................... ..4

3.1 S OONER 

# S TATION 

# R AW 

# W ATER 

# S UPPLY 

# ........................................................................................4

3.2 M USKOGEE 

# S TATION 

# R AW 

# W ATER 

# S UPPLY 

# ...................................................................................4

4. A IR 

# Q UALITY 

# C ONTROL 

# S YSTEMS 

# (AQCS)....................................................................................4

4.1 SO 2 

# E MISSIONS 

# C ONTROL 

# ..............................................................................................................4

4.2 P ARTICULATE 

# E MISSIONS 

# C ONTROL 

# ..............................................................................................5

5. B OOSTER 

# F ANS



# ............................................................................................................................... ...5

6. C HIMNEY



# ............................................................................................................................... ............5

7. M ATERIAL 

# H ANDLING 

# S YSTEM 

# .......................................................................................................6

7.1 F LY 

# A SH 

# H ANDLING 

# S YSTEM 

# .........................................................................................................6

7.2 L IME 

# H ANDLING 

# S YSTEM 

# ...............................................................................................................6

8. C OST 

# E STIMATING 

# B ASIS 

# .................................................................................................................6

8.1 S OONER 

# E STIMATE 

# S COPE 

# ..............................................................................................................6

8.2 M USKOGEE 

# E STIMATE 

# S COPE 

# ........................................................................................................6

8.3 C OMMERCIAL 

# B ASIS 

# .......................................................................................................................7

8.4 T ECHNICAL 

# B ASIS 

# ..........................................................................................................................8

# Sooner 1 & 2 & Muskogee 4 & 5 12/28/09

D ESIGN 

# B ASIS 

# D OCUMENT 

# Project 11418-019



# C ONTENTS



# S ECTION 

# P AGE



# ii

Design Basis for Dry FGD 

# Tables

Table 1.1-1 Major Site Conditions – Sooner Station ............................................................................. .......1

Table 1.1-2 Major Site Conditions – Muskogee Station.......................................................................... ....2

Table 2.1-1: Sooner & Mus kogee – Coal Properties .............................................................................. .....3

Attachments

Attachment 1 – Mass Balance Diagrams fo r Sooner Station and Muskogee Station

Attachment 2 – Sooner Station General Arrangement Drawing

Attachment 3 – Sooner Station Power Requirement Tables

Attachment 4 – Sooner Station Units 1 and 2 Material Handling Diagrams

Attachment 5 – Summary of Vendor Quotations

Attachment 6 – Project Schedule

# Sooner 1 & 2 & Muskogee 4 & 5 12/28/09

D ESIGN 

# B ASIS DOCUMENT 

# Project 11418-019



# 1

Design Basis for Dry FGD 

# 1. S OONER 

# P LANT 

# L OCATION AND 

# T RANSPORTATION 

# A CCESS



# Sooner Station consists of two 575 MW pulverized coal fired units located east of Red Rock,

Oklahoma. Sooner Station is located on 11, 000 acres of land that straddles Noble and

Pawnee Counties. The power block for Sooner 1 & 2 is located in Noble County.

The site is served by the Burlington Northern Santa Fe Railroad. The site is also accessible

via truck from US Highway 177.

A major feature of the site is the 150,000 acre -foot reservoir that provides cooling water for

Sooner 1 & 2.

The northern portion of the site contains the co al storage area. The rail loop encircles the

coal handling area. Coal pile runoff flows to the Coal Pile Runoff Pond which, in turn, flows

to the Waste System Evaporation Pond.

Sooner 1 & 2 began commercial operation in 1979 and 1980 respectively. Sooner 1 & 2 are

currently base load units and use No. 2 fuel oil as a start-up fuel and sub-bituminous low

sulfur coal as the primary fuel. Each boiler was manufactured by Combustion Engineering

with a design output of 550 megawatts (MW). Particulate emissions are controlled by cold

side electrostatic dust precipitators with a desi gn removal efficiency of 99.52%. Both units

have 500-foot tall chimneys.

1.1 W EATHER 

# C ONDITIONS



# 1.1.1 Sooner Plant Weather Conditions

Table 1.1-1 lists the major site conditions at Sooner Station, which are based on American

Society of Heating, Refrigeration and Ai r Conditioning Engineers (ASHRAE) data.

Table 1.1-1

Major Site Conditions – Sooner Station

Parameter Data

Nearest weather data location (2009 ASHRAE

Handbook – Fundamentals (IP)) Stillwater, OK Regional Airport

Latitude/longitude 36.15N/97.08W

Elevation 933 feet

Standard pressure 14.07 psia

Heating dry bulb temper ature, 99.6% occurrence 13.6 ° F

# Sooner 1 & 2 & Muskogee 4 & 5 12/28/09

D ESIGN 

# B ASIS DOCUMENT 

# Project 11418-019



# 2

Design Basis for Dry FGD 

# Parameter Data

Cooling dry bulb temperature, 0.4% occurrence 101.8 ° F

Extreme wind speed, 1% occurrence 24.6 mph

50-year occurrence dry bulb temperatures:

Maximum 112.3 ° F

Minimum -10.3 ° F



# 1.1.2 Muskogee Plant Weather Conditions

Table 1.1-2 lists the major site conditions at Muskogee Station which are based on American

Society of Heating, Refrigeration and Ai r Conditioning Engineers (ASHRAE) data.

Table 1.1-2

Major Site Conditions – Muskogee Station

Parameter Data

Nearest weather data location (2009 ASHRAE

Handbook – Fundamentals (IP)) Tulsa, OK Lloyd Jones Regional

Airport

Latitude/longitude 35.40N/97.58W

Elevation 520 feet

Standard pressure 14.42 psia

Heating dry bulb temper ature, 99.6% occurrence 15.8 ° F

Cooling dry bulb temperature, 0.4% occurrence 100.1 ° F

Extreme wind speed, 1% occurrence 19.8 mph

50-year occurrence dry bulb temperatures:

Maximum 112.3 ° F

Minimum -10.3 ° F



# 2. F UEL 

# C HARACTERISTICS



# 2.1 M AIN 

# F UEL



# Each facility typically fires Powder River Basi n (PRB) coal delivered to each site by rail.

# Sooner 1 & 2 & Muskogee 4 & 5 12/28/09

D ESIGN 

# B ASIS DOCUMENT 

# Project 11418-019



# 3

Design Basis for Dry FGD 

# The design basis fuel analysis, presented in Ta ble 2.1-1 was developed based on the PRB coal

fired at the stations and potential future PRB coal sources. The worst case coal was used to

size the FGD equipment while the average coal was used to develop yearly O&M costs.

Table 2.1-1: Sooner & Muskogee – Coal Properties

FUEL ANALYSIS: Powder River Basin

Worst Case PRB

(FGD Sizing) Powder River Basin

Average PRB (Used

for O&M Costs)

Ultimate Analysis

Carbon % 48.52 51.29

Sulfur % 0.48 0.22

Oxygen % 11.80 12.22

Hydrogen % 3.10 3.34

Nitrogen % 0.77 0.67

Chlorine % 0.01 0.01

Ash % 7.50 5.30

Moisture % 27.82 26.95

100.00 100.00

Proximate Analysis

Moisture % 27.8 26.95

Volatile matter % 32.21 31.73

Fixed Carbon % 32.47 36.04

Ash % 7.50 5.30

Gross (Higher) Heating

Value Btu/lb 8,000 8,400

Gross Heating Value

(Dulong) Btu/lb 8,084 8,593

Hardgrove Grindability HGI 59 59

Chlorine ppmvd (wt) 125 100

Fluorine ppmvd (wt) 75 60

Mercury ppmvd (wt) 0.10 0.08

Ash Analysis

Silica % 32.00 36.64

Ferric Oxide % 5.00 5.57

Alumina % 16.00 16.06

Titanic Oxide % 1.30 1.37

Calcium Oxide % 22.50 22.04

Magnesia % 4.80 4.89

# Sooner 1 & 2 & Muskogee 4 & 5 12/28/09

D ESIGN 

# B ASIS DOCUMENT 

# Project 11418-019



# 4

Design Basis for Dry FGD 

# FUEL ANALYSIS: Powder River Basin

Worst Case PRB

(FGD Sizing) Powder River Basin

Average PRB (Used

for O&M Costs)

Sulfur Trioxide % 14.70 8.40

Potassium Oxide % 0.40 0.46

Sodium Oxide % 1.10 1.64

Phosphorous Pentoxide % 1.10 0.84

Barium Oxide % 0.00 0.52

Undetermined % 1.13 1.57

Total % 100.0 100.0



# 3. W ATER 

# S UPPLY



# Each station will supply water for the dry FGD system from its existing cooling water supply.

Because dry FGD systems do not produce wastewat er, additional wastewater treatment is not

required at either site.

3.1 S OONER 

# S TATION 

# R AW 

# W ATER 

# S UPPLY



# Sooner Station utilizes a cooling water reservoir to supply water to its once-through cooling

system. The dry FGD will draw raw water from this same reservoir to use in its process.

New raw water pumps will be installed near the existing circulating water pumps to supply

make-up water to the dry FGD system.

3.2 M USKOGEE 

# S TATION 

# R AW 

# W ATER 

# S UPPLY



# It has been assumed that the existing city water line will supply make-up water for the dry

FGD system.



# 4. A IR 

# Q UALITY 

# C ONTROL 

# S YSTEMS 

# (AQCS)

4.1 SO 2 

# E MISSIONS 

# C ONTROL



# Emissions of SO 2 

# will be controlled using DFGD systems at both stations. Pebble lime slurry

and recycle ash slurry will be used as the reag ents. The maximum lime usage will be based

on pebble lime with at least 90 percent as CaO availability determined using ASTM C25 and

at least 40° C temperature rise in 3 minutes reactivity determined using ASTM C110.

# Sooner 1 & 2 & Muskogee 4 & 5 12/28/09

D ESIGN 

# B ASIS DOCUMENT 

# Project 11418-019



# 5

Design Basis for Dry FGD 

# 4.2 P ARTICULATE 

# E MISSIONS 

# C ONTROL



# Each of Sooner Units 1 and 2 and Muskogee Units 4 and 5 have existing electrostatic

precipitators (ESPs) to control particulate em issions. These ESPs will remain in service after

the DFGD systems are installed to allow both plan ts to continue to sell their ESP fly ash.

Emissions of DFGD waste will be controlled using a new multi-compartment pulse jet fabric

filter (PJFF), commonly called a baghouse. Waste collected in the PJFF hoppers will be

pneumatically transported to the recycle ash storage silo for use as a reagent in the DFGD

system. Excess waste will be pneumatically transported to a DFGD waste ash silo for

disposal off-site. ESP fly ash will be blende d into the DFGD waste to stabilize it. The

blending ratio will be a maximum of 10% ESP fly ash.

For the following reasons a new baghouse is proposed instead of trying to use the existing

ESP for particulate control:

• SO 2 

# Emissions Control

Utilizing a baghouse downstream of a dry F GD will provide a higher sulfur removal

rate than utilizing an ESP. A DFGD/ESP combination would be expected to remove

only about 70% of the sulfur while a DFGD/baghouse combination is capable of

removal rates in the 90% range. In addition, using a baghouse will also lower emissions

of HCl and HF compared to an ESP. Grand River Dam Authority Unit 2 is an example

of a plant that utilizes an ESP with a Dry F GD and has an approximate sulfur removal

rate of 70%.

• Particulate Emissions

If a dry FGD were added upstream of an existing ESP, the amount of dust loading in the

ESP would be increased and the character of the dust loading would change. This

would raise concerns of whether the plant c ould continue to meet particulate emissions

limits without major ESP modifications.

• Outage Duration

A new baghouse with interconnecting ductwork c ould be completely installed prior to a

tie-in outage whereas any ESP and ESP inlet a nd outlet duct modifications would have

to take place during an outage. This woul d increase the required tie-in outage duration

and increase power replacement costs for the project.



# 5. B OOSTER 

# F ANS



# Two 50% capacity axial booster fans will be provided on each unit.



# 6. C HIMNEY



# The existing chimneys will be reused. The hei ght of the chimney is 500 feet above grade.

The top 50’ on the interior of each steel chimne y and exterior of the c oncrete shell will have

an acid resistant coating applied to miti gate the effects of acid condensation.

# Sooner 1 & 2 & Muskogee 4 & 5 12/28/09

D ESIGN 

# B ASIS DOCUMENT 

# Project 11418-019



# 6

Design Basis for Dry FGD 

# 7. M ATERIAL 

# H ANDLING 

# S YSTEM



# 7.1 F LY 

# A SH 

# H ANDLING 

# S YSTEM



# DFGD waste collected in the PJFF hoppers will be pneumatically transported to the recycle

storage silo for use as a reag ent in the DFGD system. Excess waste will be pneumatically

transported to the DFGD waste silos for disposal off site.

Filter separators will be provided on the recycle ash storage silo and the DFGD waste ash silo

for control of fugitive fly ash emissions.

7.2 L IME 

# H ANDLING 

# S YSTEM



# Lime will be delivered to each site via truck. The lime would be pneumatically transferred to

a 14-day lime storage silo. From the 14-day storage silo, lime would be pneumatically

conveyed to a 24-hour lime day bin located at the DFGD system reactant preparation building

for each unit. One day bin will be located at each unit.

Fugitive emissions will be controlled using bin ve nt filters located on the 14-day lime storage

silo and the 24-hour lime day bins.



# 8. C OST 

# E STIMATING 

# B ASIS



# Two separate cost estimates will be developed for this study. One estimate will be developed

for Sooner Units 1 and 2, and the other for Muskogee Units 4 and 5.

8.1 S OONER 

# E STIMATE 

# S COPE



# The Sooner Station cost estimate will be based on the following scope:

• Unit 1 Spray Dryer Absorber Area

• Unit 2 Spray Dryer Absorber Area

• Units 1 and 2 Common Areas (lime unloading and waste handling)

• Auxiliary Power System

• Booster ID Fans

• Baghouses

8.2 M USKOGEE 

# E STIMATE 

# S COPE



# The Muskogee Station cost estimate will be based on the following scope:

• Unit 4 Spray Dryer Absorber Area

• Unit 5 Spray Dryer Absorber Area

• Units 4 and 5 Common Areas (lime unloading and waste handling)

• Auxiliary Power System

# Sooner 1 & 2 & Muskogee 4 & 5 12/28/09

D ESIGN 

# B ASIS DOCUMENT 

# Project 11418-019



# 7

Design Basis for Dry FGD 

# • Booster ID Fans

• Baghouses

8.3 C OMMERCIAL 

# B ASIS



# 8.3.1 Equipment and Material Cost

Equipment and material costs will be based on vendor budgetary quotes, estimated quantities,

and the S&L in-house database.

8.3.2 Labor Wage Rates

Labor wage rates will be based on an open shop Oklahoma labor force.

8.3.3 Labor Crews

The construction and erection labor cost is based on the use of applicable construction crews

typically required for projects of this type.

8.3.4 Productivity

No allowances have been made to cover ite ms such as the loss in productivity because of

inability to attract labor, weather conditions, etc.

8.3.5 Quantity Sources

All quantity data was developed internally by S&L Lead Engineers.

8.3.6 Project Schedule

The project schedule is attached.

8.3.7 Indirect Expenses

The engineering costs included herein are est imated and are not to be interpreted as a

proposal by S&L to perform engineering servi ces. The indirect expenses also include

Owner’s Construction Management, General Owner’s Costs, and Owner’s Bond Fees.

8.3.8 Escalation Rates

a. Equipment escalation is assumed to be 2.5% for 2010 and 4.0% for 2011 through

2014. Based on project schedule, it is assumed that for Sooner 30% of the

equipment will be purchased in 2012 w ith the balance purchased in 2013. No

major equipment procurement is anticipated past 2013. For Muskogee, it is

assumed that 30% of the equipment will be purchased in 2012 with the balance

purchased in 2014.

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Design Basis for Dry FGD 

# b. Material escalation is 0.0% for 2010, 3.0% for 2011, and 5.0% for 2012 and

beyond. Based on project schedule, it is assumed for Sooner that 10% of the

material will be purchased in 2012, 50% in 2013, and 40% in 2014. For

Muskogee it is assumed that 10% of the ma terial will be purchased in 2013, 50%

in 2014, and 40% in 2015.

c. Labor escalation is 3.0% for 2010 and 4.0% for 2011-2014. Based on project

schedule, it is assumed that for Sooner 10 % of the labor cost will be spent in

2012, 50% in 2013, and 40% in 2014. For Muskogee, it is assumed that 10% of

the labor cost will be spent in 20 13, 50% in 2014, and 40% in 2015.

d. Escalation for indirects is 3.0% for 2010 and 4.0% for 2011-2015. Based on

project schedule, it is assumed that for Sooner 20% of indirects will be spent in

2011, 40% in 2012, 30% in 2014, and 10% in 2015. For Muskogee, it is

assumed that 5% of the indirects will be spent in 2011, 15% in 2012, 40% in

2013, 30% in 2014, and 10% in 2015.

8.3.9 Sales/Use Taxes

It has been assumed the project will be struct ured to avoid sales tax. Therefore, Sales/Use

Taxes are estimated at 0% of equipment and material.

8.3.10 Contingency

For Sooner, contingency is estimated at 14.04% of total direct and indirect costs based on a

95% confidence level. For Muskogee, contingenc y is estimated at 14.09% of total direct and

indirect costs based on a 95% confidence level

8.3.11 AFUDC Rate

AFUDC is calculated as 8.66% from 2010 based on information received from OG&E.

8.3.12 Bond Fees

Bond fees are estimated at 1% based on typical bond fees and the level of project equity.

8.3.13 General Owner’s Cost

General Owner’s Cost is estimated at 5% of Total Direct Cost.

8.4 T ECHNICAL 

# B ASIS



# The following is a summary of the technical b asis of the spray dryer absorber FGD system

capital cost estimate.

8.4.1 Common Lime Handling Systems

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# B ASIS DOCUMENT 

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# 9

Design Basis for Dry FGD 

# A common lime handling system will be installed at each station. The lime handling systems

will be capable of unloading and conv eying lime to day bins at each unit.

a. Lime truck unloader

i. Lime will be brought on site in trucks.

ii. The system will be vacuum pneumatic to unload the truck.

iii. The blowers will be housed in the skirt of the lime storage silo.

iv. A ventilation system and dust collector will provide dust control.

b. Lime storage silo

i. One common lime storage silo will be provided to house 14-days of lime usage

while burning the design coal.

ii. The storage silo will be made of concrete.

iii. The total storage will be 3000 tons.

iv. The Lime silo will be 36-feet in diameter and 95-feet tall.

v. Bin vent filters will be provided on the concrete silo for dust control.

vi. The silo will have a two-hopper outlet.

c. Lime transfer systems

i. Two runs of pneumatic, pressurized pipe from the lime silo to the lime prep day

bins

ii. Piping will be located on an above grade pipe rack

8.4.2 Lime Preparation and Recycle Area per Unit

Each unit will have the following equipment in the quantities listed below. Both the lime

preparation and recycle area for each unit will be located in the same building. Therefore,

each unit will have a lime preparation and recycle of the dimensions 55 ft x 100 ft x 125 ft in

height.

a. Lime preparation

i. Two 100% ball mill lime slakers each with a grit screen and gravimetric

feeder.

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Design Basis for Dry FGD 

# ii. Two lime transfer tanks.

iii. Two lime slurry storage tanks.

iv. Two slurry feed centrifugal pumps.

v. Two slurry transfer centrifugal pumps

vi. One lime day bin

vii. The equipment, tanks, and day bin will be enclosed by a preparation building

of the dimension: 100 ft x 55 ft x 125 ft

b. Each unit will be equipped with a recycle area to recycle lime byproduct through the

absorber process.

i. One (1) recycle storage silo

ii. Two (2) recycle mix tanks

iii. Two (2) recycle slurry tanks each with two (2) recycle slurry centrifugal

pumps per tank

iv. Agitators for each tank

8.4.3 Absorber Area per Unit

Each unit will be equipped with the absorber equipment detailed below.

a. Two (2) absorber vessels per unit, with access doors

b. Rotary atomizers or dual fluid nozzles, spare atomizers will be included

c. The vessel material will be carbon steel of a thickness between 1/4 in. and 5/8 in.

d. A penthouse enclosure for the absorbers.

e. Each absorber will be provided with 6-inches of insulation and lagging.

f. Heating and ventilation equipment will be provided for each absorber structure.

g. Vacuum piping

h. Vendor quotes have confirmed that tw o SDA’s will be utilized per unit.

8.4.4 Baghouse FGD Waste Handling System Common to Both Units

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Design Basis for Dry FGD 

# A baghouse will be installed on each unit after the SDA’s to capture FGD waste. The

baghouses will be sized to handle the FGD waste produced by each unit. Each station will

have an FGD waste handling system to convey FGD waste from the baghouses to storage

locations. The waste handling systems will be sized to handle the FGD waste produced by

each unit.

a. New pipe and blowers will be required to convey waste from the new baghouses. A

new ash handling blower building of the dime nsions 25 ft x 50 ft x 25 ft high will be

provided, per unit.

b. Addition of one new 3-day storage DFGD waste silo for truck unloading.

i. The DFGD waste silo will be concrete , 30’ in diameter by 68’ tall.

ii. The silo capacity will be 1,500-tons.

c. A new ESP fly ash silo will be added near the DFGD waste silo for fly ash blending

to stabilize the FGD waste.

i. The fly ash silo will be concrete , 20’ in diameter by 46’ tall.

ii. The fly ash silo capacity will be 450-tons.

iii. A pin mixer for fly ash conditioning

8.4.5 Flues Including Support Steel per Unit

Each unit will require additional ductwork to bri ng the flue gas from the existing ID fans to

the absorbers, absorbers to the baghouses, baghouses to th e new booster fans, and new

booster fans to the existing chimney.

a. ID Fan Outlet to Absorber Inlet

i. Carbon steel 1⁄4 in.

ii. Velocity 4000 fpm

iii. 6” insulation with lagging

b. Absorber Outlet to Baghouse Inlet

i. Carbon steel, 1⁄4 in.

ii. Velocity 4000 fpm

iii. 6” insulation with lagging

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Design Basis for Dry FGD 

# c. Baghouse Outlet to Axial Booster Fan

i. Carbon steel, 1⁄4 in.

ii. Velocity 4000 fpm

iii. 4” insulation with lagging

d. Booster Fan Outlet to Chimney

i. Carbon steel, 1⁄4 in.

ii. Velocity 4000 fpm

iii. 4” insulation with lagging

8.4.6 Control System Modifications

The control system modification estimates are based on the estimated number of I/O points

added to each unit and to the common system for each Station. In total, the entire dry FGD

system will require approximately 4,500 new I/O points at each Station, broken down as

follow

.

a. Each individual unit will require approximately 1,250 I/O points. This includes the

SDA’s and reagent prep areas.

b. The common area at each station will re quire approximately 2,000 I/O points.

8.4.7 Subsurface and Foundation Work, Both Stations

Based on the Sooner soil reports, deep foundati ons (piles and caissons) are not required and

are not included in the cost estimate.

Based on the Muskogee soil reports, deep founda tions (piles and caissons) are required and

have been included in the Muskogee cost estimate.

The existing storm drainage system in the DF GD area at both sites will have to be removed

and replaced to make room for the new foundations associated with the DFGD system.

8.4.8 Civil Work, Both Stations

The civil work required will be typical to bot h stations. New roads will be paved for lime

trucks and maintenance access. All other areas will be finished with white rock surfacing.

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Design Basis for Dry FGD 

# 8.4.9 Construction Work, Both Stations

Construction labor will be drawn from the same workforce for work on both stations. The

workforce is detailed below.

a. Labor will be open shop labor based out of Oklahoma.

b. The workforce wages will include premiums and per diems.

c. Labor is based on a 5x10 work week

d. No incentives to attract labor are included

8.4.10 Pipe Racks

Pipe racks will be installed common to both units at each station as detailed below.

a. A pipe rack for lime transport piping will be installed between the lime unloading

area and the lime storage silos.

b. A pipe rack for lime slurry piping from the lime slakers to the SDA’s

c. A pipe rack for lime transport piping will be installed between the lime silo and

reagent prep area.

d. A pipe rack for FGD waste transport will be installed between the baghouse and new

fly ash silos.

e. A pipe rack for recycle transfer from the baghouses to the recycle prep area.

f. A pipe rack for recycle slurry to the SDA’s

g. One pipe rack per unit for cabling from the Auxiliary Transformers to the reagent

areas.

8.4.11 Chimney Modifications

Each unit will re-use its existing chimney. Th e interior top 50 feet of each steel chimney

liner will have an acid resistant coating applied to mitigate the effects of acid condensation.

8.4.12 Baghouse Sizing

A new baghouse will be installed at each unit. The baghouses will be used to remove DFGD

waste from the flue gas stream.

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Design Basis for Dry FGD 

# 8.4.13 Demolition and Relocation

a. Sooner Station

i. The existing storm drainage system in the DFGD area will be removed and

replaced.

ii. Ash piping in the vicinity of the existing ID fans will be relocated and resupported to make room for the new ductwork.

b. Muskogee Station

i. A prefabricated maintenance and material storage warehouse will require

relocation at Muskogee Station.

8.4.14 CEMS

Each Unit’s existing CEMS will be reused. No modifications are required.

8.4.15 Water Treatment at Each Station

Water containing a sulfate content of less than 200 mg/L is considered good, and less than

500 mg/L is considered acceptable. Sooner Station will obtain its water from the Sooner

Reservoir, which has a sulfate content below 200 mg/L and Muskogee Station will draw its

water from city water which also has a sulfat e content below 200 mg/L. Therefore, water

treatment, aside from strainers, will not be required at either station.

8.4.16 Instrument Air Compressors and Dryers, per Station

Each Station will require new instrument air compressors and dryers to expand the existing

instrument air systems. The required sizing is discussed below.

a. 2 x 100% air compressors sized for 250 scfm each at 100 psig.

b. 2 x 100% instrument air dryers with filters, sized for 250 net scfm each.

8.4.17 Field Painting, All Units

All exposed ductwork will be painted with a mu ltiple coat paint system. All other exposed

steel with painted with an inorganic zinc primer and polyurethane system.

8.4.18 Performance Testing

Performance testing is included as part of th e Owner’s costs in the estimate tabulation.

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Design Basis for Dry FGD 

# 8.4.19 Construction Support

Construction support will be required at each stati on. It is estimated that support will be

required for 12 months, at an average of 1.5 persons per station.

8.4.20 Piping per Unit

Each Unit will require new instrument air piping run as a header from th e new instrument air

dryers. Instrument air takeoffs will be run from the headers to each lime silo or day bin, bin

vent, and reagent preparation and recycle area.

8.4.21 New Booster Fans

New axial booster fans will be required to overcome the additional pressure drop seen

through the SDA’s and baghouses.

a. Two 3500 hp axial ID fans w ill be installed on each unit. These fans will be arranged

in a 2 x 50% configuration.

b. The price includes foundations and motors. A spare motor is not included.

8.4.22 Electrical per Station

The electrical items discussed below summarize everything required to power the new DFGD

area at each Station

a. One additional startup transformer will be requi red at each station. i.e. one at Sooner

and one at Muskogee.

b. One unit auxiliary transformer will be requi red per unit, totaling two per station.

Each UAT will be housed in a pre-engineered building.

c. Medium voltage switchgear for each unit.

d. One 480 V switchgear for reagent prepara tion, recycle, and SDA at each unit.

e. One pre-engineered reagent preparation el ectrical equipment building for each unit.

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# 16

Design Basis for Dry FGD 

# Attachment 1

Mass Balance Diagrams for

Sooner Station and Muskogee StationClient: Oklahoma Gas ElectricStation: Sooner - Unit 1 or 2SDA FGD SystemProject No.11418-01911/25/2009PROCESS FLOW DIAGRAM04 05 0701Ca:S Inlet 1.5Ca:S Inlet 5.10°F 30°F 13302lb/lb dry air 0.131lb/MMBtu 0.012% 50.003ft/s 5.9ft 59Carbon wt% 48.52SO2Inlb/MMBtu 1.176Hydrogen wt% 3.10BSO2Outlb/MMBtu 0.100Nitrogen wt% 0.77SO3Inlb/MMBtu 0.009Sulfur wt% 0.48SO3Outlb/MMBtu 0.002Oxygen wt% 11.80Chlorine wt% 0.01DFluorine wt% 0.00CMoisture wt% 27.82 CaO dry wt% 90.0CAsh wt% 7.50 MgO dry wt% 5.0 06Booster Fans (2x50%)Calc. HHV Btu/lb 8,084 Inert Solids dry wt% 5.00809Temperature °FPressure in. WC (g)N2lb/hr-vol% 4,010,582 69.80 4,010,582 66.22 4,010,582 66.22 4,010,582 66.22 10O2lb/hr-vol% 302,541 4.61 302,238 4.37 302,194 4.37 302,194 4.37H2Olb/hr-vol% 482,914 13.07 684,352 17.58 684,352 17.58 684,352 17.5814CO2lb/hr-vol% 1,125,871 12.47 1,125,871 11.83 1,125,871 11.83 1,125,871 11.83SO2lb/hr-ppmv 6,015 458 1,203 87 511 37 511 37 Recycle Feed Pumps (3x100%)11SO3lb/hr-ppmv 463915050HCl lb/hr-ppmv 659000000HF lb/hr-ppmv0000000012Total Flow lb/hr-acfm 5,928,032 1,910,947 6,124,255 1,724,051 6,123,515 1,764,944 6,123,515 1,712,144 Recycle Solids Mixing Tanks (2x100%)MW - Moist. lb/lbmol-lb/lb 28.889 0.089 28.313 0.122 28.311 0.126 28.311 0.122Ash lb/hr-gr/acf 380 0.023 6,287 0.425 63 0.004 63 0.004Fresh Lime Slaker H2O Lime Slurry Dilution H2O Diluted Slurry Recycle SDA Inlet Waste SolidsRecycle SolidsRecycle H2O Pin Mixer H2O Landfill Total Water Stabilization Flyash Waste01 02 03 04 05 06 07 08 09 10 11 12 13 14 15Inert Solids lb/hr 445 0 445 0 445 5,524 5,970 762 5,524 0 0 1,638 0 876 36,715 02CaO lb/hr 8,0170 0 0 0 0 0 0 0 0 0 0 000Ca(OH)2lb/hr 0 0 10,594 0 10,594 29,908 40,502 4,127 29,908 0 0 4,127 0 0 0 04MgO lb/hr 445 0 445 0 445 3,228 3,673 445 3,228 0 0 445 0 0 0CaSO3*0.5H2Olb/hr0000060,656 60,656 8,369 60,656 0 0 8,369 0 0 0 10CaSO4*2H2Olb/hr0000026,958 26,958 3,720 26,958 0 0 3,720 0 0 0CaCl2 + CaF2 lb/hr0 0 0 0 0 717 717 99 717 0 0 99 0 0 0 11Total Solids lb/hr 8,908 0 11,484 0 11,484 126,992 138,476 17,522 126,992 0 0 18,398 0 876 36,715Water lb/hr 0 29,374 26,797 0 26,797 190,488 217,285 1,947 14,110 176,378 5,938 7,885 211,690 0 0 13Total Flow lb/hr 8,908 29,374 38,281 0 38,281 317,480 355,762 19,469 141,102 176,378 5,938 26,283 211,690 876 36,715Total Flow gpm --- 59 62 0 62 491 554 --- --- 352 12 53 423 --- ---Solids wt% 100 0 30 0 30 40 39 90 90 0 0 70 0 100 100Water BalanceFGD Process ParametersC1BaghouseInlet Stoich.Internal Stoich.Approach to SaturationSaturation TemperatureSaturation HumidityOutlet ParticulatesFlow per AbsorberVelocity per AbsorberDiameter per AbsorberSulfur LevelsA B163279 163-1 -7 -16Stream CharacteristicsCoal AnalysisLime AnalysisD171Short TermRecycle Silos(2x100%)Stream CharacteristicsID Fan Outlet SDA Outlet Stack InletBooster Fan InletFresh Lime Slurry TankFrom Cold ESPOutletASpray Dryer AbsorberID Fans (2x50%)Lime SlakerLong TermWaste SiloPin MixerFly AshDaySiloSargent & Lundy LLC ConfidentialPage 1 of 1Client: Oklahoma Gas ElectricStation: Sooner - Unit 1 or 2SDA FGD SystemAverage Sulfur CaseProject No.11418-01912/4/2009PROCESS FLOW DIAGRAM04 05 0701Ca:S Inlet 1.5Ca:S Inlet 12.84°F 30°F 13202lb/lb dry air 0.129lb/MMBtu 0.014% 50.003ft/s 5.9ft 59Carbon wt% 51.29SO2Inlb/MMBtu 0.509Hydrogen wt% 3.34BSO2Outlb/MMBtu 0.100Nitrogen wt% 0.67SO3Inlb/MMBtu 0.004Sulfur wt% 0.22SO3Outlb/MMBtu 0.001Oxygen wt% 12.22Chlorine wt% 0.01DFluorine wt% 0.00CMoisture wt% 26.95 CaO dry wt% 90.0CAsh wt% 5.30 MgO dry wt% 5.0 06Booster Fans (2x50%)Calc. HHV Btu/lb 8,593 Inert Solids dry wt% 5.00809Temperature °FPressure in. WC (g)N2lb/hr-vol% 3,998,604 70.08 3,998,604 66.45 3,998,604 66.45 3,998,604 66.45 10O2lb/hr-vol% 301,362 4.62 301,231 4.38 301,230 4.38 301,230 4.38H2Olb/hr-vol% 469,360 12.80 670,245 17.33 670,245 17.33 670,245 17.3314CO2lb/hr-vol% 1,119,692 12.49 1,119,692 11.84 1,119,692 11.84 1,119,692 11.84SO2lb/hr-ppmv 2,605 200 521 38 513 37 513 37 Recycle Feed Pumps (3x100%)11SO3lb/hr-ppmv 201402020HCl lb/hr-ppmv 618000000HF lb/hr-ppmv0000000012Total Flow lb/hr-acfm 5,891,704 1,897,800 6,090,297 1,710,996 6,090,286 1,751,677 6,090,286 1,699,299 Recycle Solids Mixing Tanks (2x100%)MW - Moist. lb/lbmol-lb/lb 28.911 0.087 28.339 0.120 28.338 0.124 28.338 0.120Ash lb/hr-gr/acf 252 0.016 7,298 0.498 73 0.005 73 0.005Fresh Lime Slaker H2O Lime Slurry Dilution H2O Diluted Slurry Recycle SDA Inlet Waste Solids Recycle Solids Recycle H2OPin Mixer H2OLandfill Total Water StabilizationFlyash Waste01 02 03 04 05 06 07 08 09 10 11 12 13 14 15Inert Solids lb/hr 195 0 195 0 195 6,916 7,111 374 6,916 0 0 745 0 370 24,992 02CaO lb/hr 3,5110 0 0 0 0 0 0 0 0 0 0 000Ca(OH)2lb/hr 0 0 4,639 0 4,639 39,548 44,187 2,142 39,548 0 0 2,142 0 0 0 04MgO lb/hr 195 0 195 0 195 3,602 3,797 195 3,602 0 0 195 0 0 0CaSO3*0.5H2Olb/hr0000058,799 58,799 3,184 58,799 0 0 3,184 0 0 0 10CaSO4*2H2Olb/hr0000026,133 26,133 1,415 26,133 0 0 1,415 0 0 0CaCl2 + CaF2 lb/hr000001,719 1,719 93 1,719 0 0 93 0 0 0 11Total Solids lb/hr 3,901 0 5,029 0 5,029 136,716 141,745 7,403 136,716 0 0 7,774 0 370 24,992Water lb/hr 0 12,863 11,734 0 11,734 205,075 216,809 823 15,191 189,884 2,509 3,332 205,256 0 0 13Total Flow lb/hr 3,901 12,863 16,763 0 16,763 341,791 358,554 8,226 151,907 189,884 2,509 11,105 205,256 370 24,992Total Flow gpm --- 26 27 0 27 529 556 --- --- 379 5 22 410 --- ---Solids wt% 100 0 30 0 30 40 40 90 90 0 0 70 0 100 100Fresh Lime Slurry TankFrom Cold ESPOutletASpray Dryer AbsorberID Fans (2x50%)ID Fan Outlet SDA Outlet Stack InletBooster Fan InletD170Short TermRecycle Silos(2x100%)Stream CharacteristicsStream CharacteristicsCoal AnalysisLime AnalysisA B162279 162-1 -7 -16Approach to SaturationSaturation TemperatureSaturation HumidityOutlet ParticulatesFlow per AbsorberVelocity per AbsorberDiameter per AbsorberSulfur LevelsWater BalanceFGD Process ParametersC1BaghouseInlet Stoich.Internal Stoich.Lime SlakerLong TermWaste SiloPin MixerFly AshDay SiloSargent & Lundy LLC ConfidentialPage 1 of 1Client: Oklahoma Gas ElectricStation: Muskogee - Unit 4 or 5SDA FGD SystemProject No.11418-01911/25/2009PROCESS FLOW DIAGRAM04 05 0701Ca:S Inlet 1.5Ca:S Inlet 5.10°F 30°F 13302lb/lb dry air 0.131lb/MMBtu 0.012% 50.003ft/s 6.0ft 60Carbon wt% 48.52SO2Inlb/MMBtu 1.176Hydrogen wt% 3.10BSO2Outlb/MMBtu 0.100Nitrogen wt% 0.77SO3Inlb/MMBtu 0.009Sulfur wt% 0.48SO3Outlb/MMBtu 0.002Oxygen wt% 11.80Chlorine wt% 0.01DFluorine wt% 0.00CMoisture wt% 27.82 CaO dry wt% 90.0CAsh wt% 7.50 MgO dry wt% 5.0 06Booster Fans (2x50%)Calc. HHV Btu/lb 8,084 Inert Solids dry wt% 5.00809Temperature °FPressure in. WC (g)N2lb/hr-vol% 4,295,932 69.80 4,295,932 66.22 4,295,932 66.22 4,295,932 66.22 10O2lb/hr-vol% 324,066 4.61 323,742 4.37 323,695 4.37 323,695 4.37H2Olb/hr-vol% 517,273 13.07 733,044 17.58 733,044 17.58 733,044 17.5814CO2lb/hr-vol% 1,205,976 12.47 1,205,976 11.83 1,205,976 11.83 1,205,976 11.83SO2lb/hr-ppmv 6,442 458 1,288 87 548 37 548 37 Recycle Feed Pumps (3x100%)11SO3lb/hr-ppmv 49 3 1015050HCl lb/hr-ppmv 709000000HF lb/hr-ppmv0000000012Total Flow lb/hr-acfm 6,349,808 2,046,910 6,559,992 1,846,716 6,559,199 1,890,519 6,559,199 1,833,962 Recycle Solids Mixing Tanks (2x100%)MW - Moist. lb/lbmol-lb/lb 28.889 0.089 28.313 0.122 28.311 0.126 28.311 0.122Ash lb/hr-gr/acf 407 0.023 6,734 0.425 67 0.004 67 0.004Fresh Lime Slaker H2O Lime Slurry Dilution H2O Diluted Slurry Recycle SDA Inlet Waste Solids Recycle Solids Recycle H2OPin Mixer H2OLandfill Total Water Stabilization Flyash Waste01 02 03 04 05 06 07 08 09 10 11 12 13 14 15Inert Solids lb/hr 477 0 477 0 477 5,917 6,394 816 5,917 0 0 1,755 0 938 40,265 02CaO lb/hr 8,5870 0 0 0 0 0 0 0 0 0 0 000Ca(OH)2lb/hr 0 0 11,347 0 11,347 32,036 43,383 4,420 32,036 0 0 4,420 0 0 0 04MgO lb/hr 477 0 477 0 477 3,458 3,935 477 3,458 0 0 477 0 0 0CaSO3*0.5H2Olb/hr0000064,972 64,972 8,965 64,972 0 0 8,965 0 0 0 10CaSO4*2H2Olb/hr0000028,876 28,876 3,984 28,876 0 0 3,984 0 0 0CaCl2 + CaF2 lb/hr0 0 0 0 0 768 768 106 768 0 0 106 0 0 0 11Total Solids lb/hr 9,541 0 12,302 0 12,302 136,027 148,329 18,768 136,027 0 0 19,707 0 938 40,265Water lb/hr 0 31,464 28,704 0 28,704 204,041 232,745 2,085 15,114 188,927 6,360 8,446 226,751 0 0 13Total Flow lb/hr 9,541 31,464 41,005 0 41,005 340,069 381,074 20,854 151,142 188,927 6,360 28,153 226,751 938 40,265Total Flow gpm --- 63 66 0 66 526 594 --- --- 378 13 56 453 --- ---Solids wt% 100 0 30 0 30 40 39 90 90 0 0 70 0 100 100Water BalanceFGD Process ParametersC1BaghouseInlet Stoich.Internal Stoich.Approach to SaturationSaturation TemperatureSaturation HumidityOutlet ParticulatesFlow per AbsorberVelocity per AbsorberDiameter per AbsorberSulfur LevelsA B163279 163-1 -7 -16Stream CharacteristicsCoal AnalysisLime AnalysisD171Short TermRecycle Silos(2x100%)Stream CharacteristicsID Fan Outlet SDA Outlet Stack InletBooster Fan InletFresh Lime Slurry TankFrom Cold ESPOutletASpray Dryer AbsorberID Fans (2x50%)Lime SlakerLong TermWaste SiloPin MixerFly AshDay SiloSargent & Lundy LLC ConfidentialPage 1 of 1Client: Oklahoma Gas ElectricStation: Muskogee - Unit 4 or 5SDA FGD SystemAverage Sulfur CaseProject No.11418-01912/4/2009PROCESS FLOW DIAGRAM04 05 0701Ca:S Inlet 1.5Ca:S Inlet 12.91°F 30°F 13202lb/lb dry air 0.129lb/MMBtu 0.014% 50.003ft/s 6.0ft 60Carbon wt% 51.29SO2Inlb/MMBtu 0.507Hydrogen wt% 3.34BSO2Outlb/MMBtu 0.100Nitrogen wt% 0.67SO3Inlb/MMBtu 0.004Sulfur wt% 0.22SO3Outlb/MMBtu 0.001Oxygen wt% 12.22Chlorine wt% 0.01DFluorine wt% 0.00CMoisture wt% 26.95 CaO dry wt% 90.0CAsh wt% 5.30 MgO dry wt% 5.0 06Booster Fans (2x50%)Calc. HHV Btu/lb 8,593 Inert Solids dry wt% 5.00809Temperature °FPressure in. WC (g)N2lb/hr-vol% 4,283,094 70.08 4,283,094 66.45 4,283,094 66.45 4,283,094 66.45 10O2lb/hr-vol% 322,803 4.62 322,663 4.38 322,662 4.38 322,662 4.38H2Olb/hr-vol% 502,756 12.80 717,934 17.33 717,934 17.33 717,934 17.3314CO2lb/hr-vol% 1,199,363 12.49 1,199,363 11.84 1,199,363 11.84 1,199,363 11.84SO2lb/hr-ppmv 2,778 199 556 38 550 37 550 37 Recycle Feed Pumps (3x100%)11SO3lb/hr-ppmv 211402020HCl lb/hr-ppmv 668000000HF lb/hr-ppmv0000000012Total Flow lb/hr-acfm 6,310,880 2,032,825 6,523,614 1,832,731 6,523,606 1,876,308 6,523,606 1,820,203 Recycle Solids Mixing Tanks (2x100%)MW - Moist. lb/lbmol-lb/lb 28.911 0.087 28.339 0.120 28.338 0.124 28.338 0.120Ash lb/hr-gr/acf 270 0.016 7,831 0.498 78 0.005 78 0.005Fresh Lime Slaker H2O Lime Slurry Dilution H2O Diluted Slurry Recycle SDA Inlet Waste Solids Recycle Solids Recycle H2OPin Mixer H2OLandfill Total Water StabilizationFlyash Waste01 02 03 04 05 06 07 08 09 10 11 12 13 14 15Inert Solids lb/hr 208 0 208 0 208 7,425 7,633 400 7,425 0 0 795 0 395 26,770 02CaO lb/hr 3,7440 0 0 0 0 0 0 0 0 0 0 000Ca(OH)2lb/hr 0 0 4,947 0 4,947 42,443 47,390 2,287 42,443 0 0 2,287 0 0 0 04MgO lb/hr 208 0 208 0 208 3,860 4,068 208 3,860 0 0 208 0 0 0CaSO3*0.5H2Olb/hr0000062,933 62,933 3,391 62,933 0 0 3,391 0 0 0 10CaSO4*2H2Olb/hr0000027,970 27,970 1,507 27,970 0 0 1,507 0 0 0CaCl2 + CaF2 lb/hr000001,850 1,850 100 1,850 0 0 100 0 0 0 11Total Solids lb/hr 4,160 0 5,363 0 5,363 146,482 151,845 7,893 146,482 0 0 8,287 0 395 26,770Water lb/hr 0 13,717 12,514 0 12,514 219,723 232,236 877 16,276 203,447 2,675 3,552 219,839 0 0 13Total Flow lb/hr 4,160 13,717 17,877 0 17,877 366,204 384,081 8,770 162,757 203,447 2,675 11,839 219,839 395 26,770Total Flow gpm --- 27 29 0 29 566 596 --- --- 407 5 24 439 --- ---Solids wt% 100 0 30 0 30 40 40 90 90 0 0 70 0 100 100Fresh Lime Slurry TankFrom Cold ESPOutletASpray Dryer AbsorberID Fans (2x50%)ID Fan Outlet SDA Outlet Stack InletBooster Fan InletD170Short TermRecycle Silos(2x100%)Stream CharacteristicsStream CharacteristicsCoal AnalysisLime AnalysisA B162279 162-1 -7 -16Approach to SaturationSaturation TemperatureSaturation HumidityOutlet ParticulatesFlow per AbsorberVelocity per AbsorberDiameter per AbsorberSulfur LevelsWater BalanceFGD Process ParametersC1BaghouseInlet Stoich.Internal Stoich.Lime SlakerLong TermWaste SiloPin MixerFly AshDaySiloSargent & Lundy LLC ConfidentialPage 1 of 1

# Sooner 1 & 2 & Muskogee 4 & 5 12/28/09

D ESIGN 

# B ASIS DOCUMENT 

# Project 11418-019



# 17

Design Basis for Dry FGD 

# Attachment 2

Sooner Station and Muskogee Station

General Arrangement Drawings

# Sooner 1 & 2 & Muskogee 4 & 5 12/28/09

D ESIGN 

# B ASIS DOCUMENT 

# Project 11418-019



# 18

Design Basis for Dry FGD 

# Attachment 3

Sooner Station and Muskogee Station

Power Requirement Tables

# Oklahoma Gas Electric

Sooner and Muskogee Stations

BART Analysis Follow-Up Work Project No. 11418-019

November 25, 2009

Inputs: Capacity Heat Input SDA Inlet

Flow* SDA

Outlet

Flow* Booster

Fan Inlet

Flow* Max.

Sulfur in

Coal HHV Inlet SO 2 

# Max.

Lime*

MWg mmBtu/hr acfm acfm acfm % Btu/lb lb/mmBtu lb/hr

Sooner Unit 1 or 2 570 5,116 1,910,947 1,724,051 1,764,944 0.48 8,084 1.176 8,908

Operatin g

Connecte d Operatin g HP kW HP kW HP kW Usa ge

Absorber Island

A tomizer s 2 2 960 716 1920 1432 1920 1432

Penthouse Heater s 2 2 50 100 100 ( winter )

Damper s 2 2 5 4 10 7 10 0.1 2% tim e

Miscellaneou s 30 22 30 22 3 2 10% tim e

Total 1562 1535

Operatin g

Connecte d Operatin g HP kW HP kW HP kW Usa ge

Reagent Preparation and Recycle Island

Lime Unloadin g Blowe 2 1 300 224 600 448 30 22 10% tim e

Silo Live Botto m 2 1 7 5 14 10 7 5

Lime Feede r 2 1 5 4 10 7 5 4

Ball Mill Slake r 2 1 110 82 220 164 110 82

Slurr y Tank A g itato r 2 1 40 30 80 60 40 30

Slurr y Feed Pum p 2 1 20 15 40 30 20 15

Rec y cle Silo Fluidization Air Blow e 2 1 20 15 40 30 20 15

Rec y cle Silo Fluidization Air Heat e 2 1 40 80 40

Rec y cle Slurr y Mixer 2 1 150 112 300 224 150 112

Rec y cle Feed Pum p 2 1 40 30 80 60 40 30

Miscellaneou s 20 15 20 15 10 7 50% tim e

Total 1127 362 Summary of DFGD/BAGHOUSE Power Consumption

Sooner Unit 1 or 2

*From S&L mass balance



# CONNECTED OPERATING OPERATING CONNECTED Load per Moto r

0.5 to 10 HP motor s

0.5 to 10 HP motor s Load per Moto r

Page 1 of 4

# Oklahoma Gas Electric

Sooner and Muskogee Stations

BART Analysis Follow-Up Work Project No. 11418-019

November 25, 2009

Summary of DFGD/BAGHOUSE Power Consumption

Sooner Unit 1 or 2

Operatin g

Connecte d Operatin g HP kW HP kW HP kW Usa ge

Baghouse/Ash Handling Islan d

Compresso r 2 1 500 373 1000 746 250 187 50% tim e

Hopper Heate r 16 16 260 260 130 50% tim e

Penthouse Heaters / Hoppe r

Enclosure Heaters 12 12 240 240 120 50% time

Transport Air Vac. Blower s 2 1 150 112 300 224 150 112

Miscellaneou s 50 37 50 37 10 7 20% tim e

Total 1507 556

Operatin g

Connecte d Operatin g HP kW HP kW HP kW Usa ge

Booster Fan System w FGD

Booster Fan with FG D 2 2 3280 2450 6560 4890 6560 4890

Miscellaneou s 20 10 20 15 20 15

Total 4900 4900

Total Aux. Power Connected



# (MW) Operatin g

(MW)

FGD S y stem onl y ( SDA+BH ) Bas e 4.2 2.5

Total 4.2 2.5

SDA/Baghouse/Booster Fans Base 9.1 7.4

Total 9.1 7.4 1.29% CONNECTED OPERATING Load per Moto r CONNECTED OPERATING

0.5 to 10 HP motor s 0.5 to 10 HP motor s

Load per Moto r

Page 2 of 4

# Oklahoma Gas Electric

Sooner and Muskogee Stations

BART Analysis Follow-Up Work Project No. 11418-019

November 25, 2009

Inputs: Capacity Heat Input SDA Inlet

Flow* SDA

Outlet

Flow* Booster

Fan Inlet

Flow* Max.

Sulfur in

Coal HHV Inlet SO 2 

# Max.

Lime*

MWg mmBtu/hr acfm acfm acfm % Btu/lb lb/mmBtu lb/hr

Muskogee Unit 4 or 5 572 5,480 2,046,910 1,846,716 1,890,519 0.48 8,084 1.176 9,541

Operatin g

Connecte d Operatin g HP kW HP kW HP kW Usa ge

Absorber Island

A tomizer s 2 2 1020 761 2040 1522 2040 1522

Penthouse Heater s 2 2 50 100 100 ( winter )

Damper s 2 2 5 4 10 7 10 0.1 2% tim e

Miscellaneou s 30 22 30 22 3 2 10% tim e

Total 1652 1624

Operatin g

Connecte d Operatin g HP kW HP kW HP kW Usa ge

Reagent Preparation and Recycle Island

Lime Unloadin g Blowe 2 1 320 239 640 477 32 24 10% tim e

Silo Live Botto m 2 1 8 6 16 12 8 6

Lime Feede r 2 1 5 4 10 7 5 4

Ball Mill Slake r 2 1 120 90 240 179 120 90

Slurr y Tank A g itato r 2 1 40 30 80 60 40 30

Slurr y Feed Pum p 2 1 30 22 60 45 30 22

Rec y cle Silo Fluidization Air Blow e 2 1 30 22 60 45 30 22

Rec y cle Silo Fluidization Air Heat e 2 1 40 80 40

Rec y cle Slurr y Mixer 2 1 150 112 300 224 150 112

Rec y cle Feed Pum p 2 1 40 30 80 60 40 30

Miscellaneou s 20 15 20 15 10 7 50% tim e

Total 1203 387 0.5 to 10 HP motor s Load per Moto r OPERATING CONNECTED Load per Moto r

0.5 to 10 HP motor s Summary of DFGD/BAGHOUSE Power Consumption

Muskogee Unit 4 or 5

*From S&L mass balance



# CONNECTED OPERATING

Page 3 of 4

# Oklahoma Gas Electric

Sooner and Muskogee Stations

BART Analysis Follow-Up Work Project No. 11418-019

November 25, 2009

Summary of DFGD/BAGHOUSE Power Consumption

Muskogee Unit 4 or 5

Operatin g

Connecte d Operatin g HP kW HP kW HP kW Usa ge

Baghouse/Ash Handling Islan d

Compresso r 2 1 540 403 1080 806 270 201 50% tim e

Hopper Heate r 16 16 260 260 130 50% tim e

Penthouse Heaters / Hoppe r

Enclosure Heaters 12 12 240 240 120 50% time

Transport Air Vac. Blower s 2 1 150 112 300 224 150 112

Miscellaneou s 50 37 50 37 10 7 20% tim e

Total 1567 571

Operatin g

Connecte d Operatin g HP kW HP kW HP kW Usa ge

Booster Fan System w FGD

Booster Fan with FG D 2 2 3520 2630 7040 5250 7040 5250

Miscellaneou s 20 10 20 15 20 15

Total 5260 5260

Total Aux. Power Connected



# (MW) Operatin g

(MW)

FGD S y stem onl y ( SDA+BH ) Bas e 4.4 2.6

Total 4.4 2.6

SDA/Baghouse/Booster Fans Base 9.7 7.8

Total 9.7 7.8 1.37% 0.5 to 10 HP motor s 0.5 to 10 HP motor s

Load per Moto r CONNECTED OPERATING Load per Moto r CONNECTED OPERATING

Page 4 of 4

# Sooner 1 & 2 & Muskogee 4 & 5 12/28/09

D ESIGN 

# B ASIS DOCUMENT 

# Project 11418-019



# 19

Design Basis for Dry FGD 

# Attachment 4

Sooner Station Units 1 and 2

Muskogee Units 4 and 5

Material Handling Diagrams

# Sooner 1 & 2 & Muskogee 4 & 5 12/28/09

D ESIGN 

# B ASIS DOCUMENT 

# Project 11418-019



# 20

Design Basis for Dry FGD 

# Attachment 5

Summary of DFGD Vendor Quotations

Sooner and MuskogeeOG&ESooner Units 1&2DFGD Budgetary Proposal PricingDate: 12/11/2009Equipment Description Bidder 1 Bidder 2 Bidder 3 Average CostLime preparation $5,010,000 $20,000,000 Incl with Other MiscAbsorber Equipment $20,962,000 $16,000,000 $21,400,000Recycle System $4,506,000 $4,000,000 Incl with Other MiscFabric Filter $13,054,000 $26,000,000 $23,600,000Compressor System $2,670,000 $2,000,000 Incl with Other MiscOther Misc Equipment $10,820,000 $4,000,000 $33,000,000Total Equipment (Units 1&2) $57,022,000 $72,000,000 $78,000,000 $69,007,333S&L Cost Estimate for Sooner 1&2Erection Budget Price (Units 1&2)$62,384,000 $67,270,000 $73,036,000$67,563,333S&L Cost Estimate for Sooner 1&2Note:Bidders 2and3providedestimated erection manhours.Budget erection cost is calculated based oncurrent S&L Cost Estimate using $62/mhrfor mechanical labor cost (non-union) and55% markup forCrane+scaffolding+mob/demob+Overtime+Per diem+G&A+ProfitNote: S&L Cost estimate was performedbased on our historical pricing informationfor Equipment/Material and Labor Costs.Labor costs were developed independentlyfrom the three bidders$70,500,000$65,753,000PROPOSAL PRICING COMPARISON FOR OG&E - SOONER UNITS 1&2 DFGD SYSTEM

# Sooner 1 & 2 & Muskogee 4 & 5 12/28/09

D ESIGN 

# B ASIS DOCUMENT 

# Project 11418-019



# 21

Design Basis for Dry FGD 

# Attachment 6

Project ScheduleActivityIDDBActivityDescriptionOrigDureuStartFinishDFGDPRELIMINARY ENGINEERINGSLN1001Project Authorization001FEB11*SLN1G01020Develop FGDs GAs and Engineering Studies14001FEB1116AUG11SLN1G01090Prepare Design Criteria8405APR1101AUG11SLN1G01608Prepare Preliminary Site Arrangement Dwgs2331MAY1130JUN11EPC SPECSLN1110DFGD Sys EPC Spec - Bid Issue to Client4001FEB1128MAR11SLN1118DFGD Sys EPC Spec- Bid Issue to Vendors529MAR1104APR11SLN1120Vendor Bid Period6005APR1127JUN11SLN1130Evaluate Bids3028JUN1109AUG11SLN1140Negotiation4010AUG1104OCT11SLN1150Award EPC004OCT11PERMITTINGSLP0000108FGD Other Permits97802AUG11*15MAY15SLN2P00001Air Permit: Dry FGD Prepare/Submit63630AUG1114FEB14ENGINEERING - ALL UNITSSLNSUM1900Ductwork Design47215JUN1215APR14SLNSUM0500BOP Piping & Hanger Design58625JUN1201OCT14SLNSUM0510Electrical Design65428JUN1212JAN15SLNSUM0520Substructure Design46109JUL1221APR14SLNSUM0800Steel Design45009JUL1204APR14SLNSUM1060Develop Preliminary P&ID's20618JUL1203MAY13SLNSUM0550P&I ID Preparation48219SEP1201AUG14SLNSUM0600Electrical Wiring53322JAN1313FEB15MAJOR PROCUREMENT - ALL UNITSSLN1M10000DFGD Spec - Bid Issue6019OCT1112JAN12SLN1M10060DFGD Spec - Award Contract011APR12SLN1M23600Fabric Filter Bid/Award10012APR1230AUG12SLN1M13500ID Booster Fans - Bid/Award9207MAY1212SEP12SLN1E17500Switchyard/TL Upgrades Bid/Award9229MAY1204OCT12201120122013201420152016JFMAMJJASONDJFMAMJJASONDJFMAMJJASONDJFMAMJJASONDJFMAMJJASONDJFA© Primavera Systems, Inc.Start Date 31MAY10Finish Date 26FEB16Data Date 01JUN10Run Date 30NOV09 13:26DF01OKLAHOMA GAS & ELECTRICSooner & Muskogee Stations DFGD PrjSUMMARY SCHEDULESheet 1 of 4Sheet 2 of 4ActivityIDDBActivityDescriptionOrigDureuStartFinishMAJOR PROCUREMENT - ALL UNITSSLN2S12000Ductwork Bid/Award9213AUG1218DEC12SLN2S13000Structural Steel Bid/Award9213AUG1218DEC12SLN1ES7000Aux Transformer Bid/Award9213SEP1222JAN13SLN2E18000Medium Voltage Switchgear Spec - Prep/Rvw/Award9216OCT1222FEB13SLN2F15000DCS Bid/Award9208NOV1219MAR13SLN2M16000Dampers Bid/Award9208NOV1219MAR13FABRICATION / DELIVERY - SOONER U1FDS10010DFGD Fabrication & Delivery - Sooner U126217MAY1222MAY13FDS10020Fabric Filter Fabrication & Delivery - Sooner U130031AUG1229OCT13FDS10030ID Booster Fan Fab & Delivery - Sooner U128013SEP1214OCT13FDS10040Aux Transformer Fab & Delivery - Sooner U119006MAR1327NOV13FABRICATION / DELIVERY - SOONER U2FDS20010DFGD Fabrication & Delivery - Sooner U226205DEC1210DEC13FDS20020Fabric Filter Fabrication & Delivery - Sooner U230025FEB1323APR14FDS20030ID Booster Fan Fab & Delivery - Sooner U228018MAR1316APR14FDS20040Aux Transformer Fab & Delivery - Sooner U219006AUG1330APR14FABRICATION / DELIVERY - MUSKOGEE U4FDM40010DFGD Fabrication & Delivery - Muskogee U426230MAY1304JUN14FDM40020Fabric Filter Fab & Delivery - Muskogee U430019AUG1315OCT14FDM40030ID Booster Fan Fab & Delivery - Muskogee U428009SEP1308OCT14FDM40040Aux Transformer Fab & Delivery - Muskogee U419029JAN1422OCT14FABRICATION / DELIVERY - MUSKOGEE U5FDM50010DFGD Fabrication & Delivery - Muskogee U526221NOV1326NOV14FDM50020Fabric Filter Fab & Delivery - Muskogee U530011FEB1409APR15FDM50030ID Booster Fan Fab & Delivery - Muskogee U528004MAR1402APR15FDM50040Aux Transformer Fab & Delivery - Muskogee U519023JUL1416APR15CONSTRUCTION CONTRACTSSLN1S20000General Work Contract - Prep/Rvw/Award/Spec8508JUN1205OCT12CONSTRUCTION - SOONER U1CMS10010General Work Contractor Mobilization - Sooner U11022OCT1202NOV12CMS10020U/G Utilities Relocation FGD Area - Sooner U14505NOV1208JAN13CMS10030DFGD Foundations - Sooner U18024DEC1216APR13CMS10040Structural Steel Installation - Sooner U110016APR1303SEP13CMS10050DFGD Erection and Startup - Sooner U130022MAY1321JUL14201120122013201420152016JFMAMJJASONDJFMAMJJASONDJFMAMJJASONDJFMAMJJASONDJFMAMJJASONDJFASheet 2 of 4Sheet 3 of 4ActivityIDDBActivityDescriptionOrigDureuStartFinishCONSTRUCTION - SOONER U1CMS10060ID Booster Fan Area Foundations - Sooner U19024JUN1328OCT13CMS10070Duckwork Installation - Sooner U115015AUG1314MAR14CMS10080Fabric Filter Erection - Sooner U114530OCT1322MAY14CMS10090ID Booster Fan Installation - Sooner U16012NOV1305FEB14CMS10100Electrical Installation - Sooner U116005DEC1321JUL14CMS10110Mechanical Installation - Sooner U114006JAN1421JUL14CMS10120Ductwork Erection ID Fan - Sooner U14006FEB1402APR14START-UP - SOONER U1SUS10010FGD Commissioning & Start Up - Sooner U114008FEB1421JUL14SUS10020Tie-in Outage - Sooner U13709JUN1421JUL14SUS10030DFGD in Service - Sooner U1021JUL14SUS10040DFGD System Balancing / Performance Testing - S15222JUL1419SEP14CONSTRUCTION - SOONER U2CMS20010General Work Contractor Mobilization - Sooner U21015APR13*26APR13CMS20020U/G Utilities Relocation FGD Area - Sooner U24529APR1328JUN13CMS20030DFGD Foundations - Sooner U28017JUN1307OCT13CMS20040Structural Steel Installation - Sooner U210007OCT1325FEB14CMS20050DFGD Erection and Startup - Sooner U230012NOV1312JAN15CMS20060ID Booster Fan Area Foundations - Sooner U29024DEC1330APR14CMS20070Duckwork Installation - Sooner U215020FEB1418SEP14CMS20080Fabric Filter Erection - Sooner U214524APR1413NOV14CMS20090ID Booster Fan Installation - Sooner U26015MAY1407AUG14CMS20100Electrical Installation - Sooner U216029MAY1412JAN15CMS20110Mechanical Installation - Sooner U214026JUN1412JAN15CMS20120Ductwork Erection ID Fan - Sooner U24008AUG1402OCT14START-UP - SOONER U2SUS20010FGD Commissioning & Start Up - Sooner U214002AUG1412JAN15SUS20020Tie-in Outage - Sooner U23701DEC1412JAN15SUS20030DFGD in Service - Sooner U2012JAN15SUS20040DFGD System Balancing / Performance Testing - S25213JAN1513MAR15CONSTRUCTION - MUSKOGEE U4CMM40010General Work Contractor Mobilization - Muskogee41007OCT13*18OCT13CMM40020U/G Utilities Relocation FGD Area - Muskogee U44521OCT1320DEC13201120122013201420152016JFMAMJJASONDJFMAMJJASONDJFMAMJJASONDJFMAMJJASONDJFMAMJJASONDJFASheet 3 of 4Sheet 4 of 4ActivityIDDBActivityDescriptionOrigDureuStartFinishCONSTRUCTION - MUSKOGEE U4CMM40030DFGD Foundations - Muskogee U48009DEC1301APR14CMM40040Structural Steel Installation - Muskogee U410001APR1419AUG14CMM40050DFGD Erection and Startup - Muskogee U430007MAY1406JUL15CMM40060ID Booster Fan Area Foundations - Muskogee U49018JUN1422OCT14CMM40070Duckwork Installation - Muskogee U415014AUG1413MAR15CMM40080Fabric Filter Erection - Muskogee U414516OCT1408MAY15CMM40090ID Booster Fan Installation - Muskogee U46006NOV1430JAN15CMM40100Electrical Installation - Muskogee U416020NOV1406JUL15CMM40110Mechanical Installation - Muskogee U414018DEC1406JUL15CMM40120Ductwork Erection ID Fan - Muskogee U44002FEB1527MAR15START-UP - MUSKOGEE U4SUM40010FGD Commissioning & Start Up - Muskogee U414024JAN1506JUL15SUM40020Tie-in Outage - Muskogee U43725MAY1506JUL15SUM40030DFGD in Service - Muskogee U4006JUL15SUM40040DFGD System Balancing / Performance Testing - M45207JUL1504SEP15CONSTRUCTION - MUSKOGEE U5CMM50010General Work Contractor Mobilization - Muskogee51001APR14*14APR14CMM50020U/G Utilities Relocation FGD Area - Muskogee U54515APR1416JUN14CMM50030DFGD Foundations - Muskogee U58003JUN1423SEP14CMM50040Structural Steel Installation - Muskogee U510023SEP1411FEB15CMM50050DFGD Erection and Startup - Muskogee U530029OCT1428DEC15CMM50060ID Booster Fan Area Foundations - Muskogee U59010DEC1416APR15CMM50070Duckwork Installation - Muskogee U515006FEB1504SEP15CMM50080Fabric Filter Erection - Muskogee U514510APR1530OCT15CMM50090ID Booster Fan Installation - Muskogee U56001MAY1524JUL15CMM50100Electrical Installation - Muskogee U516015MAY1528DEC15CMM50110Mechanical Installation - Muskogee U514012JUN1528DEC15CMM50120Ductwork Erection ID Fan - Muskogee U54027JUL1518SEP15START-UP - MUSKOGEE U5SUM50010FGD Commissioning & Start Up - Muskogee U514018JUL1528DEC15SUM50020Tie-in Outage - Muskogee U53716NOV1528DEC15SUM50030DFGD in Service - Muskogee U5028DEC15SUM50040DFGD System Balancing / Performance Testing - M55229DEC1526FEB16201120122013201420152016JFMAMJJASONDJFMAMJJASONDJFMAMJJASONDJFMAMJJASONDJFMAMJJASONDJFASheet 4 of 4

# Oklahoma Gas & Electric December 28, 2009

BART Analysis Follow-Up Report (Rev. 1) Project No. 11418-019



# Attachment B

Annualized Costs

Sooner Units 1 & 2

Muskogee Units 4 & 5

# TABLE B-1

MUSKOGEE STATION UNIT 4

BART COST EVALUATION - DRY FGD (SDA) WORKSHEET

INPUT

Case 1 x 572 MW-gross

PC Boiler

Gross Plant Output (MW-gross) 572

Net Plant Output (MW-net) 527 Adjusted to account for additional auxiliary power.

Approximate Full Load Flue Gas Flow Rate (acfm) 2,288,000

Maximum Heat Input (mmBtu/hr) 5,480

Uncontrolled SO2 Emission Rate (lb/mmBtu) 0.507

Post Dry FGD SO2 Emission Rate (lb/mmBtu) 0.10

Capacity Factor used for Cost Estimates (%) 90%

CAPITAL COSTS Basis

Direct Costs $167,572,100

Indirect Costs $24,801,000

Contingency $31,552,100

Total Plant Cost $223,925,200

Escalation $31,638,600

Allow. for Funds Used During Constr. (AFUDC) $61,629,800

Total Plant Investment (TPI) $317,193,600

Replacement Power Costs $0

Total Capital Requirement (TCR) $317,193,600

Total Capital Investment ($/kW - gross) $555

Capital Recovery Factor 0.1036 See derivation in Table 5.

Annualized Capital Costs

(Capital Recover Factor x Total Capital Investment) $32,861,300

OPERATING COSTS Basis

Operating & Maintenance Costs

Variable O&M Costs

Lime Reagent Cost $1,730,600 105.53 $ Based on maximum heat input, SO2 removal rate (lb/hr), 0.90 stoichiometry,

90% CaO, 90% capacity factor, and $105.53/ton for lime.

Water Cost $534,100 2.57 $ Based on 219,839 lb/hr at full load, 90% capacity factor, and $2.57/1000 gal

FGD Waste Disposal Cost $1,894,300 40.59 $ Based on maximum heat input, SO2 removal rate (lb/hr), 90% capacity factor,

and $40.59/ton on-site disposal cost. Disposal cost only includes FGD byproducts and does not include fly ash.

Bag and Cage Replacement Costs $675,100 3.31 $ Based on the exhaust gas flow through the baghouse, air-to-cloth ratio of 3.5

for pulse jet baghouse, $3.31/ft2 bag cost (including fabric and hangers), 4%

contingency for bag cleaning, and 3 year bag life.

Ash Disposal Costs $0 40.59 $ Assumed no increase in ash disposal with the fabric filter compared to the

existing ESP control system.

Auxiliary Power Cost $5,812,000 85.92 $ Based on auxiliary power requirement of 1% (gross) for DFGD plus 0.5%

(gross) for the baghouse, 90% capacity factor, and $85.92/MWh.

Total Variable O&M Costs $10,646,100

Fixed O&M Costs

Additional Operators per shift 2.0 Based on S&L O&M estimate for dry FGD.

Operating Labor $1,029,500 58.76 $ 3 shifts/day, 365 days/year @ 58.76/hour (salary + benefits) .

Supervisor Labor $154,400 15.0% of operating labor. EPA Control Cost Manual, page 2-31

Maintenance Materials $1,903,200 0.6% Based on S&L experience on other FGD projects.

Maintenance Labor $1,132,500 110.0% of operating labor. EPA Control Cost Manual, page 2-31

Total Fixed O&M Cost $4,219,600

Indirect Operating Cost

Property Taxes $2,696,100 0.85%

Insurance $33,200 0.0105%

Administration $843,900 20%

Total Indirect Operating Cost $3,573,200

Total Annual Operating Cost $18,438,900

TOTAL ANNUAL COST

Annualized Capital Cost $32,861,300

Annual Operating Cost $18,438,900

Total Annual Cost $51,300,200 Musko g ee Unit 4

Based on Sargent & Lundy's conceptual cost estimating system. Direct costs

include equipment, material, and labor; plus spare parts, special tools,

consumables, and freight. Indirect costs include engineering, procurement,

construction management, start-up, commissioning, operator training, and

owner's costs.

Escalation and AFUDC were calculated from the estimated distribution of cash

flows during the construction period and OG&E's before-tax weighted average

cost of capital of 8.66%/year. The 37-day tie-in outage for each unit is

assumed to be coordinated with the normal 5-week scheduled outage such that

incremental replacement cost is negligible.

Calculated as % of total capital investment (EPA Air Pollution Control Cost

Manual 6th Ed., page 2-34). Administrative costs are 20% of Fixed O&M

based on S&L experience on other projects.

# TABLE B-2

MUSKOGEE STATION UNIT 5

BART COST EVALUATION - DRY FGD (SDA) WORKSHEET

INPUT

Case 1 x 572 MW-gross

PC Boiler

Gross Plant Output (MW-gross) 572

Net Plant Output (MW-net) 527 Adjusted to account for additional auxiliary power.

Approximate Full Load Flue Gas Flow Rate (acfm) 2,288,000

Maximum Heat Input (mmBtu/hr) 5,480

Uncontrolled SO2 Emission Rate (lb/mmBtu) 0.514

Post Dry FGD SO2 Emission Rate (lb/mmBtu) 0.10

Capacity Factor used for Cost Estimates (%) 90%

CAPITAL COSTS Basis

Direct Costs $167,572,100

Indirect Costs $24,801,000

Contingency $31,552,100

Total Plant Cost $223,925,200

Escalation $31,638,600

Allow. for Funds Used During Constr. (AFUDC) $61,629,800

Total Plant Investment (TPI) $317,193,600

Replacement Power Costs $0

Total Capital Requirement (TCR) $317,193,600

Total Capital Investment ($/kW - gross) $555

Capital Recovery Factor 0.1036 See derivation in Table 5.

Annualized Capital Costs

(Capital Recover Factor x Total Capital Investment) $32,861,300

OPERATING COSTS Basis

Operating & Maintenance Costs

Variable O&M Costs

Lime Reagent Cost $1,730,600 105.53 $ Based on maximum heat input, SO2 removal rate (lb/hr), 0.90 stoichiometry,

90% CaO, 90% capacity factor, and $105.53/ton for lime.

Water Cost $534,100 2.57 $ Based on 219,839 lb/hr at full load, 90% capacity factor, and $2.57/1000 gal

FGD Waste Disposal Cost $1,894,300 40.59 $ Based on maximum heat input, SO2 removal rate (lb/hr), 90% capacity factor,

and $40.59/ton on-site disposal cost. Disposal cost only includes FGD byproducts and does not include fly ash.

Bag and Cage Replacement Costs $675,100 3.31 $ Based on the exhaust gas flow through the baghouse, air-to-cloth ratio of 3.5

for pulse jet baghouse, $3.31/ft2 bag cost (including fabric and hangers), 4%

contingency for bag cleaning, and 3 year bag life.

Ash Disposal Costs $0 40.59 Assumed no increase in ash disposal with the fabric filter compared to the

existing ESP control system.

Auxiliary Power Cost $5,812,000 85.92 $ Based on auxiliary power requirement of 1% (gross) for DFGD plus 0.5%

(gross) for the baghouse, 90% capacity factor, and $85.92/MWh.

Total Variable O&M Costs $10,646,100

Fixed O&M Costs

Additional Operators per shift 2.0 Based on S&L O&M estimate for dry FGD.

Operating Labor $1,029,500 58.76 $ 3 shifts/day, 365 days/year @ 58.76/hour (salary + benefits) .

Supervisor Labor $154,400 15.0% of operating labor. EPA Control Cost Manual, page 2-31

Maintenance Materials $1,903,200 0.6% Based on S&L experience on other FGD projects.

Maintenance Labor $1,132,500 110.0% of operating labor. EPA Control Cost Manual, page 2-31

Total Fixed O&M Cost $4,219,600

Indirect Operating Cost

Property Taxes $2,696,100 0.85%

Insurance $33,200 0.0105%

Administration $843,900 20%

Total Indirect Operating Cost $3,573,200

Total Annual Operating Cost $18,438,900

TOTAL ANNUAL COST

Annualized Capital Cost $32,861,300

Annual Operating Cost $18,438,900

Total Annual Cost $51,300,200 Musko g ee Unit 5

Based on Sargent & Lundy's conceptual cost estimating system. Direct costs

include equipment, material, and labor; plus spare parts, special tools,

consumables, and freight. Indirect costs include engineering, procurement,

construction management, start-up, commissioning, operator training, and

owner's costs.

Escalation and AFUDC were calculated from the estimated distribution of cash

flows during the construction period and OG&E's before-tax weighted average

cost of capital of 8.66%/year. The 37-day tie-in outage for each unit is

assumed to be coordinated with the normal 5-week scheduled outage such that

incremental replacement cost is negligible.

Calculated as % of total capital investment (EPA Air Pollution Control Cost

Manual 6th Ed., page 2-34). Administrative costs are 20% of Fixed O&M

based on S&L experience on other projects.

# TABLE B-3

SOONER STATION UNIT 1

BART COST EVALUATION - DRY FGD (SDA) WORKSHEET

INPUT

Case 1 x 569 MW-gross

PC Boiler

Gross Plant Output (MW-gross) 569

Net Plant Output (MW-net) 524 Adjusted to account for additional auxiliary power.

Approximate Full Load Flue Gas Flow Rate (acfm) 2,276,000

Maximum Heat Input (mmBtu/hr) 5,116

Uncontrolled SO2 Emission Rate (lb/mmBtu) 0.509

Post Dry FGD SO2 Emission Rate (lb/mmBtu) 0.10

Capacity Factor used for Cost Estimates (%) 90%

CAPITAL COSTS Basis

Direct Costs $162,651,300

Indirect Costs $24,045,100

Contingency $29,336,700

Total Plant Cost $216,033,100

Escalation $23,301,500

Allow. for Funds Used During Constr. (AFUDC) $52,960,300

Total Plant Investment (TPI) $292,294,900

Replacement Power Costs $0

Total Capital Requirement (TCR) $292,294,900

Total Capital Investment ($/kW - gross) $514

Capital Recovery Factor 0.1036 See derivation in Table 5.

Annualized Capital Costs

(Capital Recover Factor x Total Capital Investment) $30,281,800

OPERATING COSTS Basis

Operating & Maintenance Costs

Variable O&M Costs

Lime Reagent Cost $1,826,900 118.80 $ Based on maximum heat input, SO2 removal rate (lb/hr), 0.90 stoichiometry,

90% CaO, 90% capacity factor, and $118.80/ton for lime.

Water Cost $95,100 0.49 $ Based on 205,256 lb/hr at full load, 90% capacity factor, and $0.49/1000 gal

FGD Waste Disposal Cost $1,733,500 39.60 $ Based on maximum heat input, SO2 removal rate (lb/hr), 90% capacity factor,

and $39.60/ton on-site disposal cost. Disposal cost only includes FGD byproducts and does not include fly ash.

Bag and Cage Replacement Costs $653,300 3.22 $ Based on the exhaust gas flow through the baghouse, air-to-cloth ratio of 3.5

for pulse jet baghouse, $3.22/ft2 bag cost (including fabric and hangers), 4%

contingency for bag cleaning, and 3 year bag life.

Ash Disposal Costs $0 39.60 $ Assumed no increase in ash disposal with the fabric filter compared to the

existing ESP control system.

Auxiliary Power Cost $5,640,900 83.83 $ Based on auxiliary power requirement of 1% (gross) for DFGD plus 0.5%

(gross) for the baghouse, 90% capacity factor, and $83.83/MWh.

Total Variable O&M Costs $9,949,700

Fixed O&M Costs

Additional Operators per shift 2.0 2 Based on S&L O&M estimate for dry FGD.

Operating Labor $1,004,400 57.33 $ 3 shifts/day, 365 days/year @ 57.33/hour (salary + benefits) .

Supervisor Labor $150,700 15.0% of operating labor. EPA Control Cost Manual, page 2-31

Maintenance Materials $1,753,800 0.6% Based on S&L experience on other FGD projects.

Maintenance Labor $1,104,800 110.0% of operating labor. EPA Control Cost Manual, page 2-31

Total Fixed O&M Cost $4,013,700

Indirect Operating Cost

Property Taxes $1,753,800 0.60%

Insurance $30,600 0.0105%

Administration $802,700 20%

Total Indirect Operating Cost $2,587,100

Total Annual Operating Cost $16,550,500

TOTAL ANNUAL COST

Annualized Capital Cost $30,281,800

Annual Operating Cost $16,550,500

Total Annual Cost $46,832,300 Sooner Unit 1

Based on Sargent & Lundy's conceptual cost estimating system. Direct costs

include equipment, material, and labor; plus spare parts, special tools,

consumables, and freight. Indirect costs include engineering, procurement,

construction management, start-up, commissioning, operator training, and

owner's costs.

Escalation and AFUDC were calculated from the estimated distribution of cash

flows during the construction period and OG&E's before-tax weighted average

cost of capital of 8.66%/year. The 37-day tie-in outage for each unit is

assumed to be coordinated with the normal 5-week scheduled outage such that

incremental replacement cost is negligible.

Calculated as % of total capital investment (EPA Air Pollution Control Cost

Manual 6th Ed., page 2-34). Administrative costs are 20% of Fixed O&M

based on S&L experience on other projects.

# TABLE B-4

SOONER STATION UNIT 2

BART COST EVALUATION - DRY FGD (SDA) WORKSHEET

INPUT

Case 1 x 569 MW-gross

PC Boiler

Gross Plant Output (MW-gross) 569

Net Plant Output (MW-net) 524 Adjusted to account for additional auxiliary power.

Approximate Full Load Flue Gas Flow Rate (acfm) 2,276,000

Maximum Heat Input (mmBtu/hr) 5,116

Uncontrolled SO2 Emission Rate (lb/mmBtu) 0.516

Post Dry FGD SO2 Emission Rate (lb/mmBtu) 0.10

Capacity Factor used for Cost Estimates (%) 90%

CAPITAL COSTS Basis

Direct Costs $162,651,300

Indirect Costs $24,045,100

Contingency $29,336,700

Total Plant Cost $216,033,100

Escalation $23,301,500

Allow. for Funds Used During Constr. (AFUDC) $52,960,300

Total Plant Investment (TPI) $292,294,900

Replacement Power Costs $0

Total Capital Requirement (TCR) $292,294,900

Total Capital Investment ($/kW - gross) $514

Capital Recovery Factor 0.1036 See derivation in Table 5.

Annualized Capital Costs

(Capital Recover Factor x Total Capital Investment) $30,281,800

OPERATING COSTS Basis

Operating & Maintenance Costs

Variable O&M Costs

Lime Reagent Cost $1,826,900 118.80 $ Based on maximum heat input, SO2 removal rate (lb/hr), 0.90 stoichiometry,

90% CaO, 90% capacity factor, and $118.80/ton for lime.

Water Cost $95,100 0.49 $ Based on 205,256 lb/hr at full load, 90% capacity factor, and $0.49/1000 gal

FGD Waste Disposal Cost $1,733,500 39.60 $ Based on maximum heat input, SO2 removal rate (lb/hr), 90% capacity factor,

and $39.60/ton on-site disposal cost. Disposal cost only includes FGD byproducts and does not include fly ash.

Bag and Cage Replacement Costs $653,300 3.22 $ Based on the exhaust gas flow through the baghouse, air-to-cloth ratio of 3.5

for pulse jet baghouse, $3.22/ft2 bag cost (including fabric and hangers), 4%

contingency for bag cleaning, and 3 year bag life.

Ash Disposal Costs $0 39.60 $ Assumed no increase in ash disposal with the fabric filter compared to the

existing ESP control system.

Auxiliary Power Cost $5,640,900 83.83 $ Based on auxiliary power requirement of 1% (gross) for DFGD plus 0.5%

(gross) for the baghouse, 90% capacity factor, and $83.83/MWh.

Total Variable O&M Costs $9,949,700

Fixed O&M Costs

Additional Operators per shift 2.0 2 Based on S&L O&M estimate for dry FGD.

Operating Labor $1,004,400 57.33 $ 3 shifts/day, 365 days/year @ 57.33/hour (salary + benefits) .

Supervisor Labor $150,700 15.0% of operating labor. EPA Control Cost Manual, page 2-31

Maintenance Materials $1,753,800 0.6% Based on S&L experience on other FGD projects.

Maintenance Labor $1,104,800 110.0% of operating labor. EPA Control Cost Manual, page 2-31

Total Fixed O&M Cost $4,013,700

Indirect Operating Cost

Property Taxes $1,753,800 0.60%

Insurance $30,600 0.0105%

Administration $802,700 20%

Total Indirect Operating Cost $2,587,100

Total Annual Operating Cost $16,550,500

TOTAL ANNUAL COST

Annualized Capital Cost $30,281,800

Annual Operating Cost $16,550,500

Total Annual Cost $46,832,300 Sooner Unit 2

Based on Sargent & Lundy's conceptual cost estimating system. Direct costs

include equipment, material, and labor; plus spare parts, special tools,

consumables, and freight. Indirect costs include engineering, procurement,

construction management, start-up, commissioning, operator training, and

owner's costs.

Escalation and AFUDC were calculated from the estimated distribution of cash

flows during the construction period and OG&E's before-tax weighted average

cost of capital of 8.66%/year. The 37-day tie-in outage for each unit is

assumed to be coordinated with the normal 5-week scheduled outage such that

incremental replacement cost is negligible.

Calculated as % of total capital investment (EPA Air Pollution Control Cost

Manual 6th Ed., page 2-34). Administrative costs are 20% of Fixed O&M

based on S&L experience on other projects.Table B-5Annual and Levelized Capital ChargesReal Rates Excluding InflationCalendar Year2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025Operating Year1 2 3 4 5 6 7 8 9 10 11 12Tax Depreciation 5.000% 5.000% 5.000% 5.000% 5.000% 5.000% 5.000% 5.000% 5.000% 5.000% 5.000% 5.000%Debt Balance44,300,000 42,085,000 39,870,000 37,655,000 35,440,000 33,225,000 31,010,000 28,795,000 26,580,000 24,365,000 22,150,000 19,935,000Equity Balance55,700,000 52,915,000 50,130,000 47,345,000 44,560,000 41,775,000 38,990,000 36,205,000 33,420,000 30,635,000 27,850,000 25,065,000Levelized ValuesCapital Recovery5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000Debt Return932,578 1,525,649 1,449,366 1,373,084 1,296,801 1,220,519 1,144,237 1,067,954 991,672 915,389 839,107 762,824 686,542Equity Return2,740,413 4,483,171 4,259,012 4,034,854 3,810,695 3,586,537 3,362,378 3,138,220 2,914,061 2,689,902 2,465,744 2,241,585 2,017,427Income Taxes 1,688,180 2,761,772 2,623,684 2,485,595 2,347,506 2,209,418 2,071,329 1,933,241 1,795,152 1,657,063 1,518,975 1,380,886 1,242,798Property Taxes and Insurance 0000000000000Total Capital Charges 10,361,171 13,770,592 13,332,062 12,893,533 12,455,003 12,016,473 11,577,944 11,139,414 10,700,885 10,262,355 9,823,825 9,385,296 8,946,766Annual Rate (% of initial capital investment) 13.77% 13.33% 12.89% 12.46% 12.02% 11.58% 11.14% 10.70% 10.26% 9.82% 9.39% 8.95%Levelized Rate 10.36%Income Statement (Check)Revenue Requirements 13,770,592 13,332,062 12,893,533 12,455,003 12,016,473 11,577,944 11,139,414 10,700,885 10,262,355 9,823,825 9,385,296 8,946,766Property Taxes and Insurance000000000000EBITDA 13,770,592 13,332,062 12,893,533 12,455,003 12,016,473 11,577,944 11,139,414 10,700,885 10,262,355 9,823,825 9,385,296 8,946,766Depreciation 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000EBIT 8,770,592 8,332,062 7,893,533 7,455,003 7,016,473 6,577,944 6,139,414 5,700,885 5,262,355 4,823,825 4,385,296 3,946,766Interest 1,525,649 1,449,366 1,373,084 1,296,801 1,220,519 1,144,237 1,067,954 991,672 915,389 839,107 762,824 686,542EBT 7,244,943 6,882,696 6,520,449 6,158,202 5,795,954 5,433,707 5,071,460 4,709,213 4,346,966 3,984,719 3,622,472 3,260,224Income TaxesCash 2,761,772 2,623,684 2,485,595 2,347,506 2,209,418 2,071,329 1,933,241 1,795,152 1,657,063 1,518,975 1,380,886 1,242,798Deferred000000000000Total 2,761,772 2,623,684 2,485,595 2,347,506 2,209,418 2,071,329 1,933,241 1,795,152 1,657,063 1,518,975 1,380,886 1,242,798Net Income 4,483,171 4,259,012 4,034,854 3,810,695 3,586,537 3,362,378 3,138,220 2,914,061 2,689,902 2,465,744 2,241,585 2,017,427Equity Return (Check) 4,483,171 4,259,012 4,034,854 3,810,695 3,586,537 3,362,378 3,138,220 2,914,061 2,689,902 2,465,744 2,241,585 2,017,427Tax Calculations:EBITDA 13,770,592 13,332,062 12,893,533 12,455,003 12,016,473 11,577,944 11,139,414 10,700,885 10,262,355 9,823,825 9,385,296 8,946,766Tax Depreciation 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000EBIT 8,770,592 8,332,062 7,893,533 7,455,003 7,016,473 6,577,944 6,139,414 5,700,885 5,262,355 4,823,825 4,385,296 3,946,766Interest 1,525,649 1,449,366 1,373,084 1,296,801 1,220,519 1,144,237 1,067,954 991,672 915,389 839,107 762,824 686,542EBT 7,244,943 6,882,696 6,520,449 6,158,202 5,795,954 5,433,707 5,071,460 4,709,213 4,346,966 3,984,719 3,622,472 3,260,224Taxes 2,761,772 2,623,684 2,485,595 2,347,506 2,209,418 2,071,329 1,933,241 1,795,152 1,657,063 1,518,975 1,380,886 1,242,798Rate Base - Year Begin 100,000,000 95,000,000 90,000,000 85,000,000 80,000,000 75,000,000 70,000,000 65,000,000 60,000,000 55,000,000 50,000,000 45,000,000Book Depreciation 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000Deferred Taxes000000000000Net Book 95,000,000Rate Base - Year End 95,000,000 90,000,000 85,000,000 80,000,000 75,000,000 70,000,000 65,000,000 60,000,000 55,000,000 50,000,000 45,000,000 40,000,000Table B-5Annual and Levelized Capital ChargesReal Rates Excluding InflationCalendar YearOperating YearTax DepreciationDebt BalanceEquity BalanceLevelized ValuesCapital Recovery5,000,000Debt Return932,578Equity Return2,740,413Income Taxes 1,688,180Property Taxes and Insurance 0Total Capital Charges 10,361,171Annual Rate (% of initial capital investment)Levelized Rate 10.36%Income Statement (Check)Revenue RequirementsProperty Taxes and InsuranceEBITDADepreciationEBITInterestEBTIncome TaxesCashDeferredTotalNet IncomeEquity Return (Check)Tax Calculations:EBITDATax DepreciationEBITInterestEBTTaxesRate Base - Year BeginBook DepreciationDeferred TaxesNet BookRate Base - Year End2026 2027 2028 2029 2030 2031 2032 203313 14 15 16 17 18 19 205.000% 5.000% 5.000% 5.000% 5.000% 5.000% 5.000% 5.000%17,720,000 15,505,000 13,290,000 11,075,000 8,860,000 6,645,000 4,430,000 2,215,00022,280,000 19,495,000 16,710,000 13,925,000 11,140,000 8,355,000 5,570,000 2,785,0005,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000610,260 533,977 457,695 381,412 305,130 228,847 152,565 76,2821,793,268 1,569,110 1,344,951 1,120,793 896,634 672,476 448,317 224,1591,104,709 966,620 828,532 690,443 552,354 414,266 276,177 138,089000000008,508,237 8,069,707 7,631,178 7,192,648 6,754,118 6,315,589 5,877,059 5,438,5308.51% 8.07% 7.63% 7.19% 6.75% 6.32% 5.88% 5.44%8,508,237 8,069,707 7,631,178 7,192,648 6,754,118 6,315,589 5,877,059 5,438,530000000008,508,237 8,069,707 7,631,178 7,192,648 6,754,118 6,315,589 5,877,059 5,438,5305,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,0003,508,237 3,069,707 2,631,178 2,192,648 1,754,118 1,315,589 877,059 438,530610,260 533,977 457,695 381,412 305,130 228,847 152,565 76,2822,897,977 2,535,730 2,173,483 1,811,236 1,448,989 1,086,741 724,494 362,2471,104,709 966,620 828,532 690,443 552,354 414,266 276,177 138,089000000001,104,709 966,620 828,532 690,443 552,354 414,266 276,177 138,0891,793,268 1,569,110 1,344,951 1,120,793 896,634 672,476 448,317 224,1591,793,268 1,569,110 1,344,951 1,120,793 896,634 672,476 448,317 224,1598,508,237 8,069,707 7,631,178 7,192,648 6,754,118 6,315,589 5,877,059 5,438,5305,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,0003,508,237 3,069,707 2,631,178 2,192,648 1,754,118 1,315,589 877,059 438,530610,260 533,977 457,695 381,412 305,130 228,847 152,565 76,2822,897,977 2,535,730 2,173,483 1,811,236 1,448,989 1,086,741 724,494 362,2471,104,709 966,620 828,532 690,443 552,354 414,266 276,177 138,08940,000,000 35,000,000 30,000,000 25,000,000 20,000,000 15,000,000 10,000,000 5,000,0005,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,000 5,000,0000000000035,000,000 30,000,000 25,000,000 20,000,000 15,000,000 10,000,000 5,000,000 0

# Oklahoma Gas & Electric December 28, 2009

BART Analysis Follow-Up Report (Rev. 1) Project No. 11418-019



# Attachment C

BART Comparison TableOklahoma Gas ElectricSooner and Muskogee StationsBART Analysis Follow-Up WorkBART Cost EvaluationSO2ControlProject No. 11418-019December 28, 2009Technology Dry FGD-SDA/FF Dry FGD-SDA/FF Dry FGD-SDA/FF Dry FGD-SDA/FF Dry FGD-SDA/FF Dry FGD-SDA/FF Dry FGD-SDA/FF Dry FGD-SDA/FF Dry FGD-SDA/FF Dry FGD-SDA/FF Dry FGD-SDA/FF Dry FGD-SDA/FF Dry FGD-SDA/FF Dry FGD-SDA/FFStation MUSKOGEE STATION MUSKOGEE STATION SOONER STATION SOONER STATION GERALD GENTLEMAN GERALD GENTLEMAN WHITE BLUFF WHITE BLUFF BOARDMAN NORTHEASTERN NORTHEASTERN NAUGHTON NAUGHTON NEBRASKA CITYUnit UNIT 4 UNIT 5 UNIT 1 UNIT 2 UNIT 1 UNIT 2 UNIT 1 UNIT 2 UNIT 1 UNIT 3 UNIT 4 UNIT 1 UNIT 2 UNIT 1 RemarksDate December 2009 December 2009 December 2009 December 2009 March 2008 March 2008 August 2008 August 2008 November 2007 May 2008 May 2008December 2007 December 2007 August 2007Rating (gross) MW 572 572 569 569 750 750 850 850 617 493 493 176 234 Northeastern - calculated from $/kW valuesRating (net) MW 527 527 524 524 665 700 844 844 584 470 470 160 210 650Heat Input: mmBtu/hr 5,480 5,480 5,116 5,116 7,393 7,782 9,339 10,221 5,793 4,775 4,775 1,850 2,400 6,776.8Boardman - highest rolling 12 month data - worst caseNaughton - measured by CEMSCapacity Factor % 90% 90% 90% 90% 100% 100% 85% 85% 85% 85% 85% 90% 90% 100%Maximum Hours/year: hours/yr 7,884 7,884 7,884 7,884 8,760 8,760 7,446 7,446 7,446 7,446 7,446 7,884 7,884 8,760Capital Cost Recovery FactorEquipment Life years 20 20 20 20 20 20 40 40 20 20 20 20 20 20Interest Rate % 5.43% 5.43% 5.43% 5.43% 5.25% 5.25% 7.67% 7.67% 7% 8% 8% 7.1% 7.1% 5.0% OG&E - weighted after cost of capital (real)Capital Cost Recovery Factor 0.1036 0.1036 0.1036 0.1036 0.0820 0.0820 0.0809 0.0809 0.0944 0.1019 0.1019 0.0951 0.0951 0.0802Calculated based on equipment life and interest rateOG&E - levelized over 20 years, includes taxes on liability associatedwith including DFGD in OG&E's rate baseEnergy Impact % or MW 1.5% 1.5% 1.5% 1.5% 13 MW 13 MW 11.4 MW 11.4 MW 4,088 kW Not specified in BART Not specified in BART 1.66% or 2.66 MW 1.73% or 3.63 MW 1% or 6 MWFuel Subbituminous coal Subbituminous coal Subbituminous coal Subbituminous coal Subbituminous coal Subbituminous coal Subbituminouscoal Subbituminous coal Low sulfur PRB Western sub-bituminous Western sub-bituminous Subbituminous coal Subbituminous coal Western subbituminous coalFuel Sulfur Content % 0.20 - 0.37 0.20 - 0.37 0.20 - 0.37 0.20 - 0.37 0.7 0.7 0.78 0.73 0.17 - 1.00 0.45 - 0.49 0.45 - 0.49 0.58 or 1.02 0.58or 1.02 0.34Northeastern - calculated based on baseline SO2 emissions (lb/hr) andcoal usage (tpy)White Bluff - based on calculated uncontrolled SO2 emission rate andassumed coal heating value of 8500 Btu/lbNebraska City - based on 0.815 lb SO2/mmBtu, 8400 Btu/lbEMISSIONSBART Baseline Uncontrolled SO2Emission Rate lb/mmBtu 0.507 0.514 0.509 0.516 0.749 0.749 0.915 0.854 0.614 0.900 0.900 1.180 1.180 0.815OG&E - based on 3-year average emission from 2004-2006Gerald Gentleman - maximum 24 hour emissions from 2001-2003 dataWhite Bluff - calculated based on information provided in Table A-1 ofBART ReportBoardman - highest rolling 12 month total betw 2003-2005Naughton - based on average 0.58% sulfur in coalNebraska City - maximum actual 24-hour emissions over 3-yearbaseline periodBART Baseline Annual SO2Emissions ton/year 9,113 9,006 9,394 8,570 24,254 25,531 31,806 32,510 14,902 16,000 16,000 8,624 11,187 24,191 Calculation methods vary.Expected SO2Emission Ratelb/mmBtu 0.100.10 0.10 0.10 0.15 0.15 0.15 0.15 0.15 0.15 0.15 0.15 0.15 0.15Naughton - based on 0.58% sulfur in coalExpected SO2Emissions ton/year 2,160 2,160 2,017 2,017 4,857 5,113 5,215 5,708 3,643 2,720 2,720 1,094 1,419 4,452Calculation methods vary.Expected SO2Emissions Reduction ton/year 6,953 6,846 7,377 6,553 19,397 20,418 26,591 26,802 11,259 13,280 13,280 7,530 9,768 19,739 Gerald Gentleman reduction based on worst case.SO2Removal % 80.3% 80.5% 80.4% 80.6% 80.0% 80.0% 83.6% 82.4% 75.6% 83.0% 83.0% 87.3% 87.3% 81.6%Visibility Improvement - Sum ofClass I AreasΔdv9.8421.904 2.176 1.244Sum of visibility improvements at all surrounding Class I areasGerald Gentleman - only worst case provided - page 47 of BARTWhite Bluff - only worst case provided - page 5-1 of BARTVisibility Improvement - SingleClass I AreasΔdv0.9691.243 1.358 0.437Sum of visibility improvements at all surrounding Class I areasGerald Gentleman - only worst case provided - page 47 of BARTWhite Bluff - only worst case provided - page 5-1 of BARTCOSTSTotal Capital Cost Investment $ 317,193,600 317,193,600 292,294,900 292,294,900 486,188,000 495,404,000 353,448,500 353,448,500 247,293,000 273,350,000 273,350,000 108,995,970 141,244,778 201,660,000White Bluff - includes indirect expenses, escalation, sales tax,continency, AFUDCGerald Gentleman/Naughton - includes contingency, labor premium,EPC premium, boiler reinforcement, sales tax, escalation, contingencyon adders, surcharge and AFUDCCapital Cost per kW (gross) $/kw 555 555 514 514 731 708 419 419 401 555 555 681 673 310Gerald Gentleman/White Bluff/Naughton/Nebraska City - based onMWnAnnual Capital Recovery Costs $/year 32,861,300 32,861,300 30,281,800 30,281,800 38,980,692 41,032,308 51,655,000 51,655,000 23,344,000 27,841,302 27,841,302 10,368,549 13,436,308 16,180,000 Based on capital cost recovery factorAnnual Operating Costs $/year 18,438,900 18,438,900 16,550,500 16,550,500 13,826,000 13,980,000 13,500,000 13,500,000 12,978,000 15,535,100 15,535,100 4,749,236 6,234,767 18,540,000OG&E - includes Fixed O&M, Variable O&M, IndirectsNortheastern - includes Variable O&M, IndirectsGerald Gentleman/White Bluff/Boardman/Naughton - includes FixedO&M, Variable O&MTotal Annual Costs $/year 51,300,200 51,300,200 46,832,300 46,832,300 53,146,692 55,370,308 65,155,000 65,155,000 36,322,000 43,376,402 43,376,402 15,117,785 19,671,075 34,720,000Average Annual Cost Effectiveness $/ton 7,378 7,493 6,348 7,147 2,740 2,712 2,450 2,431 3,226 3,266 3,266 2,008 2,014 1,759Gerald Gentleman effectiveness based on worst case emissions. About$4783 if calculated consistent with OG&E.Naughton - values in BART based on first year cost so doesn't matchthisIncremental ImpairmentImprovement Cost - Sum of Class IAreas $/yr/dv3,690,5107,940,013 9,040,016 27,909,968Calculated based on visibility improvement in all affected Class I areas(not just area with greatest impact)Incremental ImpairmentImprovement Cost - Single Class IArea $/yr/dv37,484,00412,304,899 14,500,042 79,450,801Calculated based on visibility improvement in Class I area with greatestimpactGerald Gentleman - pg 47 of BARTWhite Bluff - pg 5-1 of BART, includes tuning, OFA, LNB, dryscrubbingNaughton - pg 4-12 of BART, includes LNB with OFANebraska City - pg 12 of BART Fact Sheet (NDEQ)1.0501.275 1.170 0.641 3.5874.217 2.440Not Available3.670Not Available82,621,717169,189,000Don't have necessaryΔdv data24,330,187 38,387,131Don't have necessaryΔdv data23,638,36639,260,00080,470,902 80,055,214008_Attachment C_OG&E BART Comparison 12-28-09Page 1 of 2Oklahoma Gas ElectricSooner and Muskogee StationsBART Analysis Follow-Up WorkBART Cost EvaluationSO2ControlProject No. 11418-019December 28, 2009Technology Dry FGD-SDA/FF Dry FGD-SDA/FF Dry FGD-SDA/FF Dry FGD-SDA/FF Dry FGD-SDA/FF Dry FGD-SDA/FF Dry FGD-SDA/FF Dry FGD-SDA/FF Dry FGD-SDA/FF Dry FGD-SDA/FF Dry FGD-SDA/FF Dry FGD-SDA/FF Dry FGD-SDA/FF Dry FGD-SDA/FFStation MUSKOGEE STATION MUSKOGEE STATION SOONER STATION SOONER STATION GERALD GENTLEMAN GERALD GENTLEMAN WHITE BLUFF WHITE BLUFF BOARDMAN NORTHEASTERN NORTHEASTERN NAUGHTON NAUGHTON NEBRASKA CITYUnit UNIT 4 UNIT 5 UNIT 1 UNIT 2 UNIT 1 UNIT 2 UNIT 1 UNIT 2 UNIT 1 UNIT 3 UNIT 4 UNIT 1 UNIT 2 UNIT 1 RemarksANNUAL COSTO&M Costs - TOTAL 14,865,700 14,865,700 13,963,400 13,963,400 13,826,000 13,980,000 13,500,000 13,500,000 12,978,000 4,601,100 4,601,100 4,749,236 6,234,767 18,540,000Fixed O&M - TOTAL$/year4,219,600 4,219,600 4,013,700 4,013,700 3,906,000 3,906,000 3,550,000 3,550,000 4,709,000 0 0 1,894,521 2,432,517 2,120,300Maintenance (Mat + Labor) $/year 3,035,700 3,035,700 2,858,600 2,858,600 2,911,000 2,911,000 Incl. above Incl. above 4,409,000 --- --- Incl.above Incl. above 1,704,300OG&E - 0.6% of PEC, 110% of operating laborWhite Bluff - 0.065% of initial capital costBoardman - 3% of capital cost per yearNebraska City - 1.5% of costOperating (Labor) $/year 1,183,900 1,183,900 1,155,100 1,155,100 995,000 995,000 Incl. above Incl. above 300,000 --- --- Incl. above Incl. above 416,000OG&E - 2 additional operators, includes supervision (15% of labor), 3shifts/day, $57.33/hr salary + benefits (Sooner), $58.76/hr salary +benefits (Muskogee)White Bluff - $40/hr, 16 additional full time staffBoardman - $100,000/yr per personNebraska City - 4 operators, $50/hrVariable O&M - TOTAL$/year10,646,100 10,646,100 9,949,700 9,949,700 9,920,000 10,074,000 9,950,000 9,950,000 8,269,000 4,601,100 4,601,100 2,854,715 3,802,250 8,365,000Lime $/year 1,730,600 1,730,600 1,826,900 1,826,900 7,316,000 7,420,000 Incl. above Incl. above 4,915,000 3,090,000 3,090,000 926,526 1,201,979 2,946,000Muskogee - $105.53/ton limeSooner - $118.80/ton limeGerald Gentleman - $95/ton deliveredWhite Bluff - $107/ton, 1.1 SRBoardman - $132/tonNortheastern - $200/ton limeNaughton - $91.25/ton lime, 1.15 SRNebraska City - $125/ton lime deliveredWater $/year 534,100 534,100 95,100 95,100 483,000 499,000 Incl. above Incl. above 300,000 --- --- 81,874 112,577 ---Muskogee - $2.57/1000 galSooner - $0.49/1000 galGerald Gentleman - $1.00/1000 galWhite Bluff - 1050 gpm per unit, $0.92/1000 gal makeup waterBoardman - 336 gpm, $2/1000 gal makeup waterNaughton - 120 gpm, $1.22/1000 galSolid FGD Waste $/year 1,894,300 1,894,300 1,733,500 1,733,500 1,620,000 1,643,000 Incl. above Incl. above 742,000 --- --- 496,582 644,215 509,000Muskogee - $40.59/ton on-site disposalSooner - $39.60/ton on-ste disposalGerald Gentleman - $5/tonWhite Bluff - $8.58/tonBoardman - $10/tonNaughton - $24.33/tonNebraska City - $9/tonFly Ash Disposal $/year0 0 0 0 --- --- --- --- --- --- --- --- --- ---OG&E - assume no increase compared to current ESP fly ashBags and Cages $/year 675,100 675,100 653,300 653,300 --- --- Incl. above Incl. above 790,000 --- --- 106,648 147,088 360,000Muskogee - $3.31/ft2bag, 3 year bag lifeSooner - $3.22/ft2bag, 3 year bag lifeWhite Bluff - $110/bagBoardman - $100/bag, $50/cageNaughton - $104/bagNebraska City - $100/bag, 5 year bag lifeSales of Allowances $/year0000-4,755,000 -4,744,000 --- --- --- --- --- --- --- ---Auxiliary Power $/year 5,812,000 5,812,000 5,640,900 5,640,900 5,256,000 5,256,000 Incl. above Incl. above 1,522,000 1,511,100 1,511,100 1,243,085 1,696,391 4,550,000Muskogee - $85.92/MWhSooner - $83.83/MWhGerald Gentleman - $45.65/MWh, includes energy charge and capacitychargeWhite Bluff - $47/MWhBoardman/Northeastern/Naughton - $50/MWhNebraska City - $30/MWh, $0.46/MWExtended Outage Power Purc.$/year0000340,000 358,00000000000Gerald Gentleman - $31.90/MWhNebraska City - $30/MWhIndirect Costs$/year3,573,200 3,573,200 2,587,100 2,587,1000000010,934,000 10,934,000 0 0 0Gerald Gentleman/White Bluff/Boardman/Naughton - Not included inestimateProperty Taxes $/year 2,696,100 2,696,100 1,753,800 1,753,800 --- --- --- --- --- 2,733,500 2,733,500 --- --- ---Muskogee - 0.85% of total capital investmentSooner - 0.6% of total capital investmentNortheastern - 1% total capital investmentInsurance $/year 33,200 33,200 30,600 30,600 --- --- --- --- --- 2,733,500 2,733,500 --- --- ---OG&E - 0.0105% of total capital investmentNortheastern- 1% total capital investmentAdministration $/year 843,900 843,900 802,700 802,700 --- --- --- --- --- 5,467,000 5,467,000 --- --- ---OG&E - 20% of fixed O&MNortheastern - 2% total capital investmentFixed Charges on Investment$/year32,861,300 32,861,300 30,281,800 30,281,800 38,980,692 41,032,308 51,655,000 51,655,000 23,344,000 27,841,302 27,841,302 10,368,549 13,436,308 16,180,000Annual Cost$/year51,300,200 51,300,200 46,832,300 46,832,300 53,146,692 55,370,308 65,155,000 65,155,000 36,322,000 43,376,402 43,376,402 15,117,785 19,671,075 34,720,000008_Attachment C_OG&E BART Comparison 12-28-09Page 2 of 2