EHTiRGY ARKANSAS, INC. 

WHITE BLUFF STATION UNITS 1 AND 2 

EVALUATION OF WET VS. DRY FGO TECHNOLOGIES 

SL-009510 

Rev. 3 

October 28, 2008 

Project 12303-004 

Prepared by 

•LundyLLC 

55 East Monroe Street • Chicago, IL 60603 USA • 312-269-2000 
LEGAL NOTICE 

This report was prepared by Sargent & Lundy, L.L.C., hereinafter. referred to as S&L, expressly for Entergy Arkansas, Inc., 

hereinafter referred to as Entergy. Neither S&L nor any person acting on its behalf (a) makes any warranty, express or implied, 

with respect to the use of any information or methods disclosed in this report or (b) assumes any liability with respect to the 

use of any information or methods disclosed in this report. 
Section 

1. INTRODUCTION ............................................................................................................................ 

-

..... 1-1 

l.l PURPOSE ........................................................................................................................................................ l-1 

1.2 STIJDY APPROACH ......................................................................................................................................... l-1 

1.3 STUDY BASIS ................................................................................................................................................. 1-2 

1.3.1 UnitDesign ........................................................................................................................................... l-2 

1.3.2 Economic Infonnation ........................................................................................................................... l-3 

1.3.3 Fuel Information ..................................................................................................................... : .............. l-4 

2. SULFUR REDUCTION TECHNOLOGY EVALUATIONS .......................................................................... 2-1 

2.1 PURPOSE ........................................................................................................................................................ 2-1 

2.2 TECHNOLOGY DESCRJPTIONS ........................................................................................................................ 2-1 

2.2.1 Lime Spray Dry FGD (LSD FGD) ........................................................................................................ 2-2 

2.2.2 Wet Limestone FGD with Forced Oxidation (LSFO FGD) ................................................................ 2-ll 

3 •. COMPARISON OF LSD AND LSFO FGD PROCESSES ......................................................................... 3-1 

3.1 DESIGNBAS!S ................................................................................................................................................ 3-l 

3.2 GENERAL ARRANGEMENT ............................................................................................................................. 3-3 

3.2.1 Lime Spray Dryer (LSD) FGD .............................................................................................................. 3-3 

3.2.2 Wet FGD ............................................................................................................................................... 3-3 

3.3 COMPARISON OF SYSTEJI.I FEATURES ............................................................................................................ 3-4 

3.3.1 AbsorberVessel .................................................................................................................................... J-4 

3.3.2 Chimney ............................................................................................................... ; ................................ 3-5 

3.3.3 3-5 
Section 

3.3.9 Mercury Collection ............................................................................................................................... 3-8 

3.3.1 0 Preliminary C02 Considerations for Dry and Wet FGD ....................................................................... 3-9 

3.4 COMPARISON OF CONSUMABLES AND WASTES .......................................................................................... 3-10 

3.4.1 

3.4.2 

3.4.3 

3.5 

3.5.1 

3.5.2 

3.5J 

3.5.4 

Power Consumption ............................................................................................................................ 3-I 0 

Reagent Consumption ......................................................................................................................... 3-11 

Waste Byproducts ............................................................................................................................... 3-11 

SULFUR REDUCTION TECHNOLOGY COST EVALUA TlON ............................................................................ 3-12 

Capital Cost ....................................... -.................................................................................................. 3-12 

Fixed and Variable Operating Costs ................................................................................................... 3-15 

Preliminary Cost Summary ................................................................................................................. 3-17 

Sensitivity Analyses ............................................................................................................................ 3-18 

3.6 SULFUR REDUCTION TECHNOLOGY CONCLUSIONS .................................................................................... 3-24 
Table 1-l. l\1ajor Economic Parameters ...................................................................................................................................... l-3 

Table 2-l. FGD System Deployment in U.S ............................................................................................................................... 2-1 

Table 3-l. Design Basis Used for Dry FGD vs. Wet FGD. Comparison ..................................................................... ; .............. 3-l 

Table 3-2. Typical PRB Coal S02 Emissions Expe9ted from FGD Teclmology ........................................................................ 3-7 

Table 3-3. FGD System Labor Requirements ........................................................................................................................... J-15 

Table 3-4. O&M Cost Basis (both units combined) .................................................................................................................. 3-I 6 

Table 3.-5. Summary Comparison of Wet and Dry FGD Levelized Costs (yr. 2013) for White Bluff Units l & 2 .................. 3-17 

Figure 2-1. Relationship Between S02 to Dry FGD and S02 Reduction Efficiency .................................................................. 2-3 

Figure 2-2. Typical Dry FGD System ......................................................................................................................................... 2-4 

Figure 2-3. Typical SDA (B&\V) ............................................................................................. , .................................................. Z-8 

Figure 2-4. Typical Pulse Jet Fabric Filter ................................................................................................................................ 2-10 

Figure2-5. Typical Wet Limestone FGD System ..................................................................................................................... 2-15 

Figure 2-6. Typical Ball Mill for Large FGD System ............................................................................................................... 2-16 

Figure 2-7. Typical FGD Scrubber with Absorption Tray ........................................................................................................ Z-18 

Figure 2-8. FGD Scrubber with Open-Spray Tower ................................................................................................................. Z-19 

Figure 2-9 .. Typical Vacuum Belt Filter .................................................................................................................................... 2-22 

Figure 2-I 0. Typical Rotary Drum Vacuum Filter. ........................ : .......................................................................................... 2-23 

Figure 3-l. ImpactofS02 in Fuel on Levelized Cost ............................................................................................................... 3-19 

Figure 3-2. Impact of Rail Delivery on Levelized Cost ............................................................................................................ 3-20 

Figure 3-3. Impact of Two Dry FGD Absorber Modules on Levelized Cost ........................................................................... 3-21 
A. Dry FGD General Arrangement 

B. Wet FGD General Arrangement 

C. Dry FGD Capital Cost Estimate 

D. Wet FGD Capital Cost Estimate 

E. Financial Analysis Summary 
1. 

1.1 PURPOSE 

INTRODUCTION 

The purpose of the study was to select the flue gas desulfurization (FGD) process best suited for application at 

Entergy's White Bluff Station Units 1 and 2. The most commonly used wet and dry FGD processes were evaluated 

relative to one another using a structured methodology to achieve that goal. The study developed conceptual 

designs, order of magnitude cost estimates, and economic analyses of adding wet or dry FGD systems. 

1.2 STUDY APPROACH 

The initial task for the study was to evaluate emission control technologies that might be applied to reduce SOx 

emissions from Entergy's White Bluff Station. The most commonly used wet and dry technologies were identified 

as potential solutions for SOx control for these units based on current configurations. The following is a list of the 

major activities that were performed in the conceptual design of the technologies described in this report. 
Material balances and process flow diagrams were developed to identify how the White Bluff units 

currently operate and how the addition of SOx control technologies would change their operation. 

• Based on the material balances that were developed, preliminary sizing of various emission control 

technology equipment was done for SOx control technologies as well as balance-of-plant (BOP) 

equipment and structures. 

a General arrangement (GA) drawings were prepared for wet FGD and dry FGD to estimate 

approximate quantity of duct material 

• Inputs for specific capital costs for wet FOD and dry FGD were developed by comparison with 

historical vendor budgetarY quotations for each technology implementation. 

o Inputs for O&M costs were developed in parallel with Entergy. A detailed· model projecting 

annualized costs for each unit over a 40-year study period was prepared for wet FGD and dry FGD. 

1.3 STUDY BASIS 

The basic data listed below were used as inputs to the study: 

• Unit Design Information. Unit size, boiler type, capacity factor, heat input, flue gas temperature, 

pressure profiles, and water quality. 

• Economic Information. Real interest rate, escalation rate, replacement energy and capacity 

charges, and process consumables. 

• Fuel Information. Basic fuel properties for Jacob's Ranch Powder River Basin (PRB) coal. 

1.3.1 Unit Design 

S&L initiated its evaluation using the heat input to the boiler of each unit provided by Entergy to generate material 

balances. Heat input to the boiler is a primary parameter used to calculate the quantity of flue gas that would need 

treatment at each White Bluff unit. A team of S&L and Entergy analyzed the various heat input data and concluded 

that 8,950 rnmBtu/hr would be anappropriate heat input for the design of the FGD system. This resulted in 

eccmoimzer modification on Unit 2 

Table 1-1 lists the 
Table 1-1. Major Economic Parameters 

Amortization life, years 

Interest rate for discounting. % 

Commercial service date 

Capacity factor, % 

Debt percentage in capital structure, % 

Preferred stock percentage in capital structure, % 

Equity percentage in capital structure, % 

O&M escalation rate, % 

Debt interest rate, % 

Preferred stock rate,% 

Capital escalation rate, % 

Federal and state tax rate, % 

Equity retum, % 

Annual property taxes and insurance, % 

AFUDC,% 

Tax depreciation schedule 

Auxiliary electric power energy charge, $/MWh 

Ash disposal cost, $/ton 

Operating labor rate, $/hr 

Raw makeup water, $/1000 gal 

Cooling tower blowdown water, $/1000 gal 

$/ton 

40 

8.24 

Sept2013 

72.0 

41.97 

4.44 

53.59 

2.0 

6.34 

5.99% 

3.0 

39.225 

9.90 

0.944 

8.24 

Amortized over 84 months 

47.00 

8.58 

40.00. 

0.92 

0.48 

107.00 
econoniic evaluation for S02 control was assessed at 2 lb S02/mmBtu sulfur and 0.8 lb 

S02/mmBtu operating sulfur as a baseline. A sensitivity analysis was performed for design sulfur levels at 3 lb 

S02/mmBtu (operating at 0.8lb S02/mmBtu) and 5lb SOlmmBtu (operating at 5lb S02/mmBtu) for wet FGD, 

and at 3 Ib S02/mmBtu for dry FGD. Dry FGD would not be competitive at 5 lbs SOlmmBtu. 
2. SULFUR REDUCTION 

2.1 PURPOSE 

EVALUATIONS 

The purpose of the sulfur reduction technology evaluations is to develop a conceptual design for retrofitting a wet 

or dry FGD technology for White Bluff Station, then to compare the economics of each technology, and finally to 

recommend the technology best suited for application. The economics identifY the cost of SOz removal based on a 

net present value (NPV) assessment and normalized cost for $/ton of S02 removed. 

2.2 TECHNOLOGY DESCRIPTIONS 

FGD technology has been applied in the U.S. since the 1960s and, with the nearly 40 years of development, it is 

considered a mature technology. A wide range ofFGD technologies is available. Table 2-llists the various types of 

utiljty power plant FGD installations in the U.S. As shown in this table, wet FGD, with either limestone or lime as 

the reagent, is the most prevalent, with almost 75% of the total flue gas scrubbing capacity. Dry lime FGD, 

typically used when sulfur levels are less than 2 lb S02/mmBtu, is the next most selected technology with over 15% 

of all installations. This section discusses wet limestone FGD and dry lime FGD technology in detaiL 

FGDType 

Wet limestone 

Wet lime 

Dry lime/SDA 

Sodium carbonate 

aqueous carbonate 

Table 2·1. FGD System Deployment In U.S. 

Boiler Units (No.) 

105 

58 

35 

Installed FGD Units (%) 

48 

26 

16 

4.1 

0.5 
2.2.1 lime Spray Dry FGD (LSD .FGD) 

The LSD FGD technology was developed beginning in 1977, to serve users of low-sulfur coal who had to meet a 

requirement of only 70% S02 removal. As the technology's experience grew and matured, it demonstrated much 

higher performance capabilities and now can provide as much as 95% S02 removal in many applications. 

Gradually, it has been adopted by users of medium-sulfur coals, and now is frequently considered for mediumsulfur coals of 3 lb/mmBtu S02 content. Maximum spray dryer absorber (SDA) vessel size had an equivalent 

capability of 150 MW of flue gas in the initial installations, but absorber vessels have grown to an equivalent of 

350 MW of flue gas. 

2.2.1.1 Description of Process 

In an LSD FGD system, flue gas is brought into contact with lime slurry in the SDA vessel. This process can use 

(pulverized) hydrated lime (Ca(OH)2) or (pebble) quicklime (CaO); however, large quantities of lime are 

consumed, so the more economical quicklime generally is used at large utility installations. CaO must be hydrated 

before use. This hydration occurs in a slaker, where lime is mixed with water and slurry of fine lime particles 

results. The chemical reaction is as follows: 

SOz absorption takes place in an SDA. Calcium reacts with the S02 to form waste solids sulfate (CaS04) and sulfite 

(CaS03), as shown in the following chemical reaction scheme. About one~third of the waste is sulfate and twothirds is sulfite. 

GaO + HzO <-+ Ca(OH)z 

Ca(OH)z + S02 +H20--> CaS03 • 1/2H20 + 3/zHzO 
The S02 removal efficiencies of the existing LSD systems range from 85-95%, depending on the SDA inlet S02 

concentration. The effectiveness of spray dryer technology decreases with fuel sulfur levels above 3 lb SOiMMBtu 

(as shown in Figure 2-1 ). At higher sulfur levels, the amount of sorbent required for removal of S02 from the gas 

stream increases substantially, and the economics generally favor wet scrubbing. The curve in Figure 2-1 represents 

the amount of S02 reduction expected for an LSD system with a baghouse. This is a general guideline for 

application of LSD technology, and is derived from S&L's in-house database on the technology's performance, 

which is based on guarantee data provided from various suppliers ofFGD systems. 

Figure Relationship Between S02 to Dry FGD and S02 Reduction Efficiency 

100 r-----r----'-----...,----,..-...,-------, 

2 3 4 5 6 

The primary operating parameters that affect S02 removal using LSD FGD are: 

" The lime stoichiometric ratio (SR) varies with the amount of S02 in the SDA in the flue gas. The 

SR can range from 1.2lb-mole lime/Ib-mole ofS02 at the inlet to 1.6lb-mole Hme/lb-mole ofS02 

at the inlet. An SR value of 1.2 is applicable for inlet S02 values of less than 1 Ib SOimmBtu, 

while the larger value is for inlet SOz values greater than 2 lb SOz/mmBtu. 

The flue gas temperature into the SDA is important. Temperatures above 300°F allow more water 

and lime to be injected with the flue gas. This increases so2 removal and the utilization of the 

lime. If the inlet temperature is below 300°F, the efficiency will be reduced. 

LSD several 
• Reagent handling and preparation 

Absorption in a spray dryer absorber 

0 Particulate collection 

• Flue gas system and stack 

Waste handling system and disposal 

Figure 2-2. Typical Dry FGD System 

Optional Ffyash 

Pre-Collection 

Head Tank 

.---

1 

I 

I 

I 

I 

I 

I 

I 

I I 

I 

Baghouse 

-il-·-----, 

l 

I 

Recycle I 

Solids I 

I 

i 

I 

I 

I I 

I 
2.2.1.2.1 Reagent Handling and Preparation 

Lime is conveyed by truck, barge, or rail to an enclosed storage silo. A detailed study will be performed if dry 

technology is selected for White Bluff. Utilities usually require a storage capacity of at least seven days, depending 

on the delivery method and lime source proximity. For delivery by truck, the maximum recommended silo height 

should be 120 feet if the truck's onboard blowers are used for unloading. However, the lime supplier should verify 

the capability of the truck blowers to transport the lime. If the silo needs to be taller than 120 feet, a permanent 

pressurized blower system needs to be installed. 

For lime delivered by truck, silos are usually sized for a 7- to 14-day capacity, 7 days if the lim.e source is close to 

the power plant and 14 days if a distant source is used. A 14-day capacity silo with truck delivery is used for this 

study. The bulk storage silo feeds directly into the lime-slaking train and no transfer system is need~ d. Delivery by 

truck may not allow for competitive bidding to supply lime if one source is significantly closer to the plant. Rail 

delivecy allows for more sources to be considered. 

For delivery by rail, larger quantities of lime are stored on site. Durations of 14 days or more have been the norm 

for most utilities. The strategy for selecting the storage capacity depends on the railroad used and the number of rail 

cars that the site can handle. Some utilities receive an entire unit train of!ime, while others receive one-third or onehalf of a unit train. 

The lime silo has either a bin activator or a fluidizer to promote lime flow ability. A rotacy feeder in series with a 

volumetric feeder supplies the lime to a slaker, where the pebble lime, CaO, is hydrated to Ca(OH)2• The slaking 

process is exothermic and the heat release helps to shatter the lime into fme particles. The slaked lime slurry then 

flows to a storage tank where it is held until it is needed by the atomization process. 

Truck-delivered lime will remain in large pieces when it enters the slaker, but lime pneumatically transferred 

several times to be in a fonn. The 

detention reaction. 
The. vessel is also fitted with a classifier section that separates the sufficiently slaked particles from the coarse lime 

particles. The larger particles are recycled back to the slaker vessel while grit material, consisting of inert material 

as well as uncalcined limestone and magnesium oxide particles, is removed. 

An attrition slaker is comprised of a vessel and a set of agitators with a common axle, which produce a counter 

current flow that induces lime particle interaction in order to speed up the slaking process. The main difference · 

between detention slakers and attrition slakers is the degree of solids interaction. Attrition slakers may also be 

mated to grinding or grit removal equipment for impurity removal. 

In a ball mill slaker, pebble lime and water is added continuously to a horizontal vessel that contains grinding 

media, which allows grinding and slaking to occur simultaneously. The product flows through a classifier that 

separates the final slaked product from the coarse material, which is then fed back to the ball mill to be processed 

further. Due to the grinding function of the ball mill slaker, a grit removal system is not necessary. 

A vertimill slaker operates in a similar fashion to the ball mill slaker, with the exception that the vessel is vertically 

oriented and includes a double pitch helix that agitates the grinding media. A classifier system is also used to 

' 

recycle the coarse product back to the grinding vessel. Similarly to the ball mill slaker, the vertimill does not 

require a grft removal system. 

The advantage of the ball mill type slakers is the less stringent requirements for quicklime size and slaking water 

quality, as well as eliminating the need for the grit removal system. Although a slaker type has not been specified, 

the horizontal ball mill was used in the cost evaluation for the slaking process. Reagent preparation with two 100% 

slurry trains is used for this study. Each train is made up of a solo, feeder, and slaker. The slurry is stored in a 

dedicated storage tank. 

2.2.1.2.2 Recycle Ash 

the SDA several times lime corlsumptlOll. The 
high SOz removal efficiencies. There is residual activity left in the lime after it has been passed through the system 

once; therefore, it is re-introduced to gain additional lime utilization. 

2.2.1.2.3 Spray Dryer Absorber 

The SDA is a vertical, open chamber with concurrent contact between the flue gas and lime slurry (Figure 2-3). The 

slurry is injected at the top of the tower using either a rotary atomizer or a dual-fluid nozzle, which produces fine 

droplets to absorb the S02• In the process of evaporating the droplets, the flue gas is cooled from the absorber inlet 

temperatureof approximate;y 3l8°F to an outlet temperature of l60-180°F depending on the adiabatic saturation 

temperature. The actual outlet temperature is chosen based on the optimum reagent utilization, the flue gas 

saturation temperature, and the required S02 removal efficiency. The absorber typically will be operated at 30°F 

above the gas saturation temperature (also known as the approach temperature) to prevent solids deposition on the 

walls of the absorber and to avoid moisture condensing in the particulate collector. The residence time of the cooled 

flue gas in the SDA should be at least 10 seconds to ensure high removal efficiencies. Most current designs utilize a 

residence time of over 12 seconds. 
Figure 2-3. Typical SDA (B&W) 

: Fiu darry 

; drop~ts 

The slurry comes into contact with the flue gas inside the SDA vessel, and the slurry should be dry before it 

contacts the SDA walL Corrosion of the SDA walls can occur if a high-chloride coal is fired; however, this is rarely 

a concern with Powder River Basin (PRB) coals. Because the flue gas exiting the SDA typically is held at 30°F 

above saturation, carbon steel ductwork is adequate and alloys are not needed. Therefore, the downstream ducts, 

baghouse, and chimney liner can all be made of carbon steel. Precautions should be taken around access doors and 

other penetrations where cool ambient air can leak into the duct and form cool spots in the SDA where acids in the 

flue gases can condense. In these locations, it is common to spray a coating over the carbon steel for a minimal 

amount of corrosion protection. 

The dry absorber does have some capability to remove mercury from the flue gas, but the mercury must be in the 

ionic form to be absorbed. PRB coal is low in chlorides and the mercury from firing PRB is not in the ionic form, 

EntergyArlmnsas WBI-2_Dry vs Wet FGD Study ReY 3 Issued 

10·28-08 

Project I 2303-004 Luncfy '~ 
but rather, is mostly in the elemental form. However, dry FGD has potential to remove significant amounts of 

mercury if the elemental form can be converted to the ionic form in the flue gas. Coal additives have completed this 

conversion of elemental to ionic mercury. Coal additives could be a halogen, such as bromine or iodine. Tests to 

date have shown that another halogen, chloride, is the least effective of these compounds, but bromine or iodine 

have been effective in utility tests. Dry FGD has the potential to capture 70-80% of the mercury in the PRB coal if 

additives are used. Additives are believed to be less expensive than powdered-activated carbon. 

The SDA vessel will have a discharge hopper on the bottom to allow any small material buildup on the walls to 

slide down and to be removed. 

2.2.1.2.4 Particulate Collector 

The SDA typically is located after the air heater outlet, and needs to be followed by a particulate collector, which is 

almost always a baghouse. Dry FGD systems usually are coupled with a fabric filter baghouse because S02 removal 

efficiencies up to 95% are then possible. A substantial amount of the S02 is removed in _the baghouse because the 

lime rich product and fly ash remain on the surface of the bags and the flue gas is pulled through tbis layer of lime. 

This close contact betlveen the flue gas and lime accounts for another I 0-15% of the overall S02 removaL 

A pulse jet baghouse (Figure 2-4) with an air-to-cloth ratio of 3.5 ft!min (J.l rn/min) typically is used doWnstream 

of a dry-FGD system on coal-fired units. The baghouse is provided with a spare compartment for routine 

maintenance. The waste is pneumatically conveyed to a waste storage silo with typically a 3-day storage capacity. 

The baghouse or ESP casing must be well insulated to contain the heat witbin the casing and to keep the interior 

skin temperature about 30°F above saturation. 
Figure 2-4. Typical Pulse Jet Fabric Filter 

Source: Wheelabrator 

2.2.1.2.5 Waste Handling 

The waste collected in the baghouse is pneumatically transported to a storage silo. A portion of the waste is 

recycled to increase the reagent utilization. The dry FGD waste is mixed in a pug mill with water to prevent dusting 

if being transported in open top (tarp covering) style trucks for disposal. Sale of the waste products from dry 

scrubbing is rare and the material is typically sent to a landfill. Dry FGD waste contains reacted calcium compounds 

EntergyArkansas WB1·2_Dlyvs Wet FGDStudy Rev 3 Issued 

10..28..()8 

Project I 2303-004 
and unreacted lime, Ca(OH)2• The waste has pozzolanic properties and when water is mixed with the waste, it cures into 

a low-grade concrete. Because this solid product is impermeable, disposal in a landfill is a safe practice. One plant in the 

U.S. fonns pellets with the waste and sells them as gravel for fill or sub-base. 

2.2.1.2.6 Flue Gas System and Stack 

Ducts downstream of the SDA can be fabricated out of carbon steel, but the ducts and expansion joints must be 

insulated with insulation pillows to contain the heat in the flue gas and maintain the gas at about 30°F above 

saturation. The chimney liner typically is insulated but its exit can have cool ambient air pulled down into the top of 

the liner under certain atmospheric conditions. The inside of a carbon steel liner is typically coated in the top 

50 feet to negate any impact of sulfurous acid condensation. 

2.2.1.2.7 StaJ71n~ 

The conceptllal design economic analysis includes 16 additional people for the O&M of the new dry FGD system, 

as summarized below. A detailed listing of the staffing cost can be found in Section 3.5.2. 

• Lime unloading will require a crew to move the rail cars or trucks through the unloader and to 

connect the equipment to each hopper. This crew will work one shift between five and seven days 

per week to unload the cars. 

e FGD process operations will require an opera~or to walk down the process equipment and check 

for malfunctions. The rotary atomizers will need to be switched on a 60- to 90-day cycle to clean · 

their atomization wheels and perform other maintenance. Dual-fluid atomizers will be cleaned 

weekly. 

• Waste loading to truck or rail cars will continue as currently practiced for fly ash. Disposal of 

larger amounts of solids will require additional time for these activities. 

Wet Limestone FGD with Forced Oxidation (LSFO FGD) 
Wet limestone FGD systems have been operating in utility applications since the 1960s. Early generations of wet 

FGD technology had internal scaling problems that caused the absorbers to be brought off line for cleaning every 

few months. To achieve acceptable availability for multi-unit use, many smaller absorbers were installed on one 

. unit so that one absorber could be taken off line for cleaning and repair while the others handled 100% of the flue 

gas. Over the years, utilities learned to combat scaling problems using two technological advances. The first 

advance was to use forced oxidation of the precipitate in the absorber reaction tank, which effectively addressed the 

problem of scaling in the absorber. The second advance was to introduce most of the water needed by the process 

into the mist eliminators of theLSFO FGD. The water required for mist eliminator wash typically has less than 

1000 mg/L total dissolved solids and less than 50% saturated calcium sulfates. Service water from a well or lake 

usually is acceptable for this application. Cooling tower blowdown and ash pond water are not acceptable. Good 

water quality significantly reduces the plugging of the mist eliminators. 

These advances solved many of the chemistry problems and made the process much less complex. State-of-the-art 

wet FGD systems do not experience scaling issues. Spare absorber modules are rarely installed and single absorbers 

are routinely installed on large units. 

Early-generation wet FGD technology experienced significant problems with corrosion of the absorber metals. 

Absorbers were coated with rubber or flake glass lined to avoid corrosion, but these systems required very high 

maintenance. To avoid high maintenance and to minimize the corrosion in the absorbers, alloys later were used 

inside the absorbers. The alloys ranged from 317 L to C-276, depending on the level of chlorides in the absorber 

recycle slurry. Utilities have identified the reasons for the corrosion and have learned to make better selections of 

alloys within the absorber. Developers of alloys have also responded with newer; more corrosion-resistant and 

lower-cost alloys. Utilities have also learned that the chloride level is the most important parameter to monitor. 

Modem wet FGD systems use blowdown water from the absorber to control the chloride concentration in the 

scrubber to within the capabilities of the materials of construction. These advances have allowed utilities to 

some value in 
transported. Gypsum can be washed to remove fly ash and! or chlorides so it can be. used for wallboard 

manufacturing, or as a soil additive in agricultural areas. Waste solids that are land-filled are dense and inert. Issues 

such as leaching and ground water contamination are not a concern for land-filling gypsum. It has been shown that 

most gypsum is land-filled, but if either of the other two uses is applicable, the gypsum can be sold or given ·away, 

thereby avoiding the land-filling costs. 

Wet LSFO FGD systems are the predominant wet FGD technology used by utilities. It is most applicable for 

medium- to high-sulfur coals where removal of 95-99% of the inlet S02 can be achieved. LSFO FGD is also 

effective on low-sulfur coals where it can remove 93-95% of the inlet S02• Wet FGD systems are limited to a 

minimum outlet concentration of between 0.03-0.041b/mmBtu of S02• Driving the concentration lower is not costeffective. 

In summary, the basic wet limestone scrubbing process is now reasonably simple and well-established. Recent 

advances in the wet limestone FGD process include design changes to promote S02 absorption at high removal 

rates. After experiencing poor reliability in the first generation of this technology during the 1970s and early 1980s, 

wet limestone ·scrubber technology has matured and is now capable of meeting availability levels of 99%. 

Additionally, gypsum can now be recovered as a salable byproduct where feasible. Extensive operating experience 

has increased industry confidence in designing larger, more reliable limestone scrubber modules. Single absorbers 

treating 1,000 MW of the flue gas are in operation. In 1994, wet limestone scrubbers were used on 70 units, (35, 100 

MWe of the total scrubbing capacity). Today, there are more than 100 operating limestone scrubbers, with more 

under construction to meet new emission criteria. LSFO FGD is a viable technology for any coal-fired boiler. 

2.2.2.1 Description of Process 

In an LSFO FGD system, flue gas containing S02 is brought into contact with limestone-slurry droplets and the 

so2 is absorbed into the water Within the droplet, the and calcium from the limestone (CaC03) react to 
CaC03 + 802 -+ CaS03 + C02 

CaS03 + 1/ 20 2 (flue gas) + 2H20 -> CaS04 • 2H20 

Before the use of forced oxidation, the bisulfite ions would be recirculated through the absorber and would scaleout on the internals of the vessel. Force oxidizing the bisulfite ions turns them into a precipitate in the reaction tank 

so it cannot scale out onto the internals of the absorber. 

Most of the solids are recycled through the absorber several times, and a small bleed stream is sent to a dewatering 

step. Vacuum drnm or belt filters are used to concentrate the bleed slurry stream to 85-92% solids. The water from· 

this process is returned to the FGD process. lf salable-grade gypsum is to be produced, the solids are washed with 

dean water to remove the chlorides. This water is also returned to the process. 

The absorber is very effective at removing hydrochloric acid (HCl) from the flue gas. The HCI reacts with the 

limestone and stays in solution as chloride ions. Chloride ions are very corrosive to ferrous-based metals, thus 

carbon steel is not an acceptable metal for construction of the absorbers. For chloride concentrations of 15,000 ppm 

or less, a new stainless steel alloy is being used, alloy 2205. This alloy is used for the lowest-capital cost absorber. 

All the internals can be made from this alloy, including supports, recycle grids, trays, and reaction tanks. In most 

cases, recycle piping is not made of alloy, but of fiber-reinforced plastic (FRP) with a wear-resistant coating. PRB 

coal has minimal chlorides to be collected, but if a moderate-sulfur coal with higher chlorides is to be considered, a 

higher quality alloy could be used at a greater cost. 

2.2.2.2 Discussion of Features 

A typical wet FGD system comprises several subsystems, including: 

<» Limestone handling 

" Limestone slurry preparation 

in the fuel. These 
Figure 2·5. Typical Wet Limestone FGD System 

2.2.2.2.1 Limestone Handling System 

Crushed limestone (typically, 3/4 x 0-inch or 1.91 x 0-cm) received at a plant typically is delivered by bottomdump railcars or trucks and is unloaded into a receiving hopper: It is assumed that limestone will be delivered by 

truck at White Bluff. The trucks will unload the limestone to an outdoor, uncovered limestone storage pile. There 

are two storage piles - one active pile (30 days' storage) that feeds the reclaim hopper and one inactive pile that is 

used only if limestone deliveries are interrupted. A bulldozer is then used to move limestone between the two piles. 

Reclaim of the limestone from the bottom of the active storage pile is by underground reclaim hoppers equipped 

with vibrating belt feeders. The feeders supply the reclaim conveyor, whlch carries the limestone to the day. silos 

located immediatCiy above the wet grinding ball mills. Rain water around the active and inactive limestone piles is 

handled by installing a drain ditch around the piles where the water can be collected. 

EntergyArl<ansas WBI ·2_Dry \'S Wet FGD Study Rev 3 Issued 

10·28..{)8. 

Project 12303..Q04 
2.2.2.2.2 Limestone Slurry Preparation System 

Preparation of the limestone slurry involves wet grinding the limestone in a horizontal ball mill. The limestone 

received on site is similar to gravel. The limestone day bins and gravimetric feeders deliver the limestone to a 

2 x 100%-capacity ball mill system for both units. Figure 2-6 shows typical ball mills. One ball mill runs continuously, 

while the second ball mill provides 100% spare capability. The ball mill grinds the limestone and discharges it into a 

small receiving tank that is then pumped through hydroclone classifiers. The limestone that is 95% less than 325-mesh is 

ready for use and sent to a storage tank, but the larger particles are retwned to the ball mills for further grinding and size 

reduction. Two I 00"/o-capaeity classification pumps are used to ensure high reliability of the classification system. 

Process makeup water or recycle water is added to the ball mills to produce 70% by weight solids slurry. The slurry 

classification process produces 30% by weight solids slurry, which is stored up to 24 hours until it is fed as reagent 

makeup into an absorber. The slurry conceiltrations are measured using nuclear density meters. The. ball mills are 

rubber-lined to reduce erosion of the mill internals. Steel balls are added as needed to replenish the balls in the mill. 

Since White Bluff is located in a warmer climate, the reagent preparation system will not need to be in a building to 

protect the equipment and staff from the weather. 

Figure 2-6. Typical Ball Mill for Large FGD System 

2.2.2,2.3 Absorber System 

Figure 2-7 depicts a typical absorber (B&W) utilizing a vertical spray/tray tower concept, with counter-current 

contact between the flue gas and scrubber slurry. This counter-current type is the most commonly used absorber in 

the utility industry. Other absorber types available include jet bubbling reactor and co current/count~r-current flow. 

EntergyArkansas WBI-2_Dry vs Wet FGD Study Rev 3 Issued 

10-28-08 

Project 12303-004 Lundy''' 

I 
First-generation absorbers relied on packing to provide the mass transfer, but in conventional absorbers the mass 

transfer occurs in the tray and in the open-spray zone .. Some vendors rely on the sprays to provide the mass transfer, 

while other vendors use the tray for mass transfer. 

The tray is a horizontal perforated plate with a two-foot-tall egg crate on top that causes the slurry to form a 

several-inch froth layer on top of the tray. Flue gas that is forced up through the tray, comes in contact with this 

froth, and then gives up itS 802 to the slurry. When a tray is present, most of the sulfur collection occurs at the tray 

and the spray levelsdo less of the sulfur collection. One advantage of the tray is that it smoothes the upward flow 

of flue gas, evenly distributing the flow so the entire absorber area is used for sulfur collection. Including a tray in 

the design allows reduction of the liquid-to-gas (LIG) ratio. B&W and Siemens both use trays. 

An open-spray tower is a se~ond popular absorber design. This type of absorber relies on several spray levels to 

create enough droplets. to carry out the necessary mass transfer. The LIG ratio for an open-spray tower is greater 

than for a tray, and the uniform downward flow of slurry is responsible for spreading the upward flow of flue gas 

for uniform flow. Open-spray towers use a baffle around the inside circumference of the absorber to prevent gas 

flow from bypassing the spray zone. Designers of this type of absorber point out that there are no internals in the 

absorber to corrode or scale. Alstom and Babcock Power Inc. both use open-spray towers. Figure 2-8 depicts 

Alstom's open-spray tower. 
Figure 2·7. Typical FGD Scrubber with Absorption Tray 

EntergyArkansas WBJ-2_Dry vs Wet FGD Study Rev 3 Issued 

10-28-08 

Project 1230~004 Source: Babcock & Wflcox 

Luncfy!\t 
Figure 2-8. FGD Scrubber with Open.Spray Tower 

After falling through the spray zone, the slurry accumulates in the reaction tank. Modem absorbers integrate the 

reaction tank. into the bottom of the absorber, whereas earlier-generation FGD systems used a separate external 

tank. The tanks hold the slurry for at least 15 hours (solids residence time) to allow the reaction between the 

limestone and S~ to complete and let gypsum crystal grow above 20 microns. The reaction tank is agitated to keep 

the solids in suspension and air is forced into the reaction tank to force-oxidize the CaS03 in the slurry. Fresh 

limestone is added to the tank so there is an excess of calcium and all sulfur is reacted. The retention time in the 

reaction tank allows all the sulfite to react with oxygen so the solution is not supersaturated with sulfite and bisulfite ions. Without the forced oxidation step, the absorber would be susceptible to scaling and would need 

frequent cleanings. With forced oxidation, there is no need to clean the absorbers of scale that could disrupt 

absorber performance. 

Ente:rgyAik:msas WBI·2_Dry vs Wet FGD Study Rev 3 Issued 

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Project 12303-004 J,..unc:ty••< 
The forced oxidation air is supplied by a set of compressors in the absorber building. Compressed air is injected 

below the reaction tank agitators through a sparger network to achieve greater than 99% oxidation of calcium 

sulfite (CaS03) to calcium sulfate (CaS04). A 3:1 stoichiometric ratio (SR) of oxygen to S02 is used to size these 

air compressors. 

From the reaction tank the slurry is pumped back into the absorber's spray zone. High-horsepower pumps are used 

for the recycle. Conventional absorbers have at least one spare recycle pump to provide high availability of the 

absorber. Slurry is sprayed through several headers that span the diameter of the absorber. Slurry is abrasive and the 

spray nozzles are erosion-resistant. Occasionally, a piece of scale can become lodged in the spray nozzle, causing 

pluggage or sending the flow in an unpredicted direction, so many smaller nozzles are used. The spray header 

material is either alloy or FRP, with the latter gaining more use in recent absorber installations . 

. ; ~ Above the spray zone is the mist eliminator, which removes the entrained slurry droplets so they do not exit the 

absorber and create particulate emissions leaving the chimney. The mist eliminator must be washed with clean 

water to remove limestone deposits. Early-generation wet FGD systems attempted to use cooling tower blowdown 

or other wastewater, but this caused plugging of the mist eliminators .. When high-quality water is used, plugging is 

virtually eliminated. 

The absorber must be constructed of materials that resist corrosion, erosion, and scaling. To reduce corrosion when 

firing PRB coal, an A-2205 SS alloy can be used so long as the chlorides in the recycle slurry are maintained 

between 8,000-15,000 ppm with typical chloride less than 12,000 ppm. PRB coals usually have a minimal amount 

of chloride so this is usually the highest alloy that needs to be considered. The absorber inlet duct is an especially 

corrosive environment because of the wet/dry interface that occurs when some of the slurry deposits on the inlet 

floor of the duct. To combat this highly corrosive environment, the inlet duct is made of C-276 from the absorber 

back about 10 feet. The outlet duct to the chimney is also a location subject to corrosion and either C-276 or FRP is 

used for this duct. FRP would be used if the unit is an FRP liner in the chimney. If FRP is riot used in the 

a 

interfere with the process. 
Because wet FGD systems absorb HCI from the flue gas at 99% efficiency, a minimal amount is released to the 

environment. Wet FGD systems do not collect S03 very effectively, and they can cause S03 to condense as very 

fine droplets that can result in a blue plume immediately after the flue gas exits the stack if the concentration of S03 

exceeds 7-10 ppm. Fortunately, when PRB coal is fired, the amount ofS03 in the flue gas is minimal and a colored 

plume will not result. Installation of an SCR will increase S03 concentrations. 

The wet absorber does have some capability to remove mercury from the flue gas, but the mercury must be in the 

ionic form to be absorbed. PRB coal is low in chlorides and the mercury from firing PRB is not in the ionic form, 

but rather, is mostly in the elemental form. However, a wet FGD has potential to remove significant amounts of 

mercury if the elemental form can be converted to the ionic form in the flue gas. Coal additives added to the coal 

have completed this conversion of elemental to ionic mercury. Coal additives could be a halogen, such as bromine 

or iodine. Tests to date have shown that another halogen; chloride, is the least effective "Of these-compounds, but 

bromine or iodine have been effective in utility tests. A wet FGD has the potential to capture 70-80% of the 

mercury in the PRB coal if additives are used. Additives are believed to be less expensive than powdered-activated 

carbon. 

2.2.2.2.4 Primary and Secondary Dewatering and Byproduct Handling Systems 

The bleed stream from the reaction tank is pumped to a set ofbydroclones for primary dewatering. The hydrodone 

overflow is recycled back into the scrubber. The hydroclone underflow, contairung 50% solids, is fed to a belt filter 

for secondary dewatering, as shown in Figure 2-9. Belt filters are designed to achieve 90% solids in the gypsum 

byproduct to meet the requirements of gypsum buyers, if the gypsum is being sold to the wallboard industry. The 

gypsum cake is washed with fresh water on the belt filters to remove any residual chlorides to a level typically less 

than 100 ppm by weight chloride in the dry solids. The wash water used for gypsum cake washing should not 

contain chlorides more than 50 ppm if the product is intended for sale to a wallboard manufacturer. The filtrate 

from the horizontal belt filter returned to the process. If gypsum is in a landfill, a lower~capital-cost 

shown in 2-10. 
I 

J 

I 

I· 

I 

Figure 2-9. Typical Vacuum Belt Filter 

Slurry feed 

EntergyArkansas WBI-2_Dry vs Wet FGD Srudy Rev 3lssued 

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Project I 2303..()()4 I , 

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'Lundy''\' 
! 

: 

I 

I 

l 

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Figure 2-10~ Typical Rotary Drum Vacuum Filter 

As mentioned earlier, chlorides are absorbed from the flue gas and they concentrate in the recycle slurry solution. A 

small blowdown stream may be required to remove chlorides and other contaminants from the process. If the 

gypsum is not being sold, washing the filter cake is not required and chloride-control of the dewatering process is 

significantly less complicated. Less costly rotary drum vacuum filters can be u5ed if the gypswn is to be sent to a 

landfill, although a water treatment faCility will still be necessary to treat the blowdown from the absorber. Landfill 

disposal requirements are very site-specific, and depend on parameters such as the actual chemical makeup of the 

gypswn waste product, local climate, and soil conditions. 

Dewatered gypsum from the belt filter is deposited on a collecting conveyor, then conveyed out of the dewatering 

building and stacked on the ·ground. The gypsum is then loaded into trucks with a front-end loader and then hauled 

away. 

Gypsum also bas potential for reuse, e.g., feedstock for wallboard manufacturing. For this to be an attractive form 

of reuse, a large quantity of gypsum is needed. Utilities with 500 MW gross or more of capacity and firing high.~ 

sulfur coal are likely candidates to pursue wallboard manufacturing options. These type plants would also need to 

be relatively ncar markets that would be in demand of large quantities of wallboard, such as urban areas. Gypsum 

can also be used for agricultural purposes, as a soil additive, or as an additive to concrete. Gypsum's inert nature 

renders it viable for land-filling. 

EntergyArkansas WBI·2_Dry vs Wer FGD Srudy Rev )Issued 

J0-28..08 

Project 12303.{)()4 ' Lundy'" 
2.2.2.2.5 Staffing 

The conceptual design economic analysis includes 21 additional people for the O&M of the new wet FGD system, 

as summarized below. A discussion of the staffing costs can be found in Section 3.5.2 . 

., Limestone unloading will require a couple of personnel to move the limestone into the reclaim 

hopper underneath the active pile and to move the rail cars through the unloader. 

o FGD process operations will require an operator to walk down the process equipment and check 

for malfunctions. Typical maintenance activities for the FGD system would involve the. 

conveyors, ball mills, including changing of ball load, recycle slurry pumps, mist eliminator, spray 

headers and nozzles, booster fans, hydroclones, rotary dru~ filters, and waste conveyors . 

., Lab Technician/System Engineer for chemistry monitoring . 

., Waste loading to trucks will require additional operators. The larger amounts of solids requiring 

disposal will also require more time for this activity. 
3. COMPARISON 

3.1 DESIGN BASIS 

AND FGD 

S&L developed and issued to Entergy separate design basis documents for dry and wet FGD, as summarized in 

Table 3-1. 

Table 3-1. Design Basis Used for Dry FGD vs. Wet FGD. Comparison 

Parameter 

NetMW 

Heat input to boiler; mmBtu/hr 

Coal type 

Coal composition 

Carbon 

Hydrogen 

Nitrogen 

Sulfur 

Oxygen 

Moisture 

Chlorine 

Ash 

HHV, Btu/lb 

Flue gas flow, acfm 

Day bin 

Value 

844 each 

8,950 

100% PRB 

49.92% 

3.58% 

0.67% 

0.87% (2.0 lb S02/mmBtu) 

12.01% 

27.72% 

0.02% 

5.2% 

8,725 

3,685,000 at 318"F 

95% 

hours 
Parameter 

Absorber 

Booster fans 

Waste recycling 

Waste storage 

Stack 

Reagent, ton/hr 

Trucks per day 

Waste, ton/hr 

Ttucks per day 

Makeup water, gpm 

Wet FGD..Specific 

Liquid-to-gas ratio 

Limestone stoichiometric. ratio 

Limestone quality 

Limestone storage pile 

Day bin storage 

Ball mills 

Absorber 

Booster fans 

Primary dewatering 

Secondary dewatering 

Stack 

Reagent, ton/hr 

Value 

3 x 33%, carbon steel (each unit) 

2 x 50% (each unit) 

1 x 100% (each unit) 

3 days, 1 x 100% (each unit) 

No modifications 

8.4 (both units) 

10 

17.8 (both units) 

22 

2,100 (both units) 

80 

1.03 

90% CaCOa 

30 days (both units) 

24 hours {both units) 

2 x 100% (both units) 

1 x 100%, alloy 2205 (each unit) 

2 x 50% (each unit) 

Hydrocyclones, 2 x 100% (both units) 

Drum filters, 2 x 100% (both units) 

35-foot diameter, 1003-foot height FRP liner (each unit) 

11.7 (both units) 
3.2 GENERAL ARRANGEMENT 

3.2.1 Lime Spray Dryer (LSD) FGD 

S&L developed general arrangement (GA) drawing of major equipment and structures for the White Bluff Station 

dry FGD system. The GA drawing for the LSD FGD is presented as Appendix A. This GA was the preferred 

arrangement primarily because it minimized the ductwork length between the SDA outlet and the baghouse inlet, 

and eliminated turns or elevation changes in the duct. This offers long-term maintenance benefits because the 

shorter duct length results in minimizing the amount of solids that can drop out and accumulate on the duct floor. 

Implementing the GA will require demolishing White Bluff Station's Ash Handling Maintenance Building due to 

the location of the new spray dryers, and building a new building directly north of the FGD system. 

Two lime silos are arranged near the lime preparation area am~ are sufficiently sized to store the reagent for 14 days 

of operation. The lime in the bulk storage silo will be pneumatically blown to a day silo located in the reagent 

preparation area. Because the reagent preparation area is located near the SDAs, lime slurr:Y will need to be pumped 

only a short distance to the top of each SDA. 

The recycle portion· of the dry FGD process will be local to the prospective unit and not included in the combined 

reagent preparation area. A set of silos will be located near the baghouse inlet to receive baghouse recycle fly ash 

that will be slurried and re-injected into the SDAs. 

Two new booster lD fans will be placed in series with the existing lD fans. The booster fans will be sized to handle 

the additional pressure drop associated with the dry FGD. 

3.2.2 Wet FGD 

S&L developed GA drawings of major equipment and structures for the White Bluff Station wet FGD system. 

Appendix B is a GA the and structures for a wet LSFO FGD system. 
The absorber vessel for each unit is located to the cast of the unit. The duet located after t

g 

location of the tie-ins for the wet FGD for each unit. A rather short duct is added to divert the flow to each absorber 

area. Two new booster ID fans are then shown to feed a single absorber, which then feeds a single new chimney per 

unit. The old ehimney could be demolished or capped and left in place. If this is the case, routine maintenance will 

need to be performed on the chimney for structural integrity and potential deterioration. The arrangement for the 

wet FGD flue gas path is relatively straightforward. 

The dewatering system is common for both units and located north of the units. This location allows easy access for 

the trucks that will haul away ihe gypsum byproduct 

The existing ESP and fly ash system will remain as is and are unaffected by the retrofit of the wet FGD, because the 

wet FGD is downstream of the ESP. 

3.3 COMPARISON OF SYSTEM FEATURES 

3.3.1 Absorber Vessel 

The wet FGD system has an advantage in that a single absorber can be used at each linit at White Bluff. Single 

absorbers have been built for up to 1,000 MW of flue gas. A single absorber per unit greatly reduces the capital cost 

of a wet scrubber. 

A dry FGD system uses a spray dryer. For White Bluff Station three SDAs were considered per unit. Some utilities 

are starting with SDAs that could be sized for one-half of a White Bluff Station unit's flow. The feasibility of a 

SDA vessel of this large a size has not yet been proven. 

A single vessel allows the system to be designed without dampers. This is a significant cost saving and reduces 

O&M of dampers and auxiliary power for heated seal air. With two or more dampers will be included to 

Without the of a two- or three-absorber 
15,000 ppm are expected inside of the vessel. This alloy is a fairly new material that only recently is being used on 

FGD systems. Additionally, the wet/dry interface at the wet absorber's inlet will need alloy C-276 to protect this 

very corrosive location. In general, wet FGD materials are more expensive than dry FGD materials. 

The single-absorber vessel represents cost savings in wet FGD but the carbon steel materials of construction are an 

advantage for dry FGD. Both of these features have been-considered in the capital cost estimates completed for 

these two technologies. 

3.3.2 Chimney 

Wet FGD technology typically is installed benveen the outlet of the existing particulate collector and chimney. 

However, most retrofit wet lin_Iestone FGD units are unable to use the existing chimney, as the chimney typicallywould have been designed rofhotflue·gas at bet\veen 70-100 fi/sec exit velocities: To accommodate saturated flue· 

gas from a wet limestone FGD system, wet stacks typically are designed using a corrosion-resistant flue with a 

design gas velocity of 55 fi/sec or less. Adding a new chimney for each unit is deemed more cost-efficient as 

opposed to a common chimney with dual flues for both units, due to complications with duct work aroun.d the 

existing coal conveyor. Using one chimney for each unit will minimize expensive ductwork downstream of the 

absorber that typically requires either FRP- or C-276-clad liners to avoid corrosion. The capital cost estimate 

includes two new FRP-lined chinmeys. Reuse of the existing chimney is often a significant cost advantage for a dry 

FGD system. 

3.3.3 Chemistry 

The wet FGD system has a more complex system operating chemistry to monitor than the dry FGD. The wet FGD 

scrubber vessel liquor chloride content must be monitored to prevent absorber corrosion. The pH level must also be 

monitored to maintain high S02 removal efficiency and minimum corrosion. Scale oxidation rate is monitored to avoid 

scrubber and the constant, it to have an that 
two. Generally, a dry FGD system needs to be monitored more carefully from hour to hour, whereas, a wet FGD system 

opetates at a fairly steady pace. 

3.3.4 Chloride Slowdown 

The wet FGD system absorbs HCl from the flue gas and it is concentrated in the recyele water. The absorber can be 

designed for up to 15,000 ppm of chloride without corrosion problems. To limit chloride buildup, some water is blown 

down to remove chlorides. This water is often mixed with other plant water and allowed to discharge with other 

effluents. If commercial-grade gypsum is to be produced, there will be a wastewater stream off the belt filters that will 

have to be treated. If the product is to be land-filled, the wastewater will be discharged with the blowdown stream and 

will have to be treated as well. Based on the chloride level of200 ppm in the fuel and the chloride level np to 390 ppm in 

the blowdown water, there will be always be a blowdown from the wet FGD. The cost estimate therefore includes the 

wastewater treatment facility. 

Dry FGD does not have a wastewater blowdown stream or a wastewater treatment facility. 

3.3.5 Water Consumption 

System design calculations for wet and dry FGD systems at White Bluff Station predict that a wet FGD system would 

consume 1,260 gallons per minute (gpm) per uuit and the dry FGD system 1,050 gpm per unit, while burning 2lb 

SO:JmmBtu coal. The wet FGD system is estimated to have a waste discharge of 43 gpm per unit that would need to be 

ehemical1y treated to precipit;te out the metals for the base case. This 43-gpm level can be reduced, if necessary and is 

based on land-filling the gypsum. The dry FGD system does not have a wastewater discharge. 

3.3.6 S02 Control 

The FGD systems considered have unique capabilities to remove S02. As previously a wet FGD is known to 

FGD Q"dPYYI<! can achieve lower 
Table 3-2. Typical PRB Coal S02 Emissions Expected from FGD Technology 

Parameter Lime SDAFGD WetLSFOFGD 

Lowest achievable S02 emission (lb/mmBtu) 0.06-0.08 0.03-0.06 

Achievable 24-hour average (lb/mmBtu) 0.12-0.15 0.09-0.10 

Achievable 30-day average {lb/mmBtu) 0.10-0.12 0.07-0.10 

Achievable annual average (lb/mmBtu) 0.08-0.10 0.06-0.08 

3.3.7 Particulate Control 

Particulate control is a pivotal issue in selecting dry or wet FGD systems because, although it is not a necessary part 

of the wet FGD process, it is integral to a dry FGD system. Recently, wet FGD suppliers have provided particulate 

control guarantees as low as 0.015 lb/mmBtu with inlet particulate up to 0.12 lb/mmBtu. Since White Bluff Station 

is equipped with an existing ESP, the particulate enlissions would be maintained with wet FGD or lowered to 

O.OISlb/mmBtu. The baghouse for the dry FGD would be designed to lower the emission to O.Ol2lb/mmBtu 

giving an advantage to the dry FGD system over the wet FGD. 

As for condensable particulate matter, the wet FGD system promotes the condensation of sulfuric acid mist more 

than the dry system due to the lower outlet temperature. For either system the condensable particulate is found 

assuming 0.8% of the S02 in the boiler is converted to S03, the outlet of the stack would contain 2 ppm of S03, or 

63 lblhr; converting this emission to a sulfuric acid mist basis gives 77 lblhr of condensable particulate. Even with 

the addition of SCR on the unit, the additional conversion of S02 to S03 would result in 7 ppm of S03, or 289lblhr 

of sulfuric acid mist. This level is greater than the current operating pennit limit of 261 lblhr of condensable 

particulate matter, a permit revision would then be necessary once an SCR is in place. 

Fugitive emissions and additional emission points from ancillary equipment must be taken into account when 

choosing an FGD technology. The wet FGD process limestone and gypsum piles, which adds a 
Similarly to the fugitive emission sources, several transfer and emission point sources are added to each FGD 

system. Storage silos, common to both types ofFGD systems, contribute to particulate emissions, but are controlled 

by vent filters by up to 95%. The reactant preparation building, common to both types of FGD, also contributes to 

particulate matter emissions, but ventilation fans reduce these emissions by up to 75%. Lastly, the wet FGD system 

conveys limestone and gypsum byproduct via belt conveyors, which add potential emission points, but dust 

suppression system are available that can reduce these emissions by up to 75%. 

3.3.8 S03 Removal 

Sulfur trioxide (S03), which condenses to sulfuric acid aerosols in an FGD system, is removed efficiently (greater 

than 90%) with a dry FGD/baghouse equipment combination. Wet scrubbers have less affinity for acid mist and 

they typically capture between 25-50% of sulfuric acid aerosols, according to FGD suppliers. Alkali injection (i.e., 

Trona) upstream of a particulate collection system or even the addition of a wet ESP would be required for a wet 

limestone FGD system to achieve the same level of acid mist removal as the inherent removal in a dry FGD system. 

S&L would expect alkali injection to be considered BACT for acid mist. The emission of sulfuric acid mist, if 

above a threshold value of 7-10 ppm at the stack, may result in a pale blue plume Visible after the water vapor 

plume dissipates. White Bluff Station fires PRB coal, which has low S03 concentrations, so a colored plume is not 

expected. 

The current 803 emission from the White Bluff units is estimated to be 3 ppmvd (@3%02) or less with 2lb 

SOimmBtu PRB fuel (assuming 0.6% oxidation in boiler, 25% removal across air heater, and 2 ppm across ESP). 

With wet FGD, the outlet concentration will be approximately 2 ppmvd (@3% 0 2) with 25% removal efficiency 

and with dry FGD, the concentration will be less than 1 ppmvd (@3%02). The advantage of a dry FGD could be 

realized only in the case of a future SCR system. If the future SCR system is designed with 3% SOrto-S03 

oxidation (only with PRB coal), the emissions from the wet FGD could be as high as 9-12 ppmvd S03, compared to 

dry FGD, which could be limited to 2 
the fuel additive injection to convert elemental mercmy into ionic mercury will be required. ACI inject 

halogenated activated carbon before the SDA and up to 90% removal is with a 2 lb/mmacffeed rate. 

Similar to dry FGD, wet FGD can remove oxidized mercury. Unfortunately, mercury in PRB coal usually is in the 

elemental state, which is not as easily removed. To use the wet FGD capability to remove mercury, a halogenated 

(chloride or bromide based) fuel additive can be used that converts the elemental mercmy to the oxidized form. The 

mercmy can then be captured by the wet FGD. An overall removal of 70..80% is possible with wet FGD. To 

achieve higher removal efficiency, an additional activated carbon injection system ahead of the ESP or ahead of a 

polishing baghouse may be required. 

The technology of converting elemental mercmy to oxidized mercury still· needs to mature. However, if this 

technology develops as anticipa~ed, an ACI system may not be required if wet FGD systems arc installed on the 

White Bluffunits. 

On February 8, 2008, the U.S. Circuit Court of Appeals for the District of Columbia rejected the strategy of 

regulating mercury emissions through a cap-and-trade program and therefore vacated the Clean Air Mercury Ru1e 

(CAMR). The rejection of the cap-and-trade regulation will compel the U.S. EPA to develop a new set of standards 

for electric generating units to reduce mercury. It is uncertain when this will occur, however it is believed it will 

take several years. 

3.3.10 Preliminary COa Considerations for Dry and Wet FGD 

The area needed for the C02 removal system (physical footprint) for a wet FGD is somewhat smaller than for a dry 

FGD. This is primarily due to the fact that C02 removal on a unit equipped with a dry FGD requires adding a wet 

chimney since the gas has to be further cooled before entering the CO:z equipment. The C02 equipment requires a 

pre-scrubber/cooler to obtain S02 emissions below 10 ppm, which is the maximum inlet S02 concentration into a 

absorber to reduce sulfur contamination. Therefore treatment to remove additional would be needed on 
A wet FGD system produces more C02 than a dry FGD due to the chemical reactions with calcium carbonate 

(CaC03), the release of one mole of C02 is accomplished for every mole of S02 absorbed. The C02 is formed 

through the decomposition of limestone {CaC03) to form calcium sulfite (CaS03). C02 makes up approximately 

44% by weight of the limestone, depending on purity. Therefore for each ton of limestone consumed, there will be 

approximately 0.44 tons of C02 formed. With the operating case of an inlet concentration of 0.8 lb SOz/nunBtu a 

total of 11.7 tph oflimestone would be consumed for both units combined, which translates to 5.1 tph ofCOz, from 

both units. This totals 45,100 additional tons of C02 per year from White Bluff. To put this in perspective, the 

combustion-based C02 emissions for the White Bluff units total slightly over 16 million tons per year combined. 

Therefore, the C02 produced from the presence of CaC03 is very minimal when compared with the C02 emissions 

from the combustion of coaL The combustion of the coal produces roughly 940 tph per unit at White Bluff Station, 

while the added C02 produced in the wet FGD system is less than 1% of this total. 

The dry FGD uses lime, which has no added production of C02 in its use. Noteworthy is that lime is a product of 

limestone and even though dry FGD is not emitting C02, the kiln that is producing the lime (CaO) generates C02 

from the gas driven off the limestone when heating it to 2000-2400°F. One mole of C02 is driven off for each mole of limestone consumed; this results in more C02 being produced in forming lime than it does in using limestone as 

a reagent. Additionally, there is fuel consumed to produce the heat, which emits C02, and the motors that drive the 

mechanical portion of the process require energy; this drives the C02 emitted from the life cycle of lime to a level 

exceeding limestone, but the release point is moved to the lime supplier and Entergy would not be concerned with 

this emission. 

3.4 COMPARISON OF CONSUMABLES AND WASTES 

3.4.1 Power Consumption 

The O&M costs presented herein account for power consumption. The wet FGD consumes 8.9 MW and the booster 
3.4.2 Reagent Consumption 

Dry FGD systems use a more expensive reagent (quicklime or hydrated lime) than limestone-based FGD systems 

(more dollars per mole of calcium), and the reagent must be stored in a steel or concrete silo. Limestone can be 

stored outdoors in a pile and moisture is not a problem in its reactivity. The wet FGD system consumes 5.9 tph of 

reagent per unit, while the dry FGD system consumes 4.2 tph of reagent per unit. 

Reagent utilization for a dry FGD system is poorer compared to a wet limestone system meaning the reagent SR for 

a dry FGDsystem is higher than the SR for a wet limestone FGD system (on the same basis) to achieve comparable 

S01 removal (more moles of calcium per mole of sulfur dioxide). The cost of reagent is provided for in the O&M 

costs presented herein. 

3~4.3 

Waste Byproducts 

For dry FGD systems, the resulting byproducts are in dry form and can be handled with conventional pneumatic fly 

ash handling equipment. The dry FGD waste containing CaS03 • 0.5H20, CaS04 • 2H20, Ca(OH)2, and fly ash is 

land-filled similarly to waste containing just fly ash. This material is stable in the landfill and could be fixated with 

fly ash to make it less permeable. Wet FGD waste is 99% CaS04• 2H20, which would be land-filled. Again, the wet 

FGD waste can be fixated with fly ash and addition oflime to make it less permeable. Currently, most utilities can 

dispose both of these wastes in a lined landfill. 

Additionally, there is no liquid waste from a dry FGD system, whereas wet FGD systems typically produce a liquid 

waste stream, depending on the disposition of the byproduct. In the caSe of the White Bluff Station, a wastewater 

treatment plant may be required to treat the liquid waste prior to discharge due to the high chloride level of the 

makeup water from cooling tower blowdown. The wastewater treatment plant produces a small volume of solid 

waste, rich in heavy metals (including oxidized mercury) that can be disposed of in a typical landfill. A dry FGD 

can provide an outlet for process wastewater from other parts of the power plant. Since the dry FGD system 

OYilroauct. The 
3.5 SULFUR REDUCTION TECHNOLOGY COST EVALUATION 

3.5.1 Capital Cost 

S&L's capital cost estimates for a retrofit dry FGD and a retrofit wet FGD system for White Bluff Units I and 2 

encompass the equipment, material, labor, and all other required direct costs. The underlying assumption is that the 

project will be implemented on a multiple contracting basis. The capital costs are based on burning 100% PRB 

coaL The capital cost estimates provided herein are "total plant cost," and include the following: 

• Equipment and material 

" Installation labor 

" lndirect field costs and BOP engineering 

• Contingency (20%) 

• Erection contractor profit (at 10% of material and labor) 

• General and administration (at 5% of material and labor) 

., Freight 

o Allowance for funds used during construction (AFUDC [8.24%]) 

" Sales/use tax (not included) 

" Startup and commissioning 

" Spare parts ( 1% of equipment) 

License fees and royalties are not expected for the proposed control strategies. The capital costs are summarized in 

Appendixes C and D for dry and wet FGD, respectively. 

The capital cost estimates for installing dry FGD or wet FGD at White Bluff Units l and 2 include the following: 
" Slurry storage tank with 24 hours of capacity 

" Slurry feed pumps for each absorber 

" Slurry pipe loops for the Units l and 2 absorbers 

3.5;1.1.2 Dry FGD 

" Lime delivered by truck 

o Silos for long term storage, 14 days 

" Ball mill slakers 

" Slurry storage tank with 24 hours of capacity 

" Feed slurry pumps 

3.5.1.2 Absorber Systf!ms 

3.5.1.2.1 ~etFGlJ 

" 1 x 100% absorber for each unit 

• Spray headers along with one slurry recycle pump for each header 

" Oxidation air compressors for each unit 

• 2205 alloy absorber, wet/dry interface- solid C-276, and outlet duct C-276 clad 

3.5.1.2.2 Dry FGD 

o 3 x 33.3% absorbers for Unit I and 3 x 33.3% absorbers for Unit 2 

" Pulse-jet baghouse, 3.5: I air-to-cloth ratio, one for each absorber 

3.5.1.3 Flue Gas Systems 

3.5.1.3.1 Wet FGlJ 

• Inlet (carbon steel) and outlet 
3.5.1.3.2 Dry FGD 

• Inlet and outlet ducts (carbon steel) 

e 2 x 50% booster induced draft (ID) fans for each tmit 

3.5.1.4 Byproduct/Waste Handling 

3.5.1.4.1 WetFGD 

e Hydroclone separator for each unit 

• Sluny pipeline from each absorber 

• Rotary drum vacuum filters 

• Stackout conveyors 

e W astcwater treatment - minimal 

3.5.1.4.2 Dry FGD 

• Waste recycle system 

• Waste conveying system 

• Silos with 3 days of waste storage capacity 

• Dustless unloaders 

3.5.1.5 Electrical/Instrumentation 

3.5.1.5.1 Wet/Dry FGD 

• Transformers 

• Switchgear 

• Instrumentation 

3.5.1.6 Makeup Water Supply/Wastewater Treatment 
3.5.1.7 Balance~of-Plant 

3.5.1.7.1 Wet/Dry FGD 

"' Compressor for instrument air, service air 

"' Foundations, steel, demolition, relocations, new storage warehouse, etc. 

"' Roads, storm drainage, etc. 

3.5.2 Fixed and Variable Operating Costs 

The fixed O&M costs determined for this study consist of operating labor, maintenance labor, maintenance 

material, and administrative labor. The wet .FGD will require an estimated 21 additional full-time operators and 

,. 

maintenance personnel and the dry FGD will require an estimated 16 additional full-time operators and 

maintenance personnel for eac"[ shift fqr both units. 

The operators would be looking afteF the absorber system, reagent preparation, and byproduct/waste system. The 

limestone receiving/handling will also require an operator. The existing shift supervisor's will handle added 

responsibility for the FGD system. Due to existing work load on the plant chemist, an additional lab technician will 

be added for the .FGD system. 

S&L's estimated staffing levels for White Bluff are as shown in Table 3-3. 

Table 3-3. FGD System Labor Requirements 

Staff 

Reagent unloading 

Absorber 

Dewatering/reagent preparation 

Gypsum handling 

1-l<>•r'\!rloltlu ash hnncrillru' 

OryFGD 

2 

10 

0 

0 

WetFGD 

2 

10 

5 

2 
Annual maintenance material and labor costs shown herein have. been estimated based on teclmology 

p

g 

experience in the U.S. The annual maintenance cost includes maintenance material for various subsystems and the 

labor required to perform the maintenance. The annual maintenance material and labor is 0.07% and 0.065% of the 

initiai equipment cost in the capital cost estimate for wet and dry FGD respectively. 

Variable O&M costs determined for each application include the cost of consumables, including reagent (lime or 

limestone), byproduct management, water, and power requirements. These costs have been calculated based on the 

capacity factors provided by Entergy. 

The O&M cost basis with 0.8lb SOimrnBtu as operating sulfur is shown in Table 3-4: 

Table 3-4. O&M Cost Basis (both units combined) 

Parameter WetFGO DryFGO Cost($) 

Limestone, tlh 11.7 0 38.00 $/ton 

Lime, tlh 0 8.4 107.00 $/ton 

Waste disposal, tlh 22.6 17.8 8.58 $/ton 

Auxiliary power, MWH 28.0 22.8 47.00 $/MWH 

Water, gpm 2,522 2,100 0.92 $/1000 gal 

Bag replacement 0 Every 3 years 110 per bag 

The following basis was used to calculate net present value (NPV): 

• Evaluation period - 40 years 

• Discount rate - 8.24% 

• Capital cost escalation rate- 3.0% 

• O&M cost escalation rate - 2.0% 
Also note that for the wet LSFO FGD and dry FGD, reagent cost and byproduct management cost a!e at 95% SOz 

removal. Wet FGD is capable of98% S02 removal, but the system comparison is based on 95% as the compliance 

with SlP requires the emission limit of 0.15 lb S02/mmBtu. 

Auxiliary power costs developed reflect the additional power requirements associated with operation of the new 

booster ID fans as well as the estimated power consumption for the absorber, reagent preparation, and byproduct 

handling areas. 

3.5.3 Preliminary Cost Summary 

Based on the economic parameters- the total capital cost, fixed O&M cost, and variable O&M cost- a fmancial 

model was developed to calculate the NPV and leveliz~d annualized cost to determine a low-cost solution. The 

model.inputand resultS for the base case are presented i!l Appendix E, which s~arizes a comparison of wet and 

dry FGD installation costs for two units. 

Table 3·5. Summary Comparison of Wet and Dry FGD Levellzed Costs (yr. 2013} for White Bluff Units 1 & 2 

WetFGD- DryFGDWith 

Cost Parameter Limestone Bag house 

Capital cost, M$ ($/kW) 744.8 (441) 706.9 (419) 

Fixed O&M cost, M$/yr ($/kW-yr) 8.4 (4.95) 7.1 (4.22) 

Variable O&M cost, M$/yr {$/MWh) 17.4 (1.58) 19.9 (1.81) 

Total O&M cost, M$/yr 25.8 27.0 

NPV,M$ 1,484 1,449 

Differential, M$ 35 0 

Annualized cost, M$/yr 113.8 111.1 

Differential, M$/yr 2.7 0 
3.5.4 Sensitivity Analyses 

Sensitivity analyses were perfonned with the following key parameters: 

• Evaluate impact of burning higher-sulfur fuels- 3 !b SO:/mmBtu and 5 lbs SOimmBtu. 

• Eva1uate impact of! ow-cost reagent delivery by train. <~~ Evaluate impact of two-absorber module design for dry FGD. 

• Evaluate impact of mercury control with ACI for future Hg-MACT. 

.. Impact of SCR- related to sulfuric acid control. 

3.5.4.1 Evaluate Impact of Burning Higher-Sulfur Fuels- 3 lb S02/mmBtu and Sib S02/mmBtu 

The economic analysis was performed with a variation in the fuel levels of S02 subjected to scrubbing. Figure 3-1 

suffimarizes the impact due'to 'the changes in so2 operating levels. 
Figure 3·1. Impact of S02 In Fuel on levelized Cost 

170~~~~~~~~~~~~======~.------------------------------------------------------, Des. S02 lbfmmBtu 2.0 3.0 5.0 

Oper. S021b/mmBtu 0.8 0.8 5.0 

100~--------------------------------------~----------------------------------------~--------------------------------~ 

0 2 3 4 5 6 

S02, lb/mmBtu 

The base case comparison for 2lb SOz/mmBtu (operation at 0.8lb SOz/mmBtu) indicates that the dry FGD would 

cost approximately LO% lower cost than wet FGD. The main difference is due to the cost differential between lime 

and limestone. The annual differential in O&M cost due to reagent cost of more than $3.4 million negates the 

higher capital cost for wet FGD. The differential is trigher at 3 lb/mmBtu coal predominantly due to somewhat 

higher cost associated with capital for wet FGD system. Again, the O&M cost was based on 0.8 lb SOz/mmBtu. 
cost of rail delivery is lower than $10 million, the reagent cost saving due to lower

per

unit cost could be justified 

with rail delivery. The results are shown in Figure 3-2. 

Figure 3-2. Impact of Rail Delivery on Levelized Cost 

1M ~~~~==~==~~~~~========;---~-------------------------------------------------, 

[)<)s.. S02 lblmmBtu 2Jl 3.0 5.0 

Oper. 502 lb/mmBtu 0.8 0.8 5.0 

150 

140 ~ :e 

!130 ·-. -- -. --. .--.. 

! 

] 

110 . ---·-·· 

155.60 

WetFGO 

100~----------------------~----------------------------------------------~-J 

0 2 3 4 5 6 

S02, lb/mmBtu 

3.5.4.3 Evaluate Impact of Two-Absorber Module for FGD 

The dry FGD system is based on the use of three absorber modules. Alstom htid proposed two modules on units 

with a similar gas flow in the past. However, B&W and Siemens had utilized three modules. The use of two 
Figure 3-3. Impact of Two Dry FGD Absorber Modules on levelized Cost ~ ::e 140 ~ 0 ~ 130 

j 

.. 

.. 

110 ---- --- ------ ------- _______ ..._ __ ----------- ---------------------------------------------- ---------------------------

•10'7.08 ~108.22 

,..,...... . OryFGO 

II. 1'0.:>.21 

100~----------------------~------------------------------------------------~ 

0 2 3 4 5 

S02, lb/mmE!tu 

By lowering the capital cost for dry FGD by 7%, the annualized cost differential reduces to 2% from 6.5% still 

favoring wet FGD. However, if the sulfur level drops to approximately 1.5 lb SO:JmmBtu, the dry FGD becomes 

cost-competitive. 

3.5.4.4 Evaluate Impact of Mercury Control with ACI for Future Hg-MACT 

and FGD PRB 
achieved (similar to regulations in Illinois), by ACI ahead of the ESP for wet FGD, the sensitivity is as presented in 

Figure 3-4. 

Figure 3-4. Impact of Mercury Control with ACI for Future Hg-MACT on levefized Cost 

170 Des. S021bfmmBtu 2.0 3.0 5.0 

150 

::;; 140 

u 

.., 

130 

j 

Oper. S02 lbfmmBtu 0.8 0.8 5.0 

.. 

... 

---

.. 

• 126.59 

100 0 2 3 4 5 6 

S02, lbfmmBtu 

ACI ahead of the ESP raises the evaluated cost significantly for the wet FGD system, rendering dry FGD a low-cost 

solution below 2 and 3 !b S02/rnmBtu fuel (operating at 0.8 lb/mmBtu PRB coal). However, if ACI has a major 

pertbnma11ce, a CORP A V may be required. The sensitivity of adding CORP AC to wet FGD is 

shmvn in 
Figure 3

5. Impact o

y 

COHPAC Baghouse for Wet FGD to Meet Future Hg·MACT 

170~~~~~~~~~~~======~~---------------------------------------------------------------------, Des. 502 lb/mmBtu 2.0 3.0 5.0 

,160 

Oper. S021b/mmBtu 0.8 0.8 5.0 

Rr.££GO ~)%CI EtA!lsori?.~IJf!l!niMJ!!fmroACEL ··-- . 

Wet FGO • ACI at COHPAC Inlet (1.51blmmACF) 

5lb/mmBtu do not require ACI 

B11a.az 

WetFGO 

110 -·-··-"··-·-· --.. ----·-·--··--·--------------·--·-------------·-----

100~. 

------------------------~----------~----------~----------~----------~ 

0 2 3 4 5 

502, lb/mmBtu 

The differential between dry and wet FGD increases significantly if wet FGD requires the additional baghouse, 

rendering dry FGD even more economical. 

3.5.4.5 Evaluate Impact of SCR - Related to Sulfuric Acid Control 

The base dry and wet FGD system designs are based on the use of high-sulfur PRB coal. The dry system will have 

wet the level of 
dry FGD system installed on 3 lb/mmBtu fuel will not 

q

y 

j

S03 control is required, the emissions will have to be lowered to similar levels as dry FGD, which could be lower 

than 5 ppmvd (@3%01). The Trona requirement was estimated to achieve this level without any credit for S03 

capture by the wet FGD. 

The injection of Trona required to control S03 eliminates the cost advantage of wet FGD over dry FGD up to 3 lb 

SOJmmBtu fuel. The results can be seen in Figure 3-6. 

Figure 3-6. Impact of 503 Control with Trona Injection for 

Future SCR Resulting in Increased Sulfuric Acid Emission 

180~~~~==~=;;=~~~========~--------------------------------~ 

Des. 502 lb/mmBtu 2.0 3.0 5.0 

Oper. S02 lblmmBtu 0.8 0.8 5.0 

170 2;·3;-amt5ilnrulfurwatf00wl!trequtnr563-con1rot .. · 

with trona injection if fired with Bitumonous co·al 

160+------------------------

!>. 150 ~ ..r 

8 (.) 140 

, 

1l ~ ...I 130 

120 

below Jlb 

DryFGD 

175.11 
sensitivities associated with reagent cost, PM 2.5, or mercury regulations. Dry FGD is the low

cost tec

gy 

through most of the sensitivities. Dry FGD becomes even more attractive below 3ib/mmBtu fuel under the 

following scenarios: 

I. The capital cost can be reduced by 7% with the use of two modules in lieu of the three modules anticipated 

in the base case design. 

2. The Hg-MACT regulation requiring 90% reduction while burning PRB coal would give dry FGD a cost 

advantage. 

3. If the operating sulfur is lower than 1.2 lb/mmBtu, the dry FGD becomes cost-competitive with wet FGD 

due to reduced operating cost for lime as a reagent 

SCR system and particulate .emissions systems installations have no significant impact on the selection of 

technology as long as current permit limits are maintained. The dry FGD system will have an advantage over the 

wefFGD system if the condensable emission rate is further· lowered from the existing level of265lb/hr (718lblhr ... 

total- 453lblhr filterable) or 0.03 Ib/mmBtu. If all the emission is assumed to be sulfuric acid, it will be equal to 

approximately 10 ppmvd (@ 3% 0 2). With the installation of either FGD for 2 lb SOz/mmBtu fuel, the sulfuric aCid 

emission rate will be lower than the current allowable limit. The wet FGD system designed for bituminous coal 

with 2, 3 and 5 lb/mmBtu will require an additional alkali injection system, whereas the dry FGD system installed 

on 2 and 3 Ib/mmBtu fuel will not require any additional alkali injection. The impact of future S03 control ahnost 

eliminates the cost advantage of wet FGD. 

The wet FGD system will have an advantage over dry FGD in the case of C02 emission control as it is capable of 

lowering the S02 concentration slightly better than the dry FGD. However, both systems will require some sort of 

pre-scrubbing, which will result in somewhat higher operating cost for the C02 scrubbing installed on the dry FGD. 
APPENDIX 

Dry FGD General Arrangement 

............ ~ ... 

-. ............ 

-

.... --.~ 
APPENDIX B 

Wet FGD General Arrangement 

APPENDIX C 

Dry FGD Capital Cost Estimate 
TOTAL TOTAL TOTAL 

ACCT.NO. DESCRIPTION EQUIPMENT COST MATERIAl COST LABOR COST TOTAL COST 

101 UNIT 1 ABSORBER AREA 24,000,000 1,362,000 14,400,000 39,762,000 

102 UNIT 2 ABSORBER AREA 24,000,000 1,362,000 14,400,000 39,762,000 103 REAGENT PREP SYSTEM 11,965,000 8,687,000 20,652,000 

104 WASTE RECYCLING SYSTEM 4,n4,ooo 3,543,000 8,267,000 

105 ASH HANDLING SYSTEM 15,880,000 1,341,000 9,396,000 26,617,000 

106 COMMON STRUCTURES AREA 3,007,000 3,171,000 6,178,000 

107 REAGENT KANOLING SYSTEM 1,750,000 2,732,000 6,512,000 10,994,000 

111 UNIT 1 flUE GAS SYSTEM 240,000 1f ,685,000 17,620,000 29,545,000 

112 2 FlUE GAS SYSTEM 240;000 11,685,000 17,620,000 29,545,000 

113 UNIT 1 BOOSTER FANS 5,700,000 168,000 564,000 6,432,006 

114 UNIT 2 BOOSTER FANS 5,700,000 168,000 564,000 6,432,000 

115 BAGHOIJSE 44,000,000 3,012,000 22,000,000 69,012,000 

121 CIVIL \lORI( 1,412,000 3,115,000 4,527;000 

151 MECHANICAL MISCELLANEOUS 1,355, 000 2,797,000 3,699,000 7,851,000 

181 PIPE RACK 2,652,000 3,406,000 6,058,000 

190 DEMOLITION COSTS 500,000 500,000 

201 ELECTRICAL 8,475,000 4,020,000 12,710,000 25,205,000 

211 lllSTRUMEIITATION 2,008,000 811,000 656,000 3,475,000 

301 MOBlliZATION/OEMOB!LIZATl 

Oil a 1% OF LABOR 

1,426,000 1,426,000 

302 COST DUE TO OVERTIME • 20,029,000 20,029,000 

5-10 1S 

304 PER DIEM - a $10 PER 19,754,000 19,754,000 

HOUR 

305 SPARE PARTS a 1% OF 1,500,000 1,500,000 EQUIPMENT 

Q 5% 

TOTAL CONSTRUCTION COSTS 207,903,000 417,297,000 
INDIRECT EXPENSES 

ESCALATION 

SAl.ES/USE TAX 

CONTINGENCY 

TOTAL PROJECT COST 

AFUOC (COll'!pOUI"lded Annually) 

GRANO TOTAl COST 

FINANCIAl ASSUMPTIONS: 

ESCAlATlOU RATES: Equipment 3.000% 

Material 3.000% 

labor 3.000% 

Indirects 3.000% 

SAlES/USe TAX RATES: Equipment 0.000% Material 0,000% 

COOTIIIGEIICY RATES: Equipment 20.0% Material 20.0% Labor 20.0% Indirects 20.0% 

AFUOC Rate 8.240% from 2010 

41,574,000 

47,059,000 

101,186,000 

607,116,000 

99,781,000 

706,897,000 
COMMERCIAl OPERATING DATE: SEP13 

Note: All costs are in thousands of dollars 

2010 2011 2012 2013 2014 2015 2016 

TOTAL DIRECT AND A 77246 209057 133748 38820 

INDIRECT CCST c 77246 286303 420051 458871 

ESCALATION COST A 4704 19385 16787 6183 

c 4704 24089 40876 47059 

COUTINGENCY A 16391) 45689 30106 9001 

c 16390 62079 92185 101186 

TAXES A 0 0 a 0 

c 0 0 0 0 

------------

TOTAL CASH FLOW A 98340 274131 180641 54004 

c 98340 372471 553112 607116 

AFUDC A 1931 17650 40768 39432 

c 1931 19581 60349 99781 

------

GRANO TOTAL COST A 100271 291.781 221409 9!436 

c 100271 392llg_ 613461 706897 

2017 2018 

Cash flow by Year 

2019 2020 2021 
APPENDIX 0 

Wet FGD Capital Cost Estimate 
COMMERC

TOTAL TOTAL TOTAL 

ACCT.!IO. DESCRIPTION EQUIPMENT COST MATERIAl COST LABOR COST TOTAL COST 

101 UNIT 1 ABSORBER-AREA 34,926,000 2,454,000 28,120,000 65,500,000 

102 UNIT 2 ABSORBER AREA 34,926,000 2,454,000 28,120,000 65,500,000 

103 REAGENT PREP SYSTEM 14,282,000 10,369,000 24,651,000 

104 DEWATERING SYSTEM 12,687,000 9,211,000 21,898,000 

105 COMMON STRUCTURES AREA 1,232,000 16,401,000 17,062,000 34,695,000 

106 REAGENT HANDLING SYSTEM 2,500,000 1,891,000 3,715,000 8,106,000 

107 GYPSUM HANDLING SYSTEM 4,500,000 156,000 2,422,000 7,078,000 

111 UN IT 1 FLUE GAS SYSTEM 30,000,000 3,n4,ooo '5,819,000 39,593,000 

112 UN IT 2 FlUE GAS SYSTEM 30,000,000 3,942,000 6,198,000 40,140,000 

113 UNIT 1 BOOSTER FANS 5,300,000 168,000 564,000 6,032,000' 

114 UNIT 2 BoOsTER FANS 5,300,000 168,000 564,000 6,032,000 

121 CIVIL I SITEWORK 1,537,000 953,000 2,490,000 

151 MECHANICAL MISCELLANEOUS 1,087,000 2,605,000 3,020,000 6,712,000 

181 PIPE RACK 1,980,000 2,336,000 4,316,000 

190 DEMOLITION COSTS 500,000 500,000 

201 ELECTRICAL 8,625,000 4,945,000 13,171,000 26,741,000 

211 INSTRU!o!ENTAT!ON 4,000,000 455,000 811,000 5,266,000 

301 MOBILIZATION/OEMOB!LIZATI 1,330,000 1,330,000 

ON a 1X OF LABOR 

302 COST DUE TO OVERTIME - 18,551,000 18,551,000 

5-10•s 

304 PER DIEM - a $10 PER HOUR 16,952,000 16,952,000 

305 SPARE PARTS a 1% Of 1,894,000 1,894,000 

EQUIPMENT 

306 FREIGHT Q 5% OF ~~iER!Al 2,147,000 2,147,000 
INDIRECT EXPENSES 

ESCAi.ATJflil 

SALES/USE TAX 

CONTINGENCY 

TOTAl PROJECT COST 

AFUDC (Compounded Annually) 

GRAND TOTAL COST 

FINANCIAL ASSUMPTIONS: 

EScAlATIOM RATES: Equipment 3.000% ' Material 3.000% 

Labor 3.000% 

tndirecta 3.000% 

SALES/USE TAX RATES: Equipment 0.000% Material O.OGOX CONTINGENCY RATES: Equipment 20.0% Material 20.0% Labor 20.0% Indirects 20.0% 

AFUDC Rate 6.240% from 2010 

48,417,000 

49,599,000 

106,617,000 

639.702.000 

105.,110,000 

744,812,000 
1\lote: At L costs are in thousards of dol Lars 

2010 2011 2012 2013 2014 2015 2016 

TOTAl DIRECT AND A 81105 220402 141037 40942 

!liD IRECT COST c 81105 301507 442544 483486 

ESCAlATION COST A 4939 20437 17702 6521 

c 4939 25376 43078 49599 

CONTINGENCY A 1n09 48168 31747 9493 

c tno9 65377 97124 106617 

TAXES A 0 0 0 0 

c 0 0 0 0 

---------

TOTAl CASH FLOIJ A 103253 21!9007 190486 56956 

c 103253 392260 582746 639702 

AFUDC A 2029 18592 42941 41548 

c 2029 20621 63562 105110 

---------

GRAIID TOTAL COST A 105282 307599- 233427 98504 

c 105282 412881 - 646308 744812 

2017 2018 

Cash flow by Year 

2019 2020 2021 
APPENDIX E 

Financial Analysis Summary 
. 'Entergy. 

._., AIUIAJISAI, IlK. 

WHITE BLUFF STATION UNITS 1 AND 2 

EVALUATION OF WET VS. DRY FGD TECHNOLOGIES 

Economic Parameter Inputs 

r---~ 11.1 .. -1...-- ~-'--'1--. 

BBSis for Fixed Charges 

Evaluation Period (years) 

Book Life· Regutatad (years) 

on 

BBSa Year tor Expressing Costs 

C<lmmercial Operating Dale 

Compliance Dale 

Escalation Rates 

Capllal Costs ('/,/year) 

Q&M.Costs (%/yoar) 

Prop11rty TW<es ('Myear) • Property TCill Rate 

Insurance Rate 

Tai< Rate for Deferred Taxes 

Common Equity Fractlon 

Preferred Stock Fraction 

Debt Fracllon 

Return on Common Equity 

Return on Preferred Stock 

Federal and State tax rate,% 

Beforo lax eos1 of money 

Aner tax eos1 of money 

Wei(lhted Annuity Factor 

Total Capital Requirement 

Fixed Charge Rat& Parameter& 

tnveslmenl Book Depreclatlon 

lT C Normalized 

Preferred AFUDC Recovery 

Equity AFUDC Recovery 

Det>t Book DepreciaUon 

Preler:red Book Depredation 

Equity Book_OepreclaUon 

Input Assumptions Source 

Case 5 ·Wet FGD 

7-Vear Amort 

PRBCoal 

- ... • Econ Pall!millers. 5-12-06 

Econ ParameleiS. 5-12-06 

2008 

2013 

9/27/2013 

Econ Parameters. 5-12-08 

Econ Parameters. 5-12-06 

Econ Parametern. 5-12-06 

. Emao s-1s.oa 

Econ Parameters.,5-12-08 

Email5-15-06 

Econ Parameters. 5-12-06 

Included In Property Tax 

Econ Parameters. 5-12-08 

Econ Parameters. 5-12.08 

Econ Peramelera. 5-12-08 

~;i~;L:i.~ Ecoo Paramelers.. 5-12.08 . .. 8.23% 

7.19"· 

7.67% 

819,294,000 

20.482.350 

8,596,442 

909,416 

10,976,491 

eNT!lRG~AR~ANSA8 WBl·l DRY VS WlH fGDSTIJDY !lEV l.A ISSUED lllJ/.08 

Projo<IIZJQl.$4 -

. case echnoloiiY 

m~ :e- 1 ·Wet FGD 

C... 2 • Drv FGD 

cas& 3 • Wet FGD · 

Cese 4 • Drv FGO · ':\.r,-

. t •2'.Bl't#J c- 6 • Wet FGIP 

""""'"'-"' 

! ' , .. I 

Tax 

r.veas Amort. 

7-Veer Amort. 

7-Year Amort. 

7-Yea< Amort. 

7-Year Amort. 

MS/yl 

,.., 

101.01. 

113.7& 

110.47 

160.U 

Fuel rv110 

PRBCoal 

PRBCoal 

PRB Coal 

PRB Coal 

PRBCoal 

M$/yr 

dl:y 

1~2 

lH.OI> 

11 1.71 

.8$ 

APPENDIX E 

SL-4:109510 

------------ ,. 
.EnietgY. 

WHITE --""" BLUFF STATION UNITS 1 ANO 2 

EVAlUATION OF WET VS. DRY FGD 'TECHNOLOGIES 

Technology Base Year Cost·and 

Performance Inputs 

Net Plant Capacity (MW) 

Capadly Fodor (at lo-&tv!te Oala) 

Equl\iolenl "••iloblllty Fa- lwl. Paww (MW) 

""" Power (UWI'olyuor at lull load) 

Conallud!co Ounollcn (monttu) 

Tle.ln Oulojje Outation (ll'<ll\11\8) 

Amount r. Exca,. o! Normol Oulojje 

Base Yaar ln-SoMmYear 

Total Water CooauntlliJQn (0\lm) 

Waalo Dlscooal (lll/hr) 

Unit Rata (IOMilV) . 

llmeslana Rate (ll>n>AY) 

O&M(lQQB $) 

Bag Replo-t Cost 

Line, $/ton Umeatcna, $Jton 

Total Water ReQUiremonl, $/IOQQ 1181 Baa Cool 

l!.NTbii.OY~Wbl•l Olt\' Vt; WliT rODST1Jl)Y ~"\' lA~ ~1)-').41 

tn;oa llJOJ-004 

-

531,~.000 Email 5-16-06 54,5S9,000 Emoll 5-11>08 

117 ,Z79,000 Email 5-111-011 0 Email f>.1!M)II 

115

,621,000 ErnaU Sol~ 

819,294,000 

819,294,000 

485 

22.569 

APPEHlllX E 

SL.coi51Q 
I'I$<1UIIr••""''lru • Case 1 

:2013 2014 :ztt1G 20Hi 2017 2f11! ~019 21)20 2021 2022 20i3 202.& 202.5 

l'lij d( .t f> 1 l Ill U U I) 

7.142"' 

2A5 

1.\149 

14,200% 

2.51 ~.1..00 

0 

15,3111 

978,576 

145,6515 

121.f.IB 

42.79 

123.88 

0.75 

.... 

14.286% 

14.200% 

14.5&% 

U<181 

13.67% lQ.8a3.875 

150,704 

I!<. IT.! 

1.5125 

0 0.8104 

1,0<> 

11U,7M.005 

24ii,9'\2,U6 

14.2.86% 

2.51 

1.1657 

0 

18,521 

1,017,261 

151,72\1 

124-.73 

·~t65 

126.36 0,71 

9.85 

14,286% 

1<.28ll% 

13.ll!l% 

1.1717 

78.74% 11.347,933 

186,236 

64.61 

2.5733 

0 0.8Xi!D 1.00 

104.991,625 

3,51.903,7$4 

1•US6'rt 

2.65 

1.1!H9 

0 

78,63-4 

1,(}18..738 

1&1.944 

127.~ 

44.52 

\28.68 

0,7\J 

10.05 

14.286'1\ 

1<.28.,1 

13.01% 

1..1951 

TaRS% n,364,11ll 

1Ba,500 

87,47 

a .. oo 

0 

0,7575 

1.00 

9<,194.203 

«6,097,957 

14.l6G% 

2.72 1.2167 

0 

7;3,5$$ 

9SZ,938 

142,130 

130.<1:() 

45.41 

t31.Mi 

o.ao 

1Cl.25 

14.265% 

14.285% 

12.24% 

1.2190 

71.89% 10,830,119 

118,330 

68.81 

2...7193 0 

0.7067 \,00 

83,29M31 

529,39&,.38.4 

14.25&'1\ 

2.'1'9 

'~" 

0 

7l,7M 

955,9G1· 

142,660 

1.33.34 

46.32 

1$4.09 

0.82 

10.45 

14.200% 

14.2®% 

11.46'% 

\.2434 

72.12% 10,663,001 

175,1!89 7U,QT 

2.7863 

0 0.8593 

1.00 

74,fiGMl52 

604,363,440 

14.286% 

2.1l7 

1.Z142. 

~ 

fi5,912 

853,928 

127.382. 

1:\<1.3< 

47.25 

13S.n 

0.1\4 

10.66 

14.265% 

H.;tOO% 

10,ft8% 

1..2682 

IJ.4AZ% 9,5Z5,100 

158,009 

84.01), 

2.8663 0 

0.6151 

1.00 

66,077,869 

670,<441,329 

7.142% 

2.% 1.J02ll 

0 

G&,087 

1\i\2,006 

131.584 

13&41 

46.19 

139.51 

o ... 

1<l8B 

7.1.2% 

7.142% 

10.13% 

,..,.,. 

66.$% 9.{1:39.929 

163,222 

>Z.96 

2.9<8!1 0 

O,ST39 

1.00 

60,859.836 

731.,101;1.85 

o.ooor. 

J.02 

\,3322 

0 10,8-iQ 

911',816 

1:1<1,SOO 

142.5< 

<t9,11l 

142..30 O.Sll 

11.og: 

0.000% 

0.000% 

9.90% 

1.3195 

8~.24% 

10.239,052 

16SI.B4Z 00.0<> 

3.Q23S 

u 0.$354 

\,00 

56,560.800 

161,662.063 

U.OOO% 

311 

1.3621 

c 76.1-&.l 

J.JB6,9M 

147,208 

14!),75 

50.14 

145.14 

0.90 

1U2 

O.IJOO% 

O.OOO."A 

9.16% 

1,3459 

74.46% 

11,0t0,Ul6 

1lt2,6J1 8S.1S 

3,1070 0 

0.41}9$ 

1.00 

5.3.5,1,631 

1141~173.694 

(),{100% 

3.19 

1,:Wl6 

0 

75,379 

SY8,S78 

145.655 

i49.03 

!H.H 

141.1:.05 

0.92 

11.54 

.tJ.OOO% 

ftOOO% 

11.62"4 

1.37Z8 

73.81% tO,fi93,815 

180,704 

t02.3Q 

3.1811 0 

O..t!XiO 1.00 

49.733,873 

890.9(}7 ,001 

iJ,OOO% 0.000% 

3.27 :.t;JS 1AZ41 L~M2 

0 

78.521 '1,011,281 

151.72!:1 

0.000% 0.000'1. 

0.000% 0.000% 

a.47%; 

1.4002 

78.14% 

11).4.7,93-9 

1l!ll.z36 

105-.H 

3.2710 0 

0,4347 

'·"' 

,.,. 

cooo~ 

3.39 

'.4.689 

APPENtllX £ 

S'-"""111~ 

O.OOC% 

.'}>17 

't-5224 

O.D:I.JO"h fi,OOQ"'Ji. 

o.ooor. G.()()O"S, 

~·~---------------------------------------------------------------------------------------------------------------------------------

4~ 
1018 "t211 ,n:to 5n'l ?tt>.J" 'M'f 21\3>t __ 10P 2M$ 2037 2038: 21J3G ZU40 Z!i41 ~ 

~1l1if,l44lf '' u 1a: 1., :w l'l u·-- --:o --l.--~~-i,--~6-----i:;:------,-,---~ 

0.0001<. 0.0001<. 0.000% O.OOIJ'.\ 0.000~ 0.000% 0.000~4 ~000% 0.000,.. MOO% MOO% (HKIO'llo- 0-ll<l<n> JXt5 3.54 3,7:t :t-.18 100 

"'"" •t.01 4.06 ·4.18 ,,, '"'' ~-32 H4 4,$4 

1.5567 1.5Q17 US0115 1.tifi42 1.7018 T-.73$9 1.1"790 1.8TGt l,SQW 1.${116 1.9446 UU84 ZU189 2.1256 

' 0 0 0 0 0 0 0 £8,061 70.845 7t'i.183 75,379 0 0 0 

882.096 tH7,87G- aoo..saa 78,521 76,634 73.555 73.78a 65.912 68,007 976,576 1,017,251 1.()18,138. 1152,93l! 9S5,J.m1 

131,584 136.900 t.t7,200 t4fi,~li!S 

fi5J.028 8S2.000 151,72& 151.9« 142.130 1~500 127,362 131,564 

170.31 

57.00 174.15 

58.75 178JlS 

59.~ 

182.07 1a&.11 100.3£ 1JW,64 199.02 203.00 

1Gttn 170.00 

81.12 62.34 ..... ..... 66.16 67.48 

t.05 1.07 173..16 1,10 176.93 160.41 184.00 187.76 191 • .51 195,34 

13.00 132• 13.52 

t.t2 1.15 1.17 . 1,2_0 1~3 1.26 

13.71! 14-.07 14.15 14-,&4- 1.(,Jl3 1S.2:) 

OJlOO% ll.OOIJ'.\ 0.000% ll.llOO'I. 0.000% OJ)(I'O% 0.000% O.OOO!h a coo" ll.OOO'J;, 0.000';;. "'"""" tLOOO% O.OW'Y. ~000% 0.0001<. o-.000% 0.000% 0.000%- 0.000% 0.00-D% 0.000% 0.000% 0.000% 0.000% 0.000% 

S.OO!'A- 8.52% &.311% 3-.27% 8.14% """" 1.5768 1.8084. 1.fMOO 1.1)734 1.lffi% 1.77% 7.6$•4 7.54% 

1lll24% 74.46% 71117% 78.14% 1.7009 1.H10 1.775a 1.8t14 1.6476 1.8a4S: 

10,Z3S.OQ2 11.()11l,01tl 1Q,6.l03-.675 11,347,933 11.364,183 7il.85%: 71.811%- 12.1:2lK .. ~ .... OO.SS% 72\~ ,0.630,17ll 10,003,90-1 169,1l42 182,631 t80,7CW. 183.236 !1,5-25,708 R,.8-JG,029 10,&4&.554 

122.0-5 124.80 12HJ.1 130.46 

188,506 176.330 118,38!) 156,000 1&3.2.22 178,6n2 133.41 1J6.41 139,.(8 142.1>2 145,.83 l<\9.11 ;.t72.16 3.1884 3,0021 3 .... 5 4.00Sil 4.(11!11' 4.1585 0 0 0 0 ·Ut29 4.2683 4.324Q 0 0 0.2ae& 0.26714 0..2495 0.2321 0 0 0 0 

0.2:171 0.2028 0.1890 0.1763 1.00 \.00 1.00 1.(10 lt164fi 0.1535 

"'"' 1.00 1.00 1.00 1Jl0 1.00 

25,303.416 26,308,855 24,841,721 

1.182.020,8:81 1,.208.320.7t8 1.2l3,171A37 
&wi'Wil@ll'f~--

'""" 

0.000% 0.000% 0.000% , Q,f.)(i()'il., 0.000'¥. O.(loi)('}% 0.000% 0..01)0% 0.000% 0.000:% 

4.!14 .os 4.86 4.91 s.oe 5.19 s.a1 &.43 ~.55 s.ur 2, f7J5 2.1224 2.272.4 2.3235 2.3758 Z.42Dl l.-4839 2.53$6 0!:.5!)63 2Ji5~ 

0 {) 0 0 0 t} 73,666 T..l,W!J 73,006 73,668 

f) 0 0 

954.406 954,400 !.l54,4oo 

73,006 73,006 73.868 7'3,66:6 73,006 i54,4oe s:s...•os 96-4.406 954,406 954,<4:06 

142,348 142.348 1<42,346 142,344 lfS4,-toa 

142,345 1.¢2.348 142,348- 14~.346 142,346 

237.19 243.14 2At1.62 254.21 2SIUJ3 285.111 .271.76 277.137 77.52 7tt07 8.0.&5 82.26 l£4,12 

mas 22a.00 213.45 

a:t~1 85.58 87.30 89:.1)4 90.82 

w ~ = .238.12. 

w . 2A.Z.M ~ 

247.74 m.1o 257.15 262.!11 

u.so t7.a!i Ht2o 1a.s1 1a.JM 1a32 

~ 1a.to 

~ ~ ~ 2o.to zo.so 

0.00{1% 

0,000-'?i 

OJ)O()% 

0.000% 

0,000% 

0.000% 

0.~ 

0.000% 0.000% O.()f;)(l% 0,000,. 0.000% O,OO!J'Yq U.OOO'l. 

&.000% OJlOO'Jt, 0.000% 0.000% 

a:an a.oo% ll.OOO'Y. Q,!Xl£1% a.re% 8.68% 6.59% ~-tso/. eAo% 8.32% 

2.0601· 2-.1223 2.1647 2.2080 tJ.2.1% 

72.00% 72.00% T.r.QO% 72.00% 2.25~2' 2..2972 2.3432 2.3901 2.4379 72-00% 12.1l0:% 72.00% 1200% 72.00% t'0,645,554 10,ti4a,SS. 10,646,554 10,t}.48,554 10,646.~ 10,641.1,554 1{1.648,5$4 

176.602. na,eoo. 11e,uo2 ltl,!i46,6S4 10,646,564 

166.66 170,41 17-4,.24 175.002 

178.16 11e.ooz ne.w 176,602 t7e,m no.so2: 

4.7469 11.essa 4.965:0 s.orn1 182. H 1illl27 100.-46 194.75 Hl:9.13 

o o o o s. uno 5.307& SA2n 5.5493 5.6742' 

0,11)85 0.1012 0.0944 

o on o o 

~ ~ ~ 

I)J)a81 

~ 

().0622 

~ 

0.01fi7 0J)1t5 0.0067 O.oo22 

~ ~ ~ ~ 

52,818,&17 52_0~8,864 51,258,128 S0,500,&31 49,774,025 49,000,576 46.387.167 47,894.401 47.().42,895 46,4!3,2!19 

15,121,665 15.424,119 1s,m,so1 1&,047.253 1(1,368,198 tfl,695.SS2 17.0:W.413 17.370,003 17.717,48<4 te,07t,&13 

F\#li£ 0 0 0 0 o o 0 o 0 () 

A~i$f~14.JrehaM 2S,134.SS3 29,~32,246. 30,094,412 30,771,597 31,463,958 32,171.f!IU 32A95.765 33,835,920 34,392,728 3!l,1tiii,~ 

H3!JFt~rWIJ'l{ o o o o o o o a a o Utrut 0 0 o 0 o 0 o 0 0 0 

Li!'!wt»tnn® s,sua,-466 s,no,-65 a.a24,s« 5.M1.131 b.os9.960 a.ta1,15s a,304,7'1!2 e,..lo,sra 6.559..49S e.JSao.ees Tollif Wat¢ift@G~nt 1,369,Gii7 1,399,SG1 1,"'31,38\l 1,.463,595 

~~w~~tt·"'v.nm• 

.1,496,528 1,530.196 1.554,&2.7 1.!$99,&32 1,635,828 1,672,&34 

=~:~rt~mnt ) wl.~f.i~g i.97 

1oil~.U~ 10.00 

.10i:tg.B~ 10.{l4 

1Ji2:.~;: 10.()6 

to~.r&:ti tO..t3 

108~~62 usl'.:~~::l~· 1ot.m.~ 11~~:~ tt8::~?,~ 10.18 10.23 10.29 10.l5 1DAZ 

12.338.t45 H,548,06Z t0,6l4,609 10,131),821 11:,494,026 8,900,628 6,:Ma,07-t 7,832,857 7.352,.478 8,904,437 1.402..Q00,40S 1.4~4,455,488 1.4ZS,Z7U.OT? 1,435.400AQ7 1,444.894,\)ZJ 1,453,795,749 1.4&2,f-t3,8.23 1,4tm.i76.88CI 1,417,320,15.8 ,}··U;4,Z33,500 

APPEHJJlXE 

S~10 
·~ APPat!JtXE 

GI..OOOSIO 

WttliE ---! lUfF STATION UNn.S. t t.ND 2 

&V"'-lJATlOM Of WU V1l. DRl PGO TectiHOUXJU!S 

Tablo E·Z: Annual Roveriue Requirement&· Can 2 

Cue.2-0ryFGO 

PRB COlli 

... .. 20t 2C2l ' • ""' 1 . .. " 1\ " A.n n. ~, ........ dl'tlc;M.l 

1n~Aa.a~~lm ll 

Ta - 1-Y-ut N'OOn. 7.1.(2,. , . ....,. 14.2N'!<, ,.....,. 14.lM~ ,.....,., 14 2~ 1,W%'A. M OO" """""' """" 0....,. OOCC% """""' ..... ..__) 0.000% : PRO Cool 2."" z.at ... , 2.6:5 l .t2 :L TD 2.&7 , .. 3.02 '" .. .. ,, , .:JS ,,,. ~fiC;cJn 1.1 l .4T 149 1.1400 1.1M7 U i 1A 1.2187 ·~.u 1.2142 . ...,.. 1.3022 1.382:1 1.>928 \AU\ \ ,4$62 , ..... 1$4 

VlrirtM O&M Ca~ 

~Riliil .... , .... ... &48 ) 

l.Mne~(b;n;J 

54,2!18 56~1 56.612 ~liSG SS.12.( ' 47,464. 19,019 ·51.007 &c,Ma 54.26<> 14>J1 1401 2 OtiS<! Sl.124 0 0 0 0 0 0 0 0 0 0 • TOIIIWI/Af-1 0 0 0 Q 1000. .. 1121.830 at3. 1B8 1141.002 84/l.215 ,.,. .... w ..... Alh 7116.002 711,042' ' 734,4.97 7a..200 l71,83a 813,1AB . &47,06:2 &48.275 , ...... 1'96,110> t:llpoNi (bnl ~ 114,270 115,044 tl~.I3Q! 1;tQ.CJ11 t t1.2MI 112.115 IDQ,$1111 , Ull,8H 108.128 ,,.,,. 115.1)4ot1 1\&.UO 120.011 I IZ,2tdl 1u.&l 5 

line. $Mn na.lO 12 1.;& U.f,TJ 127.53 ,...., ,., ,. ,,.,. , .. , ...... ,..,. t491l.l 1.52.31 \!5.~ 1 15v.,3:1 ,., .. "'-"""' 4U6 42.20 41&5 44.&2 ·~41 ... 32 47.25 4L11 ..... ,...,. BogC<>al,S 81.14 S2.11 53.21 IIU7 .. .38 

1~1.40 123.118 1~~, 02a.Be 1)1..46 1~.09 '"'n ToloiW-~StiOOO ... 

131.51 1<2.30 14!,14 140.00 1St.Ot 154.03 1GT.n t.5o.2S 

W--Mt\~$t\On 

0.1< 

... , .... 

0.15 1~ .... 0.02 .... .. .. .... O.PO 0.01 0 ... .... o ... I .DO p.es 10.05 10.15 lOA& ,.. .. 11).118 11.1$ 1U2 11.54 ,,,TT UJI\ ·= w.41 

CtiiCcU tntd v ••• r.,~ 7.l4a H.2Bti"4 14.2W,4 14.285" 1-4-..286% 14.2!811 ,.__., 7.1-i2'%r. ~"""" ....... ....... 0.000'4 O.OCOll ,...,... o."""" -"'·-- Fbe<~Clll:rg•~· 

7.'142% t~.l:M% '"'..266% 1<.2- ......... , • ..288% 14.200% T. 142% ....... ....... .o ..... 0,000'1\ O.CG)"AI. 0 ...... o.ooos 15.%7% "'""" 13.40%. 13.01% 11.24% 11..46% ,. ..... 111.13"%,. . ..... '-'"' """" ~~F~ 

UN .. ,. 0.20% ....... c.p.dtyFecil:r ,

1.

.,...,. 1182 · 1.1487 1.1711 1.1961 12190 1.2A34 1.28&2 1.21138 1.31 05 1.3AS& U 721! 1,4002 1A282 ....... . ..... 73..87% 78.7.,. 71.8&1' u.aw. 12.1 ~ ......,. ....... ....... ,.,..,. n.en . 7& 74,. ,.,..,. --1'«11>1 11,010.0 \S 71.118'!1. 12.1"" 10AI'J.815 u.w .w t1.304.tll 10.830.179 1Q.Bil.to1 t .S1:5,7Qe, ..... ,. lll.2"002 11,010,0.\0 1Q,!itl,a15 11;NT,938 tl,364,1Jl t0.Jl0,17Q 14.003,11)1 --"""'1 41l,1t~ \·H~14& tSWa 153,.af 143.603 14<.<m 1.28.665 132,8011 138,30Q \48,113 141,\.45 1U.27& 1U.U7 ....,..., 144,Q>a 

--Coot~ f-UIIf.pne.t$1~} ... &6.00 

.., 2.a1a 

... ~ !lUI 67.47 ... ., 76.{)7 ..... u .. .. ... 00.15 002.31 105.7-4 100.20 HUB 114.17 2.5133 2.1)490 2.11~ 2.t'M3 ....... , ...... ·~ 3 .\070 .).1111 3.21'10 ...... ,,,... FU>!~-1 ...000 0 0 0 0 0 0 • 0 • • ~V..F~ 

0 0 Q 0 0 o.ono ... , .. 0.3120 0..7675 0.7007 ...... ...... o.stsa ....,.. £~hri04Fa.ctX , .. 0,408$ ...... OA<1 ...... O.J1&4 o.= IJJ<l \.00 1.00 IJJO IJlQ 1Jl0 UlQ I,Qll 1.00 .... \,00 1.00 \.DO \,00 

~~~ fuat Bl&la IO~ r~rJ o \Ot~m o ~:!: ~ o o o o o o o tj~~ ~~iM a;=' li~~ 1~~~~ s:= e.::ti~ o e':::~! o ~:ru:~ o o ~~i ~~~ ~= 

Poww~ 

·o o 

B"''JR~ 

9.814,187 i,552,SQ:~, 8,.9()2.11& 10,356,.118 a.aao.on to.m.aor 10,a1a,w U.lS5,la6 t:t..zn.204 '"·.,-t•.m · 1s,.a.,111 tt.2GJ.61W tt,n:z.r;os ,a.Ol2.UI1 \8,444 ,811 

Ume 1.M1.5'8 1,&14.7-"4 1,QGG.,1Q5 2.03Q,I);)7 1,&45.412 1,i90,G&T 1.113.,171 1,91 1,041 Z,D28,l1l: 2,22.4 ,710 2..2o&!,m 2.315.638 2.08.,Jll 2.32!.QJ1 2.l7U..OM 

~ 

6.543.W o 6,l1UQ'1o 

. 7.0~Um3 1.2:2:0.!0 105.G4~ 7.DI3.411 408.,7~1 1.13),531 7.210.11' 7 .... ,07" 6.007,71G 8.fn 4.37t e.IZ0..811 M)ll.729 6JI.M.!21 

Tot&Wl• ~MW~t 

a o o o. o o a o o a o o o 61)4,7112 111.a4a 651AM &87,304 . ~~ M4..M1 ser,swn &31,685 &Tt.DA1 731.&47 747.so2 rae..t7ll ate:,w m .m lii,&ll 

T ................ ..,......?~e:,~ 

"""'"""""' .,~ ':ho; .. kMJ:m ,J:-lw. ~"Vi .J.~rtm .~u:m .al1am ,au: ,J:iG~ Ji\i ~ ,ol:ffl:MS ,ol:m.:.u ,oA:m:m aJ .lR: l~ ,J:i'll::ru 1U:a 11.iol 11..oe tO..IS6 10.1a \0.34 1o.&4 10.43 to.Dt a ... a ua D.V 1.21 tJo U il 

~P

PrtmAiiV ... 

ii

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2tl5~1S 205,515 205,&15 206.a1S 170.41 174-2-4 178.18 182.17 

4.85.58 4.965ll !i.0767 5.1810 0 0 0 0 0,'\{l'\Z. 0.011<4 O.OOM 0,002:2 

1.00 1.00 1.00 1.00 

0.000% 0..000% 

S.l1 5.43 2.4$31) 2.S3Sil 

p a 73,666 73,868 9€9,54') OO.fi.,SA3 1,.Z,34a 14:!,34ll 

265.78 2:11.16 

115.51! 67.30 2~7.74 262".70 1.54 L63 

19.32 Htro 

O.tiOOY• O.OO'J"Ai 

0.000% 0.000 .. 

6.49')1. 9..40% 

2.2972 2.3432 f.l.OO?'t JZ.OO'% 10:,1).46.,5$4 1D,646,S$4 

205,615 ZJ$,615 156.27 190 ... \i 

5.301$ 5.4212 0 0 0.0767 0Jl?t5 1.00 1.00 

2W1 2052: 

0.1100% 0.000% 

551 5.87 Z.SOOI) 2.&554 

0 a 13.£6$ 13,658- OO&,Ml 969.&.\3 

142,346 14?,34& 

~n.at 264.12: 

69.04 9(),82: 

251.15 2.fli;,91 

1.11 us 20.10 '"'·"' o.OOO'!l o.ruw•;.. 

. D.OOO% 0.000% 

6.32.% ··- 2.l001 2.4379 

72.0011 72.0Q% "\(\,&46,5.54 10,(!41).,5$4 

205,&'\5 205,615. 1S.U$ 100-13 

5.0<93 $.5742 0 0 

Q.06ili1 0.0622 1.00 t.OO 

7.~.860 7,42{1,76~ 

1.564,097,562. 1.511.514.:123: 

APPatOJXE 

8lA»iS'fll 
T.'IA2.% 14.200% 14288% t4.2fl0.% 1.o4.266% 14.28£% 1oi.2Be% 

:!:AS 2J'i5 2.12 2.79 vrr 1.11411 1.1!119 1.2187 1.2:4"(!2 1.2742 

54.26> 56,531 51l.61~ 52,!166 53,124 <1.<54 0 0 0 0 0 0 8:2U,7:ul 8S.U48 1}55,173 aoo.ara 303.413 717.00~ 

115,044 119,8Jtl' 120,011 112,2~ 112.515 100,596 

124.73 127.53 130.'10 1l3.34 136.:!4 

43.6S 44.S> 45.41 46.32 47.25 

12:6.3& 128.88 131..46 134.0!) 136,71 

0.17 o:w 0.60 0.82 M4 9.65 11),00. 10.25 10.-45 1.0.00 

7.1-"2% 1~.200"!1. 14.268% 14..286% 14.ZB6% 14.266.% 14.2S~ 

7.142%. i-4.<00,., ~ .. .200% 14.2$% H.2etl-,_ 14.200% ~4.2~ 

14.55% 1::1.50% 13.01% 12.24% 11A6% tO.Sfl% 1.1481 1.1711 1.1951 1.2190 1.2-434 1,2682. 73.S7~ 7&.74% 7S.85%' 71..89% 72.121J1,. 6-4.42% 

10,893,&75 11.341,938 11.3&4,19:'!: 10..630,179 10,663,981 &,526.108 1,52,308 151!.658 15MS3 1-48.521 1-i0,D!I2 133.170 

1>1.92 64.81 87A1 63JI1 76.o7 64.00 2.S1i!S 2.5733 2.6400 2.7193 2.1883 2,0063 

0 0 0 0 0 

0$1<>1 D..a12tl" 0.7575 0.7007 0.8!:.9~ 0,6l!i1 • 1,00 1.00 '1.()0 1.00 1.00 1.00 

7.142% • 0..000% t/.000% 

2JlS 3!\2 3.U 

1.3!)26 1.3322 1.3621 

4'!1.01'i 51,~01 54.1)4ll 

0 0 0 141.336 171.400 829,483 

103,81.o4 108,129 111.1:,270 

13!).41 142,54 1.<15.15 

4.!t19 49.1fl 50.14 

139.51 142.30 145.14 

0.00 o.aa: 0.00 10.SS 11,1)9 """ 7.142% 0.000% O.OOO'i't 

7;\42% 0.000% 0,000'1'. 

10..13% 9.!10% A.16% 1.293(1 1.3195 1.345!J 

66.55% 89.24% 7-4.46% 1),839,92.!} 10.~9.662 11.01(}.016 137,572 143,1$3 153,931 

02.96 (16,00 99.15 

2.~69 3.0236 3..1070 

0 0 0 0.5739 0.5:).54 0.41l!l5 

1.00 1.00 1.00 

nllOO% 0.000% 

3.111 3.27 

1.Ja2a U2<41 

54,269 Sll.$31 

0 0 820,739 854,!148 

115.044 11lM:139 

1-'3.03 1.52.36 

51.14 52.17 148,0:5 151.01 

0.02 M4 H.~ 11.'17 

0.000'¥. 0.000% 

O,OOIY'J. {\.\/00%. 

1Ui2% ~M1~ 

1.3728 1.4002 

73..67% '711.14% 10,893,875 11..347,938 1S2,308 153,656 

102.39' 105.7-i 3.1871 3.2710 

0 0 0.4680 0.4M7 

'1.QO. 1.00 

0.0-00% 

3.35 

1.4562 

5fl.ti12 0 1156,113 

121:>,011 

1&5,81 

53.21 

154,03 

.... 

12.01 

o.ooor. 

o.uoor. 

!),33% 

1A21!> 

7lUJS%. 

11,364.193 150.663 

109.2U 

3.3498 

0 0..4056 

1.00 

1).000% 

3,3'il' 

1,4006 

0.000% 

OJlDO'I, 

!UO% 

1.4S68 

71.89% 

1o,m,17v 

148.821 

111,00 

l.394S 

0 0.37&4 

1.00 

APf'ENDiX!9. 

&l...ooi\S'\11 

0.000:% 

3.41 

1.5224 

'""' mft 

0.000% .O.!X!O% 0.000% 0.0011% "·""""' 0.000% 0,000% 0.000% 0.~% 0.000*4 

~1T:l5 

4.64 .... <.111 5.08 5.19 5.31 5,A;3 5.55 567 2.2124 >323! ·2,3756 2.421)2: l . .C&'Jl) 2.539& 2.5969 2.6554 

53,037 53,031· 53,031 53,037 53,037 53,037 53,037 53.037 Sl,037 0 0 0 0 0 0 0 0 0 802,100 S02,10S !l02,10Ei 802,100 802,100 802.100 8:02.100. 001,108 802,106 112,432 112.431' 112,432. 112,.132 112.432 112.432 112.432 \12.432 112,<32 

237,70: 2.C3.1.t 248.62 254.21 259.113 265.78 271.78 271,8.1 2841~ T1.!i2· 1il,07 ac.ss !lZ.<!l 63.91 85.56 87.:30 68.04 oo.u 22;A:.39: 22JI.B8 233.45 238.12 242.86 ~7.74 252.70 257.75 262.5t 1A7 uso 1.53 1.57 ·uo 1.64 1Jlll 1.71 1.75 17.50 17,85 16.20 1&57 18.1ilol 19.32 19.7{) 20.10 20 ... 

0.000% 0.11001\ 0.000% 0.000% 0.000'11 OJlOO% 0.000% OJJOO% !),000%. 0.000% (l.tXIO% 0.000% 0.000% 0.000% 0.000% 0.000% 

...... ... % t\.78% ...... U9% 6 . .41)%' f1.40% 6.32'11 6.13% 2.0007 2...1223 2,1641 ,2.2Ce(l 2.2622 2.2972 2.3432 ?.3901 2.437!} '72.00% 72.00% 72.001\ 72.00% 11.00% 12'.00% 72.00%. nco% 72.00% 10,&4&.554 10.6411.554 10,64&,554 1G,646,564 10.6<16,554 10,6<18.554 10,640.554 \0,646,554 1M<6.554 148.650 1.46,800 H8,85Q 1-i6,8.56 14a,a.50 148,850 t~tl.850 1.<\8,850 'U&,aso 16&.00 17().41 1'1'.4.24 178.18 1RZ.17 166.27 190 . .48 194.75 199.13 4.7.89 """"' <4.9650 5.0161 5.10:10 UJI7B 5.4272 5.5493 S.tlT-42 0 0 0 0 0 G 0 0 0 a. toes ... 0,1.012 O.Q!1.44 o.oaat 0.0822 0.0787 0.0715 0,0067 0.0022. tOO 1.00 1.00, 1.00 1.00 too \.00 1.00 1.00 

50JID4,246 4G,Q14,l09 40,182.231 46,468:,547 .C7,713,81G 47,09B:,58S. . "",443,4B8 <45,8®,050 45,1SS,l.tS7 13.422,500 13.500,950 13,004,788 14.241.00:.. - 14,528.94a 14,&19,524 1$.115.915 15.418.233 15.726.597 (I 0 0 0 0 0 0 .o .0 24,007.179 2.5,345,340 25,936,000 28,51i,M2 27;11$.313 2T,12S,430 2.8,3$0,275 26,988.156 2!l.S40,390 3,326,832 3,392,349 · a.•oo.too 3,5Zi,400 3.,!119:,988 :t,an,sar 3,74.5.427 3.820,338 J,aaa.7.t2 12,811,850 12.Mfl.71!l 13.185,872 1l,462.M! 13,7M,it2 14,096,095 14,.tt3.2ST 1A.737,55S 15,06&,100 0 0 0 0 0 0 0 0 0 1,176..504 1.202,976 1,230»42 1,257,718 1.2.88.017 1.314,952 1.344-.539 1,374,791 1,40:5,123 1.967.021 Z.006.361 2.046.4B& 2.087,418: 2,129,1titi 2,,71,150 2.215,1~ 2,2$9,-400 ;!,3:Q+,fJ78 

.. -.n ~~- •- --~ --- 10,28&,7i6 &,651,\19 9,0SS,TOZ 8,500,«7 7,JNl2.4$1 7,499',148 1,041,003 1,433,594,Dt12 1,443.246,112 1,452,301,814 1,460,802.261 1,461.7&·V42 1.-473,2&3,600 1,483,331,874 

4-
.&leJBY. 

WHITE -·~-- &lUFf ST ATlON UNITS t AND 2 

~AlOATION Of 'HEr \'1 DRY fG.D TECHWOLOGI.ES 

Table E-5: Annual Revenue Roqulromenta - Ca•• 5 

Cese 5 ·Wet FGD PRB Coal 

Cak!l.'!!!Y!!t CIGiliill'l£i't•a~ 

o\nnal F"'*r& aftll Prion: 

fne!~ 

T-.~ 

l·Yf/IWAtrwort. 

F..-. Pneq ('$1~) 

PRB Coal 

"""""''"""' 

·-~ l.lrM (WJnl} 

~(ton•) 

Tota.IWfltMfta,QW~1(1000aga 

Wn.AIIA~(blt} 

l.>na.$1\oo 

"""'-"""' 

... Cot~$ 

Teui'N.tl4f~n>efll.511000-v-! 

w...,.Ntt~Siron 

C~uL.t.dV.W. 

Tax.,._ 

........... E-Poriod 

--c:no.vo- O&M~F.a« 

c..,.ctyf""" 

........ ,..,_., (>MbJ 

--(IA'MIJ A.u.l.. P"vwe' CoM tSIM'M'I} 

'""Prioo{;lrrml!") 

Pr¥ent '""' 

E~PonodF~ """"""- vq F.acr --

f:ili4~

f lxodOUtl ..... Fuol 

--- ... 

1..\mo. 

,_.,_.,.,. -

<DIWIWR~ 

:I:"'""'"""""' 

PI"'-"V.W.{PVM} ~~~ c.mw.t~,. PVRII ~~\'.,., .. 2,09&.266.52-4 ~(Siy6W) 1t0.84M32 

1:)(TD!lV~W& 4-Da. Vf.WliT ND mllVUVa~fQ..-t.Gt 

.......,_ IDOWIM 

I 

iOU 2G1~ 

~ .. ....,., 1.46 :1.51 ut<4a t1A00 

• 0 

4.11.l,l1111 <7a.2l<l t ,Oll,\20 t.m.m .. ~,.,. ;:;!.2,71!8 

11G.30 121.9! ..... 42.7Q 

121.45 113.80 

0.74 0.75 

9 . .47 ... 7.142% 14.298% 

7.1-U% ,.....,. 15..ml ....... um 1.1417 ,. ..... 73..,... 11 ,0U\Ch0 tQ.BU.815 

26).510 :zeo,no ..... . ..., 2.A<2l ...... 0 0 

o.am M704 1,00 1.00 

,,1,13-4,966 119,42t1.!08 

a.~~· 9.1&4.21' 0 0 

11.lt1,290 1S.02G_DI 0 • 0 :zo.zn.B75 l0.485,G48 • 780,236 7681,1-43 

uU!tfll ntH ..... ..., taa..3M.CI72 152,97f1,7M 

189.30$,072 ll2.281.857 

U2 QtW;1' iUd I .., 3G WWH~• 

2915 2()11 1017 ,.,, 

IU ..... tot ..2M% t•..zatl'!l. 1U86'!1t 

2-51 2.65 2.12 u• 1,1657 1.1G1i 1..2187 1.24SZ 

Q 0 Q 

418,1&3 ....... , 411,6·U 468,12$ • 1,01S&,829 1 ..... ,.. 087 •• 7111 t,OOO,W 

911,687 m.ow 011).21)0 ...... , 124.73 127.53 t30,4Q 1>3.3< 

..... ..... 45AI . ..,. 126.30 12AM 131..&6 ....... 0.77 0.70 .... ... , us IO.OS uus 10.(5 

1o4.288% 1'-2.86% , .. .2&6% 1'.21!Mio 

14.2tll!l'4 14.288'4 ........ 14.2 .... 

13.80% 13.01% 1Z.2.4"' 1t.40'Yt 

1.1717 1.1951 1.2100 1 ..... 

1ll.74 .. 7U5% 71.10% 72.12% 11..:W7,931 11.364.193 lG..OlO.fTU! 111.B63,00\ 

l71.SU l1U41 254,419 :!55.216 s.uu 87.47 IIUI 71.01 

2.573) 2.6490 2.7193 2.1083 0 0 0 0 

0.6120 0.7575 ~1(161 ...... 1.00 1.00 1.00 I .DO 

113.023,64.0 101~::.:: 100,2(2',768 aJ.&M.S'Q 0.3<1~ .. .UH,1)7 9,9HJ.640 

D • D 

17~7,013 la.M0,<3<1 • 17.S00.793 19.·U-',t51)3 

• 0 0 0 

D 0 0 21,7+t,405 22,211,0o5:2 21.UJt,07e 21,1&4,W • 11i,l.N ....... 002.l3S ....... n!il:m 16an.m .am ,.;e 1!..16 , .... 7.) ...... ..... 13Q,707.863 128,T&8.,431 112.226,SII18 102.3&4.973 

.661.QIW.72G 681.7U.I51 7Q0.86l',007 ltl3.3!12 ... 0 

AJ>PaiOil(E 

SL-OQISIQ 

201a M 2!l1 2SZ !W .... ,., . m• .. .. 

'W.2&ev. 1.\G% o.ooor. 0."""" . ...,.,. .. .,..,.,. O,OCI).,. o.ooo .. .....,... Ul 2.90 lJll 3.11 3.1i 3.17 ll! 3.39 ,., 1.21<2 1.302P 1.3322 1.3021 ·= 142<4;1 U~2 \MaS t.S2:2ot 

0 0 D 0 0 • 0 0 0 416.101 .. I .... <UI,ffl 411J.l18 4l6.,Zl0 41&.1!) 40&,&67 ........ .al, l2:5 

tml.Mt 123,.,. .... ,,. t.Ol3.120 I.Ol2.222 an I_,.. Kl,oUI 1.000.6<3 

l1~3i ....... 070.720 acz.m OJ>,n8 97.1,8Q7 m.ou QtG...lW. 11111011 

1311.3< 139.41 14~54 Wl.l& 14~03 152.)4 15.5.11 1&9.32 ...... ol7.2! .ta.t9 49. "te .... 51.14 l.tH $:UI $<.27 ...ltl I>B.TT 13:t.51 14:t.l0 ,...,. .... DO tS1.01 15<1.03 1~7.11 ... ,. o .... o ... o.aa .... 0.111 .... .... o .. 1.00 , .... ..... 11.tlG 11.ll 11.54 11.77 12:.01 1Z.215 12.<9 

14.2e6% 7.1<4t% 1!.000% O.OO!lll. O.OO<l'l'o 0.000.. O.OCO% ODOO'T. ....... >U116% 7.14%% .. ..... O.JlOO% 0.000'1<. 0."""" .....,.. 0.000.. 0.000'1. 

10U'lfo 10.13% 9,90% ·- ...... ... ,... ., .. ..,.,. . ..... 1.2<8:1 1.WS Ut95 ...... 1.372& 1.<001 1.4282 ,....,. I ..... fM .• U'J\ 66 {1~ ........ 74.46Yt , ...... 76..7<1% 7B.85~ 711111% n.1a O.W.l'OB o ..na.m 1Q,lW.062 11 ,010,0W 1Q,eu:l,II'T6 11.3-47,938 11 ,3&4 ,1 Q:3 10.630. 110 , O,Ml.90t 

117.80<1 2>6.805 2~ 051 2G3,510 

""·"" 271 ,691 l1t,t87 2!14,.( 11) ,..= l>lOO ...... ... .. 99.115 IO:Z.lO 10!.7.4 10\I.:ZO 11U6 114.17 

2.11663 ~. .... 3.02:16 3.1 070 1.1$11 l .ZllO 1.3< .. 3.39<6 , ..... 0 0 0 • 0 0 0 0 0 O.J1£'\ 0.6139 ~- 0,499} ... ..., O.<ll4l' ... .,. O.ll&4 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 ·= 1.00 

17.A07.J'W 13.011,4!.2 &1 ,125..2'50 79.9ol8.ln 7&,m .7oa l'7,81i.!iTl 1&,41:U&1 75.ll8.\fi1 10,111.033 10,)20.»1 10.6ZI,IOl 10-,JJT,»S 10.852.0841 11.\71,126 11,»4,540 t1.15ZZ.6-40 

0 0 • 0 • • 0 ' 19,111.171 21,!92.1115 2~52j)~ .. 2&.U5,7JI 20.'S0.1101 2!1,7\.0,&43 Zi-701,150 2&.407,1&6 

• 0 0 • 0 0 Q 0 

0 0 • • 0 • 0 0 1i,T51.)42 20.817,2!2 .22.094,U7 24,2ll.&9S 24,457.t21 25.,9&e.576 Z8,SU.27S 26.32!1.37! 

75UIIKI m...-r ........ UB,T!M 0'3$.67~ I,QOO,.OS< t~ MQ 1100.21< 

,.;:m,w, 1~ u~:liWI 10eM,4116 

1!2.W ,Ui 10.767.016 1 1..U0.11t tU&S..&IQ 1 \.UV.e.:i: 

1UJ ...... 14. .. 13 ... 

119,.104,19! 83.788.136 7B,1U ,66fi 711,2-4lUW7 71 ,\04.23-i 61,7110.178 &l.801~7 m.~.427 54,1V.7,7'M 

09l.15<,%24 970.!14070 1.05<.091.215 1,1:t:U3&.612 1.2<13."3.111 1.271.233.709 1.33<,!37,l26 l .l!lt661.753 1,4-MI,IS0.536 

4~ 
-·-·-~-

U. 

___ 1Q~_ 

It 

. ----~30 

1$. 

2931 2032: 2033 %OM.. ::lO:lS 2Cl38 2037 20l!J 2b3Q If }0 21 U lf l. l1 1• 

0.000% Q,OO()"A 0.000% 0.00<1% 0.000% "·""""' 0.000% 0 ...... o.O<J<W. 0.!100% MOO% 

3.64 3..72 3.711 '·""""' 3.88 3.114 4.01 t1)6 1,:iB'IT 1,627.5 .4.16 4.21 4.21 4.3-:Z t,664Z 1.1016 1.739$ \.rna 1.8191 1.11600 1.9013 1,1).446 t9ea4 

.4.3.1,!115-t 0 M9A7S. 

0 483,319: 

0 0 0 0 0 0 0 0 0 

923.~ 000,778 

478,22:0 4l18.,1S3 496.667 ~f.YS,e-4~ 4eB,I25 418,181 43l,B.S4 467.$4 

........ 8.78,7ZO 

,,033.,120 

9-42,733 1.022.221 ,,064,!123' 1,0&6,354 997,479 1,00Q,.643 . an3,1W1 923.3i6- Wl9,01S 932.,788 971,667 973,059 910,209 !}13..097 81$,1>39 64;1:,54.4 rut,an 

170,31 

57,£0 17-415 

SU.75 

178,00 182.07 1a6.1T \<l<l.31i '[94.&4 1f.l9.!l2 :1:03.~ 208.00 212.76 

1£6.72 170,00 173.48 

o.a.a2 81.12 62.3< 13.~9 64.11<! ... ,. t7.48 mun 70.41 

\,OS 1.07 178.93 1t'I0.47 164.00 161.78 191.51 1.$5.34 1~.2$ ZJ3.23 

~3.00 13,26 

1.10 1.12 1.15 1.17 1.20 1.23 1.28 1.28. ~.31 

'\3.~2 13.79 'l4.11T t4,3S 1•UW '\4.93 15.23 15.54 15.8'1 

\MlOO%· 

0.000%- 0.000% 

0,000% 

0.000%, 01)(){)% o.OOQ% O.Ofl<l% 0.000% 0.000% 0.000%. O.OOO'n o.ooo-~ 0.000% 0.0:00% 0.000% (1.000% 0.000'!1. 0.000% 0.00\l% O,OQ!l% Q,QOOl< 6,10% ().000%. 0.000'11 

··- ...... ·- 1.5460 1.57{19 

.(1,27% A.1<1% ...... 1.8:9'¥. . 1.77'r. 1.G5% 1.54"4 

00.$.$'1\ 1.6084 1.64011 1,6734 1,7069. 1,7410 1..7758 1.811<1 U478 UM!$ """"" if,83$,!129 1Q,2':!W,062 11,(!10,016 74..46% 10,89~875 

73.61'% 16.1~% 78.8:5% 71.8S%. 72.1Z'I. 6<1,.4-2% 66,55% 12.-. 

23S.50S 11,MT,Il3& 11,36.(,193 10,63.0.179 10.00~.901 fl:,az&,rM .... 9.029 10,646,554 l45,1l58 .263.510 2.50,730 zn<ma 27UIIl1 .zs,.f.,.tt9 =· 110.37 122,05 2Z1.JIIl8 l3S,Sll5 2SUl11 

3.&3-59 3,721l\ 12<4.6{1 121-81 13'0-.48 133,41 136.41 139.46 1.UJU 14~e3 14fM1 3,7&S4 3.&621 :1.11365 4.00511 <4.&!17 4,'t!la5 <4.2128 .....,., 0 o. 4.32:4B • 0 Q 

0'.30?'2 Q.28e0 0 0 ·o 0 0 0 

1.00 d2874 0.249!$ 0.23:'7 0.2111 0.202'8 0.1800' ~171!.1 (\.164-5 01535 1.00 \,OQ \.00 1.00 1.00 1.00 1.00 1..00 1.00 1,00 

APPENilli(E 

SC-10 

2G40 2041 ·." '""' 

O.atxl% 

2AJ31 ··"' 

0.000% 

"·"""" 1.~2.%-

1.9222 

7Z.OO% 10,a.-8,554 2'54.ll11 

'l:i2.47 

.. ,..,. 0 tti4JZ 

1.00 

0.000%. O.tl~Xl% 

444 4 54 

2..07Sa 212fi6 

222.44: 

1>04 

2:H.4S 

1.37 

16Aa 

0,000% 

0.000% 

7.3't% 

\,9601 

1200% 

Hi.646,$54 2SU11 

l!lS.IIO 

4.4423 

0 0.1.»6 

1.® 

4~ 
Wlfl1l --

·~ ..... BlUfF Slii.TlON lJNrig 1 AND Z 

EVALUAllOH 0/F 'ftn W . D«Y F® lECHKO\.OGtU 

Tabla E-5: Annual Ravanue Roqulromenta • Cao 5 

Cue 5 ·Wet FGD 

PRBCoal 

c.-. .. v ... ~y-

~ 2...,. ___ llH' 104e ~' ~-- ~ ~----mL __ _____1m_ U U -- J.l-- M JJ .»'· .11 )f Mo 

AnarwJI P.tatoN 11'11 P$:U1 .,.,.,...ltl T•- 7·Y-AmorL 

f ... _(ll_) 

PRBCNi' 

_¥_0U,C~ 

-F- -~IIMii 

...... ""'" u.-..""" Bas!CaoU 

....__,_ ...... !""'' , w_....,_!_l T<Uiw.cat~t1000.p 

T*_""""_fltOO<lpl ---1/t>n 

l;olo-4Vol-

,_~ 

,...._ ... _ ....... ................... 

~.,.-=Fid« 

----~ ...... ----Coal-) '"""'' fuooiPdoo~"'l 

-~_...._, 

Pn:wlt YaM ... 

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