Research Article Thermal Performance and Economic ...of thermal power plant using thermodynamic analysis, and economic analysis based on Net present value approach. e predicted results

Research ArticleThermal Performance and Economic Analysis of210 MWe Coal-Fired Power Plant

Ravinder Kumar,1 Avdhesh Kr. Sharma,1 and P. C. Tewari2

1 Department of Mechanical Engineering, D.C.R University of Science and Technology, Murthal, Sonepat, India2Department of Mechanical Engineering, N.I.T Kurukshetra, Haryana, India

Correspondence should be addressed to Ravinder Kumar; [email protected]

Received 19 September 2013; Revised 11 December 2013; Accepted 11 December 2013; Published 12 February 2014

Academic Editor: Mohammad Al-Nimr

Copyright © 2014 Ravinder Kumar et al. This is an open access article distributed under the Creative Commons AttributionLicense, which permits unrestricted use, distribution, and reproduction in any medium, provided the original work is properlycited.

This paper presents the thermal and economic performance of a 210MWe coal-fired power plant situated in North India. Analysisis used to predict coal consumption rate, overall thermal efficiency, mass flow rate of steam through boiler, and Net present value(NPV) of plant for given load. Thermodynamic analysis was carried out using mass and energy equations followed by empiricalcorrelations. Predicted mass flow rate of steam, coal consumption rate, and thermal efficiency give fair agreement with plantoperating data.The economic analysis includes operational activities such as equipment cost, fuel cost, operations andmaintenancecost, revenue, and plant net present value. From economic point of view, the effect of condensate extraction pump redundancy onnet present value is observed to be sensitive than boiler feed pump redundancy.

1. Introduction

Thermal power plant working is based on Rankine cycle,where the thermal efficiency of cycle can be thermodynam-ically improved by increasing the mean temperature of heataddition, that is, by introducing feedwater heating systems.Numerous researchers [1–3] have reported enhancement inthermal efficiency by dividing overall enthalpy equally viafeedwater heaters. It was proposed by [4] that the thermo-dynamic performance of Rankine cycle power plant can beimproved by reducing volumetric flow rate of steam. Later,researchers tried to improve the efficiency of the plant byincreasing steam pressure, which resulted in degradationof the steam quality at the turbine exhaust. To overcomesuch problems, steam reheating was introduced after highpressure turbine exhaust, which leads to decrease of themoisture content at low-pressure turbine exhaust. The effectof reheat pressure on cycle efficiency was investigated [5].They reported best performance of steam power plant atoptimal reheat pressure. All themodifications/improvementsin Rankine cycle (like feed water heating and reheating) leadto a substantial improvement in cycle efficiency.The study [6]

on energy analysis of 250MWe Hamedan steam power plantsuggested that energy loss mainly occurs in the condenser.

The economic analysis of the plant has been carried out inpast on the basis of initial capital investment, operating costs,annual revenue, and profit obtained.The Net present value ofplant has been evaluated in the literature [7]. The equipmentinclude steam turbine, boiler, generators, and other auxil-iary components such as pumps, condensers, and so forth.Researchers reported considerable work on economic anal-ysis using net present worth method in the various processindustries. Sensitivity analysis for the capacity improvementof a combined cycle power plant (100–600MW) concerningeconomic performance has been studied [8]. Economicfeasibility and financial risk of refuse derived fuel (RDF)production plants have been instead evaluated on the basisof the Net present value index over a capacity range of 25–200 t/h comparing either single RDF production plants orfacilities integrating also compost production and/or electric-ity generation [9]. The Net present value (NPV) approachwas implemented to determine the economic manufacturingquantities for an unreliable production systemover an infiniteplanning horizon [10]. The feasibility of using biomass to

Hindawi Publishing CorporationJournal of ermodynamicsVolume 2014, Article ID 520183, 10 pageshttp://dx.doi.org/10.1155/2014/520183

2 Journal of Thermodynamics

1a

31 29 28

30 26 23

22

24

27 25

15

1821

20 17

19

13 12

1416

G

1d 1c

45

67

10

C2

O

C6C1

I

B6

B4B 3B2 B5

J

B

1e

23

119 11b

11a

C3 C4 C5B1

HPT IPT LPT LPT

X3 X4 X5 X6

14

GM

CM

CM

1b

1

O, H, I,J, K

30 26 23 21 18HP-1 HP-2

DRLP-1 LP-2 LP-3 DC GSC EJE

COND

Boiler

G

M

32

10 10a

7

BFP CEP

SH

RH

ECO

X8 X9

X1 X 1 + X2

X1 X2

X4 X4 + X5 X 4 + X 5 + X6

Z1

Z2

d1 d2 d3

8

d4

Figure 1: Steam turbine cycle based coal-fired power plant.

provide electricity in combustion and gasification plantswas investigated and evaluated [11]. The study of economicfeasibility of constructing a 560MW coal-fired power plantin Turkey, using real options theory, was discussed [12].A parametric study concerning the use of combined cycletechnologies for power generation and cost-benefit analysiswas carried out using the independent power producersoptimization algorithm in which the electricity unit cost wascalculated by independent power producers in Cyprus [13].Performance, cost, and emissions data for coal and naturalgas-fired power plants were presented, based on informationfrom studies carried out recently for the IEA GreenhouseGas R&D Program by major engineering contractors andprocess licensors [14]. A new methodology is presented fornew design of power plants, which combines the benefitsof thermodynamics, economics, andmathematical optimiza-tion [15]. In order to account for the cost of the investmentrequired, the total capital cost must be placed on an annualbasis. The annual cost consists due to interest accumulatedon the investment, depreciation,maintenance, insurance, andtaxes.The equipment life deteriorates with time and its depre-ciation cost is associated with it and thus, loses value [16].

This work presents the thermal and economic analysisof thermal power plant using thermodynamic analysis, andeconomic analysis based on Net present value approach. Thepredicted results agree with plant operating data.

2. Coal-Fired Power Plant

A schematic diagram of 210MWe unit of a coal-fired powerplant is shown in Figure 1. In power plants, several physical,chemical, andmechanical processes are conducted to transfer

the energy, stored in fossil fuel, into electrical energy. Thisenergy conversion is divided into several stages. Thermalpower plant (Figure 5) uses coal as feedstock to convertit into mechanical energy through the expansion of steamfrom a high pressure in a suitable prime mover called steamturbine. Generator coupled with turbine produces electricalenergy. Coal received from collieries in the rail wagons ismechanically unloaded by wagon tippler and transportedby belt conveyor system to the boiler raw coal bunkers.The crushed coal, when not required for raw coal bunkers,is carried to coal storage area through belt conveyor andtelescopic chute. The quantity of coal from coal bunkers tocoal mill is regulated through raw coal chain feeder, wherecoal is pulverized into the fine powder form. The pulverizedcoal is then sucked by vapor fan and finally stored in thepulverized coal bunkers. The pulverized coal is then pushedto the boiler furnace, which is comprised of water tube wallsall around through which water circulates. This chemicallytreated water running through the walls of boiler furnace getsevaporated at high temperature into steam by getting furnaceheat.This steam is further heated in the superheater (SH).Thesuperheated steam produced in the superheater enters intothe high pressure Turbine (HPT). After expansion in HPT,cold reheat steam is divided into two streams, one is sent forreheating in reheater (RH), and another is sent towards highpressure feedwater heater (HP-1). Steam then passes throughintermediate pressure turbine (IPT) and low pressure turbine(LPT) respectively. The incoming stream of steam towardsIPT from HPT after RH is divided into three streams. One issent towards intermediate pressure feedwater heater (HP-2),and the other two are sent towards Deaerator (DR) and LPTrespectively. Similarly the incoming stream of steam towards

Journal of Thermodynamics 3

LPT from IPT is divided into four streams, and out of thesefour streams, three streams are sent towards low pressurefeedwater heater (LP-1, LP-2 and LP-3) and one stream issent towards condenser, respectively. The steam after doinguseful work in the turbine is condensed in condenser. Thecondensate is sent by condensate extraction pumps (CEP)towards gland steam cooler (GSC), drain cooler (DC) andremaining is sent towards low pressure feedwater heaters.Since the extracted steam upon condensation gets subcooledso the drain cooler (DC) is used. From the last low pressurefeedwater heater (LP-1) outlet, the condensate enters in deaer-ator shell. Boiler feed pump (BFP) supplies this condensatequantity from deaerator (DR) to Low Pressure FeedwaterHeaters and High Pressure Feed Water Heaters respectively.Boiler feed pump (BFP) is a multistage pump provided forpumping feedwater (FW) to economizer. Three pumps eachof 50% of total capacity are provided out of which two pumpswork in parallel and third will be reserve. After HP-1 thecondensate passes through economizer (ECO) and finally itenters into the boiler drum. Hence the cycle is completed.

3. Thermodynamic Modeling

Energy and mass balance equations have been used for themathematical modeling of each component. The empiricalrelations have been also derived based on thermodynamicrelations.

3.1. High Pressure Feedwater Heater (HP-1). High pressurefeedwater heater receives superheated steam bled from theturbine at state 1, the steam is first desuperheated thencondensed and finally subcooled, whereas the feedwater getsheated as shown in Figure 2. The schematic diagram of highpressure feedwater heater “HP-1” (for 𝑖 = 1) is shown inFigure 3.

Mass balance:∑𝑥in = ∑𝑥out. (1)

Energy balance:

𝑥𝑖× ℎ𝑠(𝑖)+ 1 × ℎ

𝑓(𝑖+1)= 1 × ℎ

𝑓(𝑖)+ 𝑥𝑖× ℎ𝑐(𝑖),

𝑥𝑖=

(ℎ𝑓(𝑖)− ℎ𝑓(𝑖+1)

)

(ℎ𝑠(𝑖)− ℎ𝑐(𝑖)),

(2)

where ℎ𝑓(𝑖)

= ℎ(𝑖)𝑙− TTD × Cpw and ℎ

𝑐(𝑖)= ℎ𝑓(𝑖+1)

+

ETD × Cpw. “𝑥” is the fractional mass flow with total steamflow from boiler. TTD and ETD are terminal and entrytemperature difference of feedwater heaters. The value ofTTD and ETD is taken to be 5∘C and 2∘C, respectively. Thepressure for each turbine extraction is supplied empiricallyusing design data of 210MWe thermal power plants (seeTable 1) as given by (3) as

𝑝𝑖= 0.189MWe + 1.476. (3)

The formulations of high pressure feedwater heater (HP-2) (Figure 13), deaerator (Figure 14), low pressure feedwaterheaters (LP-1, LP-2, LP3) (Figures 15, 16, and 17), drain cooler(Figure 18), gland steam condenser (Figure 19), and ejector(Figure 20) are detailed in Appendix A.

L

DC

Steam

DS

CondensateBled steam

−TTD

T FW

C

FW FWCDS DC

CondenserDesuperheater Drain cooler

ETD

1

3130

29

hs(i)

hf(i)

h(i)g h(i)l

h f(i+1)

hc(i)h(i)lg

Figure 2: Temperature-length diagram forHP-1 (DS: desuperheater,C: condenser; DC: drain cooler).

, s(i)i hx

1, f(i)h 1, (i+1)fh

, c(i)i hx

Figure 3: Schematic diagramof high pressure feedwater heater (HP-1).

HPT

ibib hx ,

1, hf(i) ,1 f(i + 1)h

, c(i)i hx

, s(i)i hx

30

1

2931

RHid ic

ie

Figure 4: Schematic diagramof turbine-cum-high pressure feedwa-ter heater.


Table 1: Design data of pressure (bar) of bled stream at various locations from turbine.

Sr. no. MWe Pressure (bar) of bled stream from the turbine𝑃1

𝑃2

𝑃3

𝑃4

𝑃5

𝑃6

1. 126 25.36 10.60 4.37 1.589 0.558 0.2882. 168 33.26 13.84 5.28 1.961 0.695 0.3563. 210 41.27 16.25 6.43 2.396 0.853 0.431

S

1e1a

2

3

4

5

6

107

23

2122

20 18

11

24

25

262728

29 3031

T

1d

Figure 5: 𝑇-𝑆 diagram of thermal power plant.

0

20

40

60

80

100

120

140

100 150 200

Coa

l con

sum

ptio

n ra

te (T

on/h

r)

Electric power output (MWe)

Operating dataPredictions

Figure 6: Coal consumption (T/hr) versus plant output.

3.2. Steam Turbine. A steam turbine is one module thatextracts thermal energy from pressurized steam and convertsit into useful mechanical work. Steam turbine is condensing,tandem compounded, horizontal, reheat type, and singleshaft machine. It has got separate high pressure, and inter-mediate and low-pressure parts. The HP part is a singlecylinder and IP & LP parts are double flow cylinders. Thecondensate which is leaving the first HP-1 feedwater heateris mixed with the subsequent feedwater heater and then thetotal condensate is mixed with the next closed feedwater


0

100

200

300

400

500

600

700

100 150 200

Flow

rate

of s

team

(T/h

r)Electric power output (MWe)

Figure 7: Mass flow rate of steam versus plant output.


20

25

30

35

40

45

100 150 200

Ove

rall

effici

ency

(%)

Electric power output (MWe)

Figure 8: Overall efficiency versus plant output.

heater and then the resultant is normally dumped intothe deaerator. In the modern thermal power plants, themodeling of steam turbine is carried out alongwith feedwaterheaters. Thus, steam turbine-feedwater heater can be treatedasmathematical element to describe the thermal power plant.The schematic diagram of steam turbine-cum-high pressurefeedwater heater is shown in Figure 4.

Thus, the power output of the turbine can be written interms of mass flow rate of working substance and enthalpydrop as

𝑃𝑜𝑝= 𝑚𝑤Δℎ, (4)

where Δℎ = ℎin − ℎout.


0100200300400500600700800900

10001100

0 1 2 3 4 5

Ann

ual c

ost (

Cror

e IN

R/Yr

)

Number of boiler feed pump

CoalMaintenanceInsurance and general

OperatingRevenue

Figure 9: Annual cost (Crore INR/Yr) versus number of boiler feedpump.

150250350450550650750850950

105011501250

0 1 2 3 4 5

Cos

t (Cr

ore I

NR)

Number of boiler feed pump

Fixed costNet present value

Figure 10: Cost (Crore INR) versus number of boiler feed pump.

Mass balance:

𝑥1𝑏=

2

∑

𝑘=1

𝑥𝐵𝑘+

2

∑

𝑘=1

𝑥𝐶𝑘+

2

∑

𝑘=1

𝑥𝑑𝑘+ 𝑥1𝑐, (5a)

𝑥1𝑐= 𝑥1𝑑+ 𝑥1𝑒. (5b)

The notation of subscripts𝐵𝑘,𝐶𝑘, 𝑑𝑘1𝑐, 1𝑑, and 1𝑒 represents

the various states in Figure 1.Work done:

𝑊𝑡1= 𝑥1𝑏(ℎ1𝑏− ℎ1𝑐) . (6)

Accordingly, formulation of intermediate and low pressureturbine can be done and final work can be written as

𝑊𝑡= 𝑊𝑡1+𝑊𝑡2+𝑊𝑡3. (7)

0

100

200

300

400

500

600

700

800

900

1000

0 1 2 3 4 5

Ann

ual c

ost (

Cror

e IN

R/Yr

)

Number of condensate extraction pump

CoalMaintenanceInsurance and general

OperatingRevenue

Figure 11: Annual cost (Crore INR/Yr) versus number of condensateextraction pump.

100

200

300

400

500

600

700

800

900

1000

1100

1200

0 1 2 3 4 5

Cos

t (Cr

ore I

NR)

Number of condensate extraction pump

Fixed costNet present value

Figure 12: Cost (Crore INR) versus number of condensate extrac-tion pump.

3.3. Condenser. In the analysis, it was assumed that thebalance steam from turbine after subtraction of bleeds is con-densed all in condenser. Thus mass balance can be written as

𝑥10𝑎= 𝑥10+

6

∑

𝑘=1

𝑥𝐵𝑘, (8a)

𝑥11= 𝑥10𝑎+ 𝑥11𝑏. (8b)


xi, hs(i)

1, hf(i) 1, hf(i+1)

xi + xi−1, hc(i)xi−1, hc(i−1)

Figure 13: Mass and energy balance for high pressure feedwaterheater (HP-2).

xi, hs(i)

1 + xz1 , hf(i)

(1 + xz1 ) −3∑

k=1

xk

xi−1 + xi−2, hc(i−1)

Figure 14: Mass and energy balance for deaerator (DR).

xi, hs(i)

xi, hc(i)

((1 + xz1 ) −3∑

k=1

xk), hf(i+1)((1 + xz1 ) −3∑

k=1

xk), hf(i+1)

Figure 15: Mass and energy balance for low pressure feedwaterheater (LP-1).

Mass consumption rate of coal can be written in terms ofunit mass flow rate of water (𝑚uw) as

𝑚coal =𝑚uw (𝑥1𝑎 (ℎ1𝑎 − ℎ31) + 𝑥1𝑑 (ℎ1𝑒 − ℎ1𝑑))

(𝜂boilerCVcoal). (8c)

𝜂boiler is the boiler efficiency; it is fixed at 0.86 in the presentcalculations [17].

xi, hs(i)

xi−1, hf(i−1) xi + xi−1, hc(i)

((1 + xz1 ) −3∑

k=1

xk), hf(i+1)((1 + xz1 ) −3∑

k=1

xk), hf(i+1)


xi, hs(i)

5∑k=4

xk, hc(i−1)

6∑k=4

xk, hc(i)

((1 + xz1 ) −3∑

k=1

xk), hf(i+1) ((1 + xz1 ) −3∑

k=1

xk), hf(i+1)


6∑k=4

xk, hc(i−1)

6∑k=4

xk, hc(i)

((1 + xz1 ) −3∑

k=1

xk), hf(i+1)((1 + xz1 ) −3∑

k=1

xk), hf(i)

Figure 18: Mass and energy balance for drain cooler (DC).

The overall plant efficiency can be defined in terms ofplant capacity (MWe) as

𝜂plant = 1000 ×MWe

(𝑚coal × CVcoal). (9)

4. Economic Analysis

The economic analysis of the plant has been carried out onthe basis of initial capital investment, operating costs, andannual revenue. The equipment cost include boiler, steamturbine, condenser, generator, and auxiliary equipment such


xi =6∑

k=1

xC𝑘, hs(i)

xi =6∑

k=1

xC𝑘, hs(i)

6∑k=1

xC𝑘, hc(i)

((1 + xz1 ) −3∑

k=1

xk), hf(i+1)

Figure 19: Mass and energy balance for gland steam condenser(GSC).

xi =2∑

k=1

xZ𝑘, hs(i)

xi =2∑

k=1

xZ𝑘, hc(i)

((1 + xz1 ) −3∑

k=1

xk), hf(i+1)((1 + xz1 ) −3∑

k=1

xk), hf(i)

Figure 20: Mass and energy balance for ejector (EJE).

as condensate extraction pump, feed water pump, and soforth. Thus, fixed (equipment) cost, 𝐶

𝐹, can be written in

terms of redundancies of respective components (if any) as

𝐶𝐹= 𝑓 (𝐶boiler + 𝐶turbine + 𝐶condenser + 𝑛ce (𝐶condpump)

+ 𝑛fb (𝐶boilerfeedpump) + 𝐶generator) .

(10a)

𝐶𝐹represents fixed cost. The coal storage, ash handling,

electrical works, civil works, and fumes treatment costs areneglected in the present work.The initial cost for each equip-ment/component𝐶

𝐹𝑖has been obtained from [11] empirically

in following form

𝐶𝐹𝑖= 𝑎(MWe)𝑏, (10b)

where the values of constants 𝑎 and 𝑏 are taken from Table 2.The total operating costs includemaintenance, insurance,

and general costs, total operating labor, and purchase of coalfeedstock as [11]

𝐶OP = (𝐶maint + 𝐶ins + 𝑛𝐿𝐶lab + 𝑚coal𝐶coal) , (11)

where𝐶 is cost in (INR), while subscripts OP,maint, ins, coal,ep, and lab correspond to operating, maintenance, insurance,

Table 2: Constants for purchased equipment cost estimation [11].

Equipments 𝑎 𝑏

Generator 138300 0.6107Steam turbine 633000 0.398Condensate extraction pumps 9000 0.4425Steam boiler 1340000 0.694Boiler feed pumps 35000 0.6107Condenser 398000 0.333

Table 3: Operating data for calculating average salary of plant per-sonnel in a typical 210MWe plant unit.

Total personnel deployedin 210MWe unit

Total monthly salaryof personnel (Rs.)

Average monthlysalary (Rs.)

233 6025000 25858.36

coal feedstock, electricity/MWe, and individual labour cost,respectively. Here maintenance and insurance costs are takento be 3% and 2.5% of the total fixed cost [11]. Averagepersonnel salary on annual basis is deduced from plant dataas given in Table 3.

Annual revenue obtained from the electricity can beevaluated as

𝑅an = 𝑓MWe × hrs ×MWe × 𝐶ep. (12)

Thus, Net present value (NPV) can be written as

NPV =𝑝𝑙

∑

𝑙=1

(𝑅an − 𝐶OP)𝑙

(1 + 𝐷)𝑙

− 𝐶𝐹. (13)

All reference values of data collected for the analysis aretabulated in Table 4. The taxes and financial charges havebeen neglected in this work.

5. Results and Discussion

The above analysis was used to predict the coal consumptionrate, overall thermal efficiency, mass flow rate of steamthrough boiler, and Net present value of thermal power plantfor given plant capacity and redundancy on pumps. Thepredictions of mass flow rate, overall plant efficiency, andcoal consumption rate were compared with operating plantdata from plant for validation as shown in Figures 6, 7, and8. The coal consumption rate and mass flow rate of steamincrease with electric power output of plant. However, overallefficiency is not showing any significant increase with electricpower output. A fair agreement between predictions andoperating data has been shown graphically at wide range ofload conditions of plant.

The effect of employing redundancy (excessive) unitsto boiler feed pumps and condensate extraction pump onannual cost of plant andNet present value is shown in Figures9, 10, 11, and 12, which reflects that equipment, maintenance,


Table 4: Input data collected from literature and plant records.

Parameter 𝑛𝐿

Lab 𝐶coal CVcoal 𝑓 pl 𝐶ep 𝑓Mwe 𝐷 hrs/yrValue 233 25858.36 (INR) 2696.81 (INR/Tone) 17656 (kJ/kg) 1.87 20 (year) 4000 (Rs/MW-hr) 0.9 9% 4555

insurance, operating, coal, and revenue increase with anyincrease in pump redundancy in various subsystems. TheNet present value decreases with any addition of boiler feedpump redundancy inwater circulation subsystem (Figure 10),while it shows marginally increasing trend with condensateextraction pump redundancy in condenser unit (Figure 12).

The effect of condensate extraction pump redundancy onNet present value is comparatively higher as compared withcase of boiler feed pump. It is expected due to lower initial costof condensate extraction pump as compared with the cost ofboiler feed pump.

6. Conclusions

The thermal and economic analysis of a 210 MWe coal-firedpower plant was carried out to predict the coal consumptionrate, overall thermal efficiency, mass flow rate of steamthrough boiler, and Net present value of thermal power plantfor given plant load and redundancy of boiler feed pumpand condensate extraction pump.Thermodynamic modelingwas carried out for evaluating the thermal performance.Predictions ofmass flow rate of steam, coal consumption rate,and thermal efficiencywere compared against plant operatingdata for validation. Economic analysis includes equipmentcost, fuel cost, operations andmaintenance cost, revenue, andplant Net present value. The redundancy due to condensateextraction pump is sensitive to Net present value.

Appendix

A. High Pressure Feedwater Heater (HP-2)

In the same manner for 𝑖 = 2,Energy balance:

𝑥𝑖=


)

(ℎ𝑠(𝑖)− ℎ𝑐(𝑖))+ 𝑥𝑖−1((ℎ𝑐(𝑖)− ℎ𝑐(𝑖−1)

)

(ℎ𝑠(𝑖)− ℎ𝑐(𝑖))) . (A.1)

Empirical relations:

𝑝𝑖= 0.077 ×MWe + 0.83, (A.2)

ℎ𝑓(𝑖)

= ℎ(𝑖)𝑙− TTD × Cpw, (A.3)

ℎ𝑐(𝑖)= ℎ𝑓(𝑖+1)

+ ETD × Cpw. (A.4)

B. Deaerator (DR)

Energy balance, for 𝑖 = 3:

𝑥𝑖= ((1 + 𝑥

𝑧1) ×


)

(ℎ𝑠(𝑖)− ℎ𝑓(𝑖+1)

)

)

− ((𝑥𝑖−1+ 𝑥𝑖−2) ×

(ℎ𝑐(𝑖−1)

− ℎ𝑓(𝑖+1)

)

(ℎ𝑠(𝑖)− ℎ𝑓(𝑖+1)

)

)

(B.1)

𝑝𝑖= 0.0312 ×MWe + 0.4367. (B.2)

C. Low Pressure Feedwater Heater (LP-1)


𝑥𝑖=

(((1 + 𝑥𝑧1) − ∑3

𝑘=1𝑥𝑘) × (ℎ

𝑓(𝑖)− ℎ𝑓(𝑖+1)

))

(ℎ𝑠(𝑖)− ℎ𝑐(𝑖))

, (C.1)

𝑝𝑖= 0.0111 ×MWe + 0.189, (C.2)ℎ𝑓(𝑖)

= ℎ(𝑖)𝑙− TTD × Cpw, (C.3a)

ℎ𝑐(𝑖)= ℎ(𝑖)𝑙− ETD × Cpw. (C.3b)

D. Low Pressure Feedwater Heater (LP-2)


𝑥𝑖= (

((1 + 𝑥𝑧1) − ∑

3

𝑘=1𝑥𝑘) × (ℎ

𝑓(𝑖)− ℎ𝑓(𝑖+1)

)


)

+ (𝑥𝑖−1×

(ℎ𝑐(𝑖)− ℎ𝑓(𝑖−1)

)

(ℎ𝑠(𝑖)− ℎ𝑐(𝑖))) ,

(D.1)

𝑝𝑖= 0.00405 ×MWe + 0.048, (D.2)ℎ𝑓(𝑖)

= ℎ(𝑖)𝑙− TTD × Cpw, (D.3a)

ℎ𝑐(𝑖)= ℎ(𝑖)𝑙− ETD × Cpw. (D.3b)

E. Low Pressure Feedwater Heater (LP-3)


𝑥𝑖= (

((1 + 𝑥𝑧1) − ∑3

𝑘=1𝑥𝑘) × (ℎ

𝑓(𝑖)− ℎ𝑓(𝑖+1)

)


)

+ (

5

∑

𝑘=4

𝑥𝑘×(ℎ𝑐(𝑖)− ℎ𝑐(𝑖−1)

)

(ℎ𝑠(𝑖)− ℎ𝑐(𝑖))) ,

(E.1)

𝑝𝑖= 0.00198 ×MWe + 0.039, (E.2)


ℎ𝑓(𝑖)

= ℎ(𝑖)𝑙− TTD × Cpw, (E.3a)

ℎ𝑐(𝑖)= ℎ(𝑖)𝑙− ETD × Cpw. (E.3b)

F. Drain Cooler (DC)


ℎ𝑓(𝑖)

= (

6

∑

𝑘=4

𝑥𝑘×

(ℎ𝑐(𝑖−1)

− ℎ𝑐(𝑖))

((1 + 𝑥𝑧1) − ∑3

𝑘=1𝑥𝑘)

) + ℎ𝑓(𝑖+1)

. (F.1)

G. Gland Steam Condenser (GSC)


ℎ𝑓(𝑖)

= (

6

∑

𝑘=1

𝑥𝐶𝑘×


((1 + 𝑥𝑧1) − ∑3

𝑘=1𝑥𝑘)

) + ℎ𝑓(𝑖+1)

. (G.1)

H. Ejector (EJE)


ℎ𝑓(𝑖)

= (

2

∑

𝑘=1

𝑥𝑧𝑘×


((1 + 𝑥𝑧1) − ∑3

𝑘=1𝑥𝑘)

) + ℎ𝑓(𝑖+1)

. (H.1)

Nomenclature

𝐶coal: Coal cost (INR/tone)𝑐𝑒: Condensate extraction pump

CVcoal: Calorific value of coal (kJ/kg)𝐷: Discount rate (%/yr)𝑓: Factor for direct installation, auxiliary,

instrumentation and control, engineering,and plant start-up

𝑓MWe: % of net electric energy power plantoutput assumed as 90% of MWe availablefor sale

𝑥𝑖: Fractional mass flow rate of steam at “𝑖th”

state (tone/hr)ℎ𝑠(𝑖)

: Enthalpy of superheated steam (kJ/kg)ℎ𝑓(𝑖)

: Enthalpy of feedwater at exit (kJ/kg)ℎ𝑓(𝑖+1)

: Enthalpy of feedwater at entry (kJ/kg)ℎ𝑐(𝑖)

: Enthalpy of condensate (kJ/kg)𝑚coal: Annual coal consumption (tone/hr)ℎ𝑟𝑠: Annual operating hours of the plant

(hrs/yr)𝑛ce: Number of sub-systems (redundancy) of

condensate extraction pumps𝑛fb: Number of sub-systems (redundancy) of

boiler feed pumps𝑛𝐿: Total number of employed personnel

𝑃𝑖: Pressure of bled steam from turbine at “𝑖th”

state (bar)𝑝𝑙: Plant life (years)𝑃npv: (INR)𝑅an: Annual revenue earned (INR/yr)𝑓𝑏: Boiler feed pump

𝜂plant: Overall thermal efficiency of the plant (%).

Conflict of Interests

The authors declare that they have no conflict of interestsregarding the publication of this paper.

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