POWER GENERATION.pdf

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Source: HANDBOOK OF MECHANICAL ENGINEERING CALCULATIONS
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POWER GENERATION
Downloaded from Digital Engineering Library @ McGraw-Hill (www.digitalengineeringlibrary.com)
Copyright © 2006 The McGraw-Hill Companies. All rights reserved.
Any use is subject to the Terms of Use as given at the website.
POWER GENERATION
Downloaded from Digital Engineering Library @ McGraw-Hill (www.digitalengineeringlibrary.com)
Copyright © 2006 The McGraw-Hill Companies. All rights reserved.
Any use is subject to the Terms of Use as given at the website.
Source: HANDBOOK OF MECHANICAL ENGINEERING CALCULATIONS
SECTION 1
MODERN POWER-PLANT
CYCLES AND EQUIPMENT
CYCLE ANALYSES
1.4
Choosing Best Options for Boosting
Combined-Cycle Plant Output
1.4
Selecting Gas-Turbine Heat-Recovery
Boilers
1.10
Gas-Turbine Cycle Efficiency Analysis
and Output Determination
1.13
Determining Best-Relative-Value of
Industrial Gas Turbines Using a Life-
Cycle Cost Model
1.18
Tube Bundle Vibration and Noise
Determination in HRSGs
1.22
Determining Oxygen and Fuel Input in
Gas-Turbine Plants
1.25
Heat-Recovery Steam Generator
(HRSG) Simulation
1.28
Predicting Heat-Recovery Steam
Generator (HRSG) Temperature
Profiles
1.33
Steam Turbogenerator Efficiency and
Steam Rate
1.36
Turbogenerator Reheat-Regenerative
Cycle Alternatives Analysis
1.37
Turbine Exhaust Steam Enthalpy and
Moisture Content
1.42
Steam Turbine No-Load and Partial-
Load Steam Flow
1.43
Power Plant Performance Based on
Test Data
1.45
Determining Turbogenerator Steam
Rate at Various Loads
1.47
Analysis of Reheating-Regenerative
Turbine Cycle
1.48
Steam Rate for Reheat-Regenerative
Cycle
1.49
Binary Cycle Plant Efficiency Analysis
1.51
Steam-Turbine Regenerative-Cycle
Performance
1.71
Reheat-Regenerative Steam-Turbine
Heat Rates
1.74
Steam Turbine-Gas Turbine Cycle
Analysis
1.76
Gas Turbine Combustion Chamber
Inlet Air Temperature
1.81
Regenerative-Cycle Gas-Turbine
Analysis
1.83
Extraction Turbine kW Output
1.86
STEAM PROPERTIES AND PROCESSES
1.87
Steam Mollier Diagram and Steam
Table Use
1.87
Interpolation of Steam Table Values
1.90
Constant-Pressure Steam Process
1.93
Constant-Volume Steam Process
1.95
Constant-Temperature Steam Process
1.97
Constant-Entropy Steam Process
1.99
Irreversible Adiabatic Expansion of
Steam
1.101
Irreversible Adiabatic Steam
Compression
1.103
Throttling Processes for Steam and
Water
1.105
Reversible Heating Process for Steam
1.107
Determining Steam Enthalpy and
Quality Using the Steam Tables
1.109
CONVENTIONAL STEAM CYCLES
1.53
Finding Cogeneration System
Efficiency vs a Conventional Steam
Cycle
1.53
Bleed-Steam Regenerative Cycle
Layout and
T-S
Plot
1.55
Bleed Regenerative Steam Cycle
Analysis
1.59
Reheat-Steam Cycle Performance
1.62
Maximizing Cogeneration Electric-
Power and Process-Steam Output
1.110
ECONOMIC ANALYSES OF
ALTERNATIVE ENERGY SOURCES
1.112
Mechanical-Drive Steam-Turbine
Power-Output Analysis
1.67
Condensing Steam-Turbine Power-
Output Analysis
1.69
1.3
Choice of Most Economic Energy
Source Using the Total-Annual-Cost
Method
1.112
Seven Comparison Methods for
Energy Source Choice
1.115
Selection of Prime Mover Based on
Annual Cost Analyses
1.120
Determining If a Prime Mover Should
Be Overhauled
1.122
Downloaded from Digital Engineering Library @ McGraw-Hill (www.digitalengineeringlibrary.com)
Copyright © 2006 The McGraw-Hill Companies. All rights reserved.
Any use is subject to the Terms of Use as given at the website.
MODERN POWER-PLANT CYCLES AND EQUIPMENT
1.4
POWER GENERATION
Cycle Analyses
CHOOSING BEST OPTION FOR BOOSTING
COMBINED-CYCLE PLANT OUTPUT
Select the best option to boost the output of a 230-MW facility based on a 155-
MW natural-gas-fired gas turbine (GT) featuring a dry low NO
x
combustor (Fig.
1). The plant has a heat-recovery steam generator (HRSG) which is a triple-pressure
design with an integral deaerator. A reheat condensing steam turbine (ST) is used
and it is coupled to a cooling-tower / surface-condenser heat sink turbine inlet. Steam
conditions are 1450-lb / in
2
(gage) / 1000 F (9991-kPa / 538 C). Unit ratings are for
operation at International Standard Organization (ISO) conditions. Evaluate the var-
ious technologies considered for summer peaking conditions with a dry bulb (DB)
temperature of 95 F and 60 percent RH (relative humidity) (35 C and 60 percent
RH). The plant heat sink is a four-cell, counterflow, mechanical-draft cooling tower
optimized to achieve a steam-turbine exhaust pressure of 3.75 inHg absolute (9.5
cmHg) for all alternatives considered in this evaluation. Base circulating-water sys-
tem includes a surface condenser and two 50 percent-capacity pumps. Water-
treatment, consumption, and disposal-related O&M (operating & maintenance)
H-p
turbine
I-p turbine
L-p turbine
Cooling tower
Generator
H-p steam
L-p
steam
Makeup water
Feedwater
pumps
Condensate
pumps
Deaerator
Reheater
Fuel
H-p
evaporator
I-p
suprerheater
H-p
economizer
I-p
suprerheater
I-p
evaporator
I-p
economizer
L-p
evaporator
L-p
economizer
Gas turbine
H-p superheater
Air
Blowdown
Blowdown
I-p pump
I-p pump
Cold
reheat
steam
Hot reheat
I-p steam
Generator
FIGURE 1
155-MW natural-gas-fired gas turbine featuring a dry low NO
x
combustor (Power).
Downloaded from Digital Engineering Library @ McGraw-Hill (www.digitalengineeringlibrary.com)
Copyright © 2006 The McGraw-Hill Companies. All rights reserved.
Any use is subject to the Terms of Use as given at the website.
MODERN POWER-PLANT CYCLES AND EQUIPMENT
MODERN POWER-PLANT CYCLES AND EQUIPMENT
1.5
costs for the zero-discharge facility are assumed to be $3 / 1000 gal ($3 / 3.8 m
3
) of
raw water, $6 / 1000 gal ($6 / 3.8 m
3
) of treated demineralized water, and $5 / 1000
gal ($5 / 3.8 m
3
) of water disposal. The plant is configured to burn liquid distillate
as a backup fuel.
Calculation Procedure:
1.
List the options available for boosting output
Seven options can be developed for boosting the output of this theoretical reference
plant. Although plant-specific issues will have a significant effect on selecting an
option, comparing performance based on a reference plant, Fig. 1, can be helpful.
Table 1 shows the various options available in this study for boosting output. The
comparisons shown in this procedure illustrate the characteristics, advantages, and
disadvantages of the major power augmentation technologies now in use.
Amidst the many advantages of gas turbine (GT) combined cycles (CC) popular
today from various standpoints (lower investment than for new greenfield plants,
reduced environmental impact, and faster installation and startup), one drawback is
that the achievable output decreases significantly as the ambient inlet air tempera-
ture increases. The lower density of warm air reduces mass flow through the GT.
And, unfortunately, hot weather typically corresponds to peak power loads in many
areas. So the need to meet peak-load and power-sales contract requirements causes
many power engineers and developers to compensate for ambient-temperature-
output loss.
The three most common methods of increasing output include: (1) injecting
water or steam into the GT, (2) precooling GT inlet air, and / or (3) supplementary
firing of the heat-recovery steam generator (HRSG). All three options require sig-
nificant capital outlays and affect other performance parameters. Further, the options
TABLE 1
Performance Summary for Enhanced-Output Options
Measured change from
base case
GT output, MW
ST output, MW
Plant aux. load, MW
Net plant output, MW
Net heat rate, Btu / kWh
3
Incremental costs
Change in total water
cost, $ / h
Change in wastewater
cost, $ / h
Change in capital cost /
net output, $ / kW
1
2
Case 6
1
Case 7
2
Case 1 Case 2 Case 3 Case 4 Case 5 Supp.- Supp.-
Water
Evap. Mech. Absorp. Steam
fired
fired
cooler chiller chiller injection injection HRSG HRSG
5.8
0.9
0.05
6.65
15
15
1
180
20.2
2.4
4.5
18.1
55
35
17
165
20.2
2.1
0.7
17.4
70
35
17
230
21.8
13
400
8.4
270
115
2
75
15.5
3.7
0.2
19
435
85
1
15
0
8
0.4
7.6
90
35
1
70
0
35
1
34
320
155
30
450
Partial supplementary firing.
Full supplementary firing.
3
Based on lower heating value of fuel.
Downloaded from Digital Engineering Library @ McGraw-Hill (www.digitalengineeringlibrary.com)
Copyright © 2006 The McGraw-Hill Companies. All rights reserved.
Any use is subject to the Terms of Use as given at the website.

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