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Combined Heat & Power Plant. Group Meeting # 2 Mentor: Shannon Brown, PE Michael Bentel Jeremy David Erik Peterson Arpit Shah. Questions from Group Meeting #1. What are the specifications for fuel? ~ 80 – 85% - C 2 + ~ 10% - CH 4 ~ 5 % - N 2 ~ 2 % - CO 2 - PowerPoint PPT Presentation
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Combined Heat & Power Plant
Group Meeting # 2Mentor: Shannon Brown, PE
Michael BentelJeremy DavidErik Peterson
Arpit Shah
1
2
Questions from Group Meeting #1What are the specifications for fuel?
~ 80 – 85% - C2+~ 10% - CH4
~ 5 % - N2 ~ 2 % - CO2
What is the primary heat source for the boiler?Combustion gases from Gas Turbine along
with Natural GasBoiler – Heat Recovery Steam Generator
(H.R.S.G.)What is the cheapest source of fuel for
this plant? Waste hydrocarbons from **Team Alpha**
3
Questions (Cont’d)What is the minimum water purity required for
boiler feed water (BFW)? Dissolved O2: < 0.007 ppmTotal Fe: < 0.01 ppmTotal Cu: <0.01 ppmTotal Hardness: 0.05 pH: 8.8-9.6Silica: <2.00 ppmConduction < 150 Total Dissolved Solids (TDS): 0.1
How is the effluent stream from the boiler being addressed?The Effluent stream will be sent through the flue gas
purification system
Group Meeting 2 ObjectivesFlow SheetsMaterial & Energy Balances
Process Flow Sheet FrozenDataHand CalculationsRough Economics
4
Outline 1. Design Basis √2. Block Flow Diagram √3. Process Flow Diagram IN PROGRESS4. Material and Energy Balance IN PROGRESS5. Calculations IN PROGRESS6. Annotated Equipment List (Data Sheet) IN PROGRESS7. Economic Evaluation factored from Equipment Costs8. Utilities9. Conceptual Control Scheme10. General Arrangement – Major Equipment Layout11. Distribution and End-use Issues Review12. Constraints Review13. Applicable Standards IN PROGRESS14. Project Communications File IN PROGRESS15. Information Sources and References IN PROGRESS
5
Pumps and CompressorsAs stated before,
compressor is going to be used to provide plant air
Because instrument air must be very dry to avoid plugging and corrosion, a rotary screw oil free air compressor is commonly put through a dryer 6
Block Numbe
r
Unit Steam Numb
er
Stream Label
16 Compressor
S-16 Air - In
17 Dryer S-17 Plant Air
24 Surge Tank
S-18 Compressed Air
S-19 Compressed Air
S-30 Instrument Air
Air Compressor Material BalanceOil - Free
Air Compress
orRefrigerat
ed Air Dryer
P1 , T1Wet (cfm) P2, T2,
Wet (cfm)
H2O (cfm)
Dry (cfm)
Conditions
P1 11.8 Psi
T1 78 F
% Rel. Humidity 90
Air Density 0.0738 lb/ft3
1 lb Dry Air 13.92 ft3
1 lb Dry Air 0.0192 lb H2O
H20 Density 62.25 lb/ft3
n (Heat Capacity Ratio) 1.4 7
Compressed Air – Energy Balances Dryer Mass Balance ft3 * 1 lb DA/ ft3 * lb H2O/ lb DA = lb H2O * ft3/lb = cfm H2O
Work Done in Compressed Air -W=P1ν1(n/(n-1))[(P2/P1) (n-1)/n-1]
=ZRT(n/(n-1))[(P2/P1) (n-1)/n-1]
Heat of Compression: T2=T1(P2/P1)(n-1/n)
TeamP2
Required (psi) Dry (cfm) Wet (cfm) T2 F H2O (cfm) HP
India 100.00 500.000 500.20 112.96 0.01109 8.34
8
Compressor CostsAnnual Electricity Cost
=
• One of the most expensive sources of energy of plant
• 10% of electricity consumption goes to compressed air generation
• Several compressors may be installed for maintenance purposes as a stand-by spare
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Williston, ND - DataDry Bulb Temperature : 92°F Wet Bulb Temperature: 66°FHighest Relative Humidity: 90%
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Induced – Draft Cooling Tower PFD
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Cooling Tower – General Material BalanceDry Air Mass Balance
ṁa1 = ṁa2 = ṁa
Water Mass Balanceṁhw + ṁa1∙ω1 = ṁcw + ṁa2∙ω2
= ṁhw- ṁcw = ṁa(ω2- ω1)Also,
ṁMU = ṁa(ω2- ω1) + ṁBD
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Cooling Tower – Energy BalanceĖin – Ėout = ΔĖsys ΔĖsys = 0
0 = (ṁa2∙ha2) + (ṁcw∙hcw) – (ṁa1∙ha1) – (ṁhw∙hhw)
ṁa =
**Assuming Steady State and Adiabatic System**
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Data Used to Calculate M&E BalanceStream Enthalpy (h)
(Btu/lb DA)ω
(lb H2O/lb DA)1/ρ (ft3/lb)
Air – In 22.8940 0.01706 18.2149
Air – Out 77.4935 0.1146
Hot Return Water
72.3646
Cold Process Water
33.6199
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Results from M&E Balance - ECT
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Stream Temperature (°F)
Humidity Flowrate (ṁ) (lb/hr)
Energy (Btu/hr)
Air – In 70 ~ 25 % 232,067 5,312,950
Air – Out 90 ~ 90 % 232,067 17,983,714
Hot Return Water
105 317,465 22,973,275
Cold Process Water
85 307,227 10,328,954
Make Up Water
85 10,238 344,209
**Calculated at 11.8 psi
Turbine & Boiler System
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Block Labels
Block Number Block Name1 Pre-Water Treatment2 Pump3 Membrane Assembly4 EDI Module5 Resistivity Cell6 Compressor7 Combustion Chamber8 Gas Turbine9 Steam Turbine
10 Processes11 Condenser12 Stacks13 Economizer14 Evaporator15 Super heater22 Deaerator23 Header25 Separator 17
Stream Labels
Label Stream NameS-1 Plant WaterS-2 Pre - Treated WaterS-3 Pre - Treated WaterS-4 Brine DischargeS-5 Fresh WaterS-6 Pure WaterS-7 Ultrapure WaterS-8 Reheated SteamS-9 Turbine Exhaust Steam
S-10 Low Pressure SteamS-11 Condensed SteamS-12 Hot Combustion GasesS-13 Superheated SteamS-14 AirS-15 Compressed AirS-28 Waste/DischargeS-29 Natural GasS-31 Boiler Feed WaterS-32 Boiler Feed Water - Processes
Results from Boiler Material BalanceStream Flowrate ((lb/hr)
Water – In 107,000
Steam – Out 107,700
18
*Based on ideal system (100% efficiency/recovery, no lose of water/steam due to system leakage)
Results from Boiler Energy Balance
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Sensible Heat (Btu/lb
)
ΔT (°F) Latent Heat
(Btu/lb)
Phase Change
Compression (Btu/lb)
ΔP (psig)
247.077 100 212 1908.300 Liquid Vapor
185.541 0 150
331.510 212 358 1905.334 Liquid Vapor
183.857 150 300
139.909 358 417 1785.464 Liquid Vapor
187.209 300 600
170.453 417 486 1615.044 Liquid Vapor
184.698 600 1200
222.199 486 567 1349.883 Liquid Vapor
802.285 567 1050
Superheated
*Calculated using steam tables and superheated steam tables for latent heat and superheated work, respectively; averaged heat capacity over temperature ranges for sensible heat; PV work for compression.
Flue Gas Clean UpParticle RemovalGaseous Contaminates Removal
Wet Scrubber – Utilizes water for removalWet-Dry Scrubber – Utilizes aqueous spray for
removalDry Scrubber – Utilizes dry powder for removal
Nitrogen Oxide Removal – Utilizes catalysis for removal
Stack – Measures contaminates in out flowing combustion gases
USEPA & NDEPA Flue Gas RequirementsNOx: 100 ppb, averaged over one hour SOx: 1 - hour standard at a level of 75 parts
per billion
CO: 8 - hour primary standard at 9 parts per million (ppm)
Turbine Material BalanceGas Turbine
Airin + Fuelin = Exhaust Gasout mAir + mfuel = mExhaust
Steam TurbineHigh Pressure Steamin = Process Steamout +
Condensing Steamout
mHigh-P = mProcess + mcondensed
22
Turbine Energy BalanceGas Turbine
Combustion Gasin = Workout + Exhaust Gasout
(m*H)Combustion = (effturbine *(m*H)Combustion + ((m*H)Combustion - effturbine *(m*H)Combustion))
Steam TurbineHigh Pressure Steamin =
Process Steamout + Condensing Steamout + Workout
(m*H)high P. = Σ(m*H)process + (m*H)condensed + effturbine *(Σ((m*H)high P – (m*H)process) + ((m*H)high
P. – (m*H)condensed)) 23
Relating Turbine and BoilerEnergy & Material BalanceEnergy - Combustion Gasin – Workout =
Exhaust Gasout = Exhaust Gasin =
Steamout + Exhaust Gasout – Feed WaterinMaterial – Airin + Fuelin =
Exhaust Gasout = Exhaust Gasin = Steamout + Exhaust Gasout – Feed Waterin
24
Results from M&E Balance – Gas TurbineStreams Flow (MMSCFD) Energy
Air 0.028 N/A
Fuel 0.0016 553,366 Btu/mol
Combusted Gas 0.03 362,257,129 Btu/day
25
Equipment ListEquipment Quantity
Reverse Osmosis System 1
Electrodeionization System 1
Water Tube Boiler 1
Gas Turbine 2
Steam Turbine 1
Compressor 1
Dryer 1
H.R.S.G System 1
Induced – Draft Cooling Tower 1
26
CHP - Rough EconomicsWhere,Ce= Purchased Equipment Costa & b = Cost ConstantsS = Size Parameter n = Exponent for that type of equipment
**All equipment costs are based on U.S. Gulf Coast Basis, Jan 2010 (CEPCI index = 532.9)**
27
Equipment Cost TableEquipment a b Supper 0.8*Supper n Ce($)
Cooling Tower
170,000
1,500
10,000 8,000 0.9 5,055,100
**Calculated Using Cost Estimation Equation in “Chemical Engineering Design”, Towler
**Calculated Using “Plant Design and Economics for Chemical Engineers” Online Simulator, 5th Edition
**Estimated Cost from GE
Equipment Cost ($)
Compressor 127,496
Steam Turbine 308,856
Gas Turbine 706,734
H.R.S.G ~20,000,000
Water Purification
System
N/A
28
Equipment Cost Equipment Quantity Cost ($)
Reverse Osmosis System
1 Waiting for Siemens to respond
Electrodeionization System
1 Waiting for Siemens to respond
Gas Turbine 2 1,413,468
Steam Turbine 1 308,856
Compressor 2 254,992
Dryer 1 10,000
H.R.S.G System 1 20,000,000
Induced – Draft Cooling Tower
1 5,055,100
29
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Economics – Cont’dTotal Equipment Cost: $27,032,416Total Cost of Installation: $117,861,333 *Assumption: 4.36*(Cost of Equipment) Total Cost of Engineering: $8,109,724 *Assumption: Engineering costs = 0.30(Cost of Equipment)
Total Cost = Cost of Equipment + Installation + Engineering = $153,003,474
QUESTIONS???
31