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Production of Propylene from Methanol
Florida Institute of Technology
College of Engineering
Department of Chemical Engineering
Senior Design 2015/16
CHE 4182-Chemcial Engineering Plant Design II
Faculty Advisor: Dr. Jonathan Whitlow
Khalid Almansoori, Abdullah Kurdi and Nasser
AlmakhmariApril 27, 2016
Dr. Jonathan WhitlowFlorida Institute of TechnologyDepartment of Chemical Engineering150 W. University Blvd.Melbourne, FL 32901
Dear Dr. Whitlow,
Enclosed you will find the requested report for the design of a production of propylene from methanol plant. As requested, the report includes all parameters and sizes of the new plant, an economic analysis that includes detailed cost estimates and a sensitivity analysis of several parameters that might affect the rate of return on investment, and key environmental and safety considerations.
If you have any questions, comments, or concerns about the report, please do not hesitate to contact us at [email protected], [email protected], or [email protected].
We thank you for giving us the opportunity to work with you in the design of this plant, and we look forward to working with you in the future.
Sincerely,
Khalid Almansoori
_________________________
Abdullah Kurdi
_________________________
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Nasser Almakhmari
_________________________
Table of ContentLetter of Transmittal DONE 1Table of Contents 2Executive Summary DONE 3Introduction DONE 4Process Description DONE
Process Flow Diagram, PFD DONEStream Table DONEUtilities Table DONEEquipment Tables DONE
Process Design and Simulation DONECapital Cost DONEManufacturing Cost DONEProfitability Analysis DONESensitivity Analysis Needs to be UpdatedProcess Control DONE
Process Instrumentation Diagram, PID DONEEnvironmental and Safety Consideration DONEReferences Needs to be alphabetizedAppendix A: Equipment Design Methods, Calculations and Assumptions DONEAppendix B: Capital Cost Sample Calculations DONEAppendix C: Manufacturing Cost Sample Calculations DONEAppendix D: Profitability Analysis Sample Calculations DONEAppendix E: Literature Review Needs work + in body referencing Appendix F: Project Timeline DONE
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Executive Summary
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Introduction
Propylene, also known as propene, is one of the most important raw
materials of the petrochemical industry; it is used in the production of a wide
range of chemical products. There are many ways of producing propylene;
the main industrial routes include Metathesis, Dehydration of Propane (PDH),
Methanol-To-Olefin (MTO) and Methanol-To-Propylene (MTP)(See Appendix E
for more information about the different routes of producing propylene)
(Jasper, 2015).
During the past few years, the gap between the continuous
consumption of the restricted petroleum reserves and the increasing
demand for propylene and its derivatives has been increasing (Wen, 2016).
The traditional petroleum-based production of propylene (such as refinery
fluid catalytic cracking (FCC) and steam thermal cracking of naphtha) is
hardly meeting the market demand (Wen, 2016). As a result, it has become
important to develop economical and energy efficient processes that can fill
the gap and replace the petroleum based production of propylene (Wen,
2016).
The following design project is a production plant for producing on-
purpose polymer-grade propylene using methanol as the feed, also known as
Methanol-To-Propylene (MTP) process. The plant is designed to have a
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production rate of 480,000 metric tons of propylene annually. The design
and simulation of the plant was conducted using Aspen Plus V8.8.
The plant is to be located in Jubail Industrial City, in the Kingdom of
Saudi Arabia. This city is the capital of petrochemical manufacturing in the
kingdom, where most of the petrochemical plants are located. Furthermore,
the kingdom is a large producer of methanol which comes from it having the
6th largest natural gas reserves, and it being the 9th largest producer??. The
kingdom has recently started looking into diversifying its sources of income
and wants to satisfy local petrochemical demand??. Another great advantage,
from a business prospective, is that the kingdom has low corporate tax rates.
The process novelty of this plant lies in the second reactor, MTP
Reactor, catalyst. The catalyst used in this process is Mordenite Zeolite
(HMOR). Mordenite has a silicon to aluminum ratio equal to 5. Comparing
Mordenite to the currently used catalyst in industry, HZSM-5, it was found
from the experimental results that HMOR has twice the selectivity for
producing propylene than HZSM-5 as well as a significantly higher
conversion rate (Moreno-Pirajan, 2013). This higher selectivity reduces the
number of reactors needed in the process from two to one, which will be
discussed further in this report. HMOR also helps in producing other useful
and valuable products such as fuel gas, liquid petroleum gas (LPG), and
gasoline, all of which with high purities (See Appendix D for more information
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about mordenite zeolite and the experimental results as well as the uses of
the by-products).
Polypropylene, propylene oxide, and acrylonitrile are the most
common chemical derivatives from propylene?. Polypropylene takes about
64% of the total propylene consumption; propylene oxide accounts for about
7% of the total propylene consumption; and acrylonitrile takes about 6% of
the total propylene consumption (IHS, 2015). The remaining 23% goes into
the production of other chemical derivatives such as acrylic acid, oxo
alcohols, and cumene (IHS, 2015). Polypropylene is used widely in the
clothing industry and many consumer products such as plastics, ropes, and
carpets?. Propylene oxide goes into the production of propylene glycol which
is used as antifreeze for cars, deicing of aircrafts, and goes into making
cosmetics?. Acrylonitrile goes into the production of acrylic fibers, which are
used in clothing and goes into the production of paints and adhesives? (See
Appendix E for more information about the products of propylene).
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The demand for propylene increases annually and continues to be
driven primarily by developments in the polypropylene industry followed by
the propylene oxide and the acrylonitrile industries (IHS, 2015). Figure 1
shows the increasing world demand and estimates that the demand for the
year 2020 will reach 100 million tons (Galadima, 2015).
Figure 1: Historical and Expected Propylene Worldwide demand (Galadima,
2015)
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The consumers of propylene are many, yet the largest consumers in
the world are China, followed by the United States, then Western Europe,
together they account for about 55% of the global propylene consumption
(IHS, 2015). South Korea and Saudi Arabia are also significant consumers of
the global propylene market as well. The following Figure 2, shows the global
consumption of propylene as of 2014.
Figure 2: Global Consumption of Propylene by Country as of 2014 (IHS, 2015)
The project timeline is found in appendix E. The timeline highlights the
major tasks performed during the Spring semester of 2016 (1/11/2016 –
4/27/2016) to complete this project. The period is represented by the
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semester working weeks, from week 1, the first week of classes, to week 15,
the last week of classes. Most of the semester was spent on reviewing
literature and gathering information as well as simulating the plant.
Process Description
The Process Flow Diagram, PFD, of the plant is shown in Figure 3, with
Stream, Utility, and Equipment tables succeeding it in Tables 1, 2, and 3
respectively. The stream tables show the specifications of each stream in the
plant; that includes the temperature, pressure, vapor fraction, mass flowrate,
mole flowrate, and the composition of the stream. The utility table shows the
equipment unit number, the type of utility used, and the amount of utility
needed. Finally, the equipment tables show each type of equipment and the
design specifications for it.
The feed methanol (via pipeline from a neighboring plant) is pumped
into the process at 3.35 bar and 45 oC (via P-101) at a flowrate of 350,000
kg/hr; the feed then goes through a heat exchanger (E-101) to be vaporized
using low-pressure steam (Hong, 2008). Low-pressure steam is converted to
boiler feed water that can be re-used for other purposes within the plant or
to be sold. The vaporized feed (stream 3) then goes through another heat
exchanger (E-102) to be superheated to 266 oC (Hong, 2008), prior to
entering the Dimethyl-Ether Reactor, DME Reactor (R-101). In the DME
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reactor (R-101), methanol is converted into dimethyl-ether and water via the
following equilibrium reaction (Farsi, 2010):
2CH3 OH⟺CH 3O CH3+H 2 O
The DME reactor is a tabular shell and tube reactor (Farsi, 2010) with packed
aluminum oxide catalyst in the tube side, where the reaction occurs (Lurgi,
2003). The reactor operates isothermally at 300 oC (Hong, 2008). The
product of the DME reactor (stream 5) goes through heat exchanger (E-103)
to heat up the stream to 420 oC (Hong, 2008) prior to entering the Methanol-
to-Propylene reactor, MTP reactor (R-102). In the MTP reactor (R-102),
dimethyl-ether and the remaining unreacted methanol are converted mainly
into Ethylene, Propylene, Butene, Pentene, Hexene, Heptene, Octene, and
Water following the two general form of reactions respectively (Meyers,
2005)(Hadi, 2014):
nCH 3O CH3 →2Cn H 2n+n H 2O n=2 ,…,8
nCH 3OH →Cn H2 n+n H2O n=2,…,8
The MTP reactor is a fixed bed reactor (Jasper, 2015) with mordenite zeolite,
HMOR, catalyst (Moreno-Pirajan, 2013). The reactor operates isothermally at
452 oC(Hong, 2008). Because the reactions taking place in the MTP reactor
(R-102) are exothermic, the stream going to the reactor (stream 6) is split
into six streams to feed the reactor at different levels (Lurgi, 2003); this
method optimizes reaction control of the MTP reactor (R-102) by controlling
the flow of feed into the reactor, which then limits the heat of reaction (Lurgi,
2003). The products of the MTP reactor (R-102) are in the gaseous phase;
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the product stream (stream 7) is then compressed to 6.1 bar via compressor
(C-101) and has a temperature of 610 oC. This hot stream (stream 8) is
cooled down by passing through the shell side of the heat exchanger (E-103)
to heat up stream 5 to its desired temperature, and through the shell side of
the heat exchanger (E-102) to heat up stream 3 to its desired temperature.
The hot stream (stream 10) is finally cooled down to 38 oC via cooling water
in heat exchanger (E-104) before entering the flash separator (V-101). At this
point, stream 11 is partially condensed with water being the majority of the
liquid composition. In the flash separator (V-101), water leaves the separator
from the bottom (stream 13), and the gaseous hydrocarbon mixture from the
top (stream 12). Stream 13 is to be sent to a neighboring wastewater
treatment facility to be treated. Stream 12, containing the gaseous
hydrocarbon mixture, is heated up to 104 oC via high-pressure steam in heat
exchanger (E-105) in preparation for compression. High-pressure steam is
converted to boiler feed water that can be re-used for other purposes within
the plant or to be sold. Stream 14 then enters a two stage compressor series
(C-102 & C-103) with equal pressure ratio and intermediate coolers (E-106 &
E-107) to compress the hydrocarbon mixture and filly condense it in heat
exchanger (E-107). Stream 18 exits heat exchanger (E-107) at 25 bar and 75 oC (Lurgi, 2003) prior to entering the first distillation column (T-101). The first
distillation column (T-101) has 44 stages with the feed entering on the 28th
stage. In this column, the heavy hydrocarbons, mainly C5+, are separated
from the mixture and leave the column as gasoline in the bottoms product at
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a purity of 99.5%. The remaining hydrocarbon mixture leaves the column as
the distillate product and is sent to the second distillation column (T-102).
The second distillation column (T-102) has 33 stages with the feed entering
on the 11th stage. In this column, the C2- hydrocarbons, mainly ethylene in
this particular process, are separated from the hydrocarbon mixture as the
distillate product and leaves the column as fuel gas at a purity of 99.9%. The
remaining mixture leaves the column as the bottoms product and is sent to
the third, and final, distillation column (T-103). The third distillation column
has 48 stages with the feed entering on the 22th stage. In this column,
propylene is separated from the hydrocarbon mixture as the distillate
product and leaves the column at a purity of 99.6%. The remaining
hydrocarbon mixture, mainly butene in this particular process, leaves the
process as liquid petroleum gas, LPG, as the bottoms product at a purity of
91.2%. In general, all product streams (19, 21, 23, and 24) are sent to their
designated storage tanks to be sold.
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Figure 3: Process Flow Diagram, PFD
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Table 1-1: Stream Summary
Stream Number 1 2 3 4Temperature (oC) 45 45 97 266Pressure (bar) 1.00 3.35 3.25 3.05Vapor Mole Fraction 0 0 1 1Flowrate (kg/hr) 350,000 350,000 350,000 350,000Flowrate (kmol/hr) 10,923.
1110,923.
1110,923.
1110,923.
11Component Flowrates (kmol/hr)
Methanol 10,923.11
10,923.11
10,923.11
10,923.11
Water 0 0 0 0Dimethyl-ether 0 0 0 0Ethylene 0 0 0 0Propylene 0 0 0 0Butene 0 0 0 0Pentene 0 0 0 0Hexene 0 0 0 0Heptene 0 0 0 0Octene 0 0 0 0
Stream Number 5 6 7 8Temperature (oC) 300 420 452 610Pressure (bar) 2.70 2.50 1.60 6.10Vapor Mole Fraction 1 1 1 1Flowrate (kg/hr) 350,000 350,000 350,000 350,000Flowrate (kmol/hr) 10,923.
1110,923.
1113,689.
4513,689.
45Component Flowrates (kmol/hr)
Methanol 1,485.24
1,485.24 2.97 2.97
Water 4,718.94
4,718.94
10,901.26
10,901.26
Dimethyl-ether 4,718.94
4,718.94 18.88 18.88
Ethylene 0 0 235.23 235.23Propylene 0 0 1,353.2
61,353.2
6
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Butene 0 0 573.46 573.46Pentene 0 0 136.85 136.85Hexene 0 0 114.04 114.04Heptene 0 0 138.20 138.20Octene 0 0 215.30 215.30
Table 1-2: Stream Summary
Stream Number 9 10 11 12Temperature (oC) 506 383 38 38Pressure (bar) 5.90 5.70 5.50 5.49Vapor Mole Fraction 1 0.61 0.21 1Flowrate (kg/hr) 350,000 350,000 350,000 154,069Flowrate (kmol/hr) 13,689.
4513,689.
4513,689.
452,815.8
2Component Flowrates (kmol/hr)
Methanol 2.97 2.97 2.97 0.17Water 10,901.
2610,901.
2610,901.
26 30.46Dimethyl-ether 18.88 18.88 18.88 18.87Ethylene 235.23 235.23 235.23 235.22Propylene 1,353.2
61,353.2
61,353.2
61,353.2
4Butene 573.46 573.46 573.46 573.46Pentene 136.85 136.85 136.85 136.85Hexene 114.04 114.04 114.04 114.04Heptene 138.20 138.20 138.20 138.20Octene 215.30 215.30 215.30 215.30
Stream Number 13 14 15 16Temperature (oC) 38 104 136 132Pressure (bar) 5.49 5.29 11.65 11.45Vapor Mole Fraction 0 1 1 1Flowrate (kg/hr) 195,932 154,069 154,069 154,069Flowrate (kmol/hr) 10,873.
632,815.8
22,815.8
22,815.8
2Component Flowrates (kmol/hr)
Methanol 2.80 0.17 0.17 0.17Water 10,870. 30.46 30.46 30.46
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80Dimethyl-ether 4.39E-
03 18.87 18.87 18.87Ethylene 0.01 235.22 235.22 235.22Propylene 0.02 1,353.2
41,353.2
41,353.2
4Butene 8.66E-
04 573.46 573.46 573.46
Pentene 1.34E-05 136.85 136.85 136.85
Hexene 6.58E-07 114.04 114.04 114.04
Heptene 4.23E-08 138.20 138.20 138.20
Octene 2.05E-09 215.30 215.30 215.30
Table 1-3: Stream Summary
Stream Number 17 18 19 20Temperature (oC) 168 75 236 58Pressure (bar) 25.20 25.00 25.32 25.00Vapor Mole Fraction 1 0 0 0Flowrate (kg/hr) 154,069 154,069 56,745 97,324Flowrate (kmol/hr) 2,815.8
22,815.8
2 603.00 2,212.82
Component Flowrates (kmol/hr)
Methanol 0.17 0.17 0.17 0.01Water 30.46 30.46 0.98 29.48Dimethyl-ether 18.87 18.87 4.12E-
04 18.87
Ethylene 235.22 235.22 2.19E-08 235.22
Propylene 1,353.24
1,353.24
1.62E-03
1,353.24
Butene 573.46 573.46 1.84 571.62Pentene 136.85 136.85 132.48 4.37Hexene 114.04 114.04 114.04 4.30E-
07Heptene 138.20 138.20 138.20 4.68E-
14Octene 215.30 215.30 215.30 9.43E-
21
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Stream Number 21 22 23 24Temperature (oC) -21 75 59.39 117.71Pressure (bar) 25.00 25.24 25.00 25.34Vapor Mole Fraction 0 0 0 0Flowrate (kg/hr) 6,596 90,728 56,865 33,863Flowrate (kmol/hr) 235.00 1,977.8
21,351.0
0 626.82Component Flowrates (kmol/hr)
Methanol 8.28E-16 0.01 6.83E-
13 0.01
Water 1.20E-08 29.48 7.86E-
05 29.48
Dimethyl-ether 3.97E-05 18.87 4.85 14.03
Ethylene 234.77 0.46 0.46 4.10E-13
Propylene 0.23 1,353.00
1,345.60 7.40
Butene 4.06E-06 571.62 0.10 571.52
Pentene 2.17E-12 4.37 4.90E-
10 4.37
Hexene 1.79E-23
4.30E-07
3.95E-23
4.30E-07
Heptene 0 0 0 0Octene 0 0 0 0
Table 2: Utility Summary
Equipment Number E-101 E-104 E-105 E-106Utility Type LPS CW HPS CWAmount of Utility (ton/hr) 188.7 10,953 18.6 18.1Equipment Number E-107 E-108 E-109 E-111Utility Type CW CW HPS LPSAmount of Utility (ton/hr) 1,046 792.7 13.1 0.793Equipment Number E-112 E-113 R-101 R-102Utility Type CW LPS CW CWAmount of Utility (ton/hr) 761 0.45 3,645 13,498Equipment Number C-101 C-102 C-103 P-101Utility Type Electricity Electricity Electricity Electricity
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Amount of Utility (MW) 39.3 2.4 2.4 0.04Equipment Number P-102 P-103 P-104Utility Type Electricity Electricity ElectricityAmount of Utility (MW) 0.04 0.02 0.05
Table 3-1: Equipment Summary
Pumps
P-101 A/B P-102 A/B
Centrifugal / electric drive Centrifugal / electric driveCarbon steel Carbon steelPower = 36.4 kW Power = 37.6 kW82% efficient 81% efficientP-103 A/B P-104 A/B
Centrifugal / electric drive Centrifugal / electric driveCarbon steel Carbon steelPower = 17.1 kW Power = 48.0 kW74% efficient 82% efficient
Table 3-2: Equipment Summary (continued)
TowersT-101 T-102Carbon steel Carbon steel44 CS sieve trays plus reboiler and condenser
33 CS sieve trays plus reboiler and condenser
60% efficient trays 70% efficient traysTotal condenser (E-108) Total condenser (E-110)Feed on tray 28 Feed on tray 11
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Reflux ratio = 0.81 Reflux ratio = 8.972 ft tray spacing 2 ft tray spacing Column height = 32.2 m Column height = 24.1 m Diameter = 4.8 m Diameter = 2.2 m T-103 Carbon steel48 CS sieve trays plus reboiler and condenser70% efficient traysTotal condenser (E-112)Feed on tray 22Reflux ratio = 2.622 ft tray spacing Column height = 35.1 m Diameter = 3.3 m
Table 3-3: Equipment Summary (continued)
ReactorsR-101 R-102Carbon steel, Shell & Tube, Packed tubes, Aluminum Oxide Catalyst
Carbon steel, Process vessel, Fixed bed, HMOR Zeolite Catalyst
V = 102 m3 V = 164 m3Length = 8 m, Tube Diameter = 0.09 m L/D = 3.02000 Tubes 100% filled with active catalystTubes are 100% filled with active Q = -281,784 MJ/hr
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catalystQ = - 75785 MJ/hrVesselsV-101 V-102Carbon steel Carbon steelVertical Horizontal L/D = 3.0 L/D = 3.0V = 1956 m3 V = 63 m3V-103 V-104Carbon steel Carbon steelHorizontal Horizontal L/D = 3.0 L/D = 3.0V = 27 m3 V = 79 m3
Table 3-4: Equipment Summary (continued)
Compressors
C-101 C-102
Carbon steel Carbon steelReciprocating ReciprocatingPower = 39.3 MW Power = 2.4 MW
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85% adiabatic efficiency 75% adiabatic efficiencyC-103
Carbon steelReciprocatingPower = 2.4 MW75% adiabatic efficiencyHeat Exchangers
E-101 E-102
A = 1,650 m2 A = 133 m2
Floating head, carbon steel Floating head, carbon steelProcess stream in tubes Process stream in tubes & shellQ = 447,992 MJ/hr Q = 106,285 MJ/hr
Table 3-5: Equipment Summary (continued)
Heat Exchangers (continued)
E-103 E-104
A = 394 m2 A = 2,767 m2
Floating head, carbon steel Floating head, carbon steelProcess stream in tubes & shell Process stream in tubes
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Q = 95,553 MJ/hr Q = 742,877 MJ/hrE-105 E-106
A = 136 m2 A = 4.2 m2
Floating head, carbon steel Double pipe, carbon steelProcess stream in tubes Process stream in pipesQ = 45,728 MJ/hr Q = 1,231 MJ/hrE-107 E-108
A = 298 m2 A = 572 m2
Floating head, carbon steel Floating head, carbon steelProcess stream in pipes Process stream in pipesQ = 70,956 MJ/hr Q = 52,871 MJ/hr
Table 3-6: Equipment Summary (continued)
Heat Exchangers (continued)
E-109 E-110
A = 1,329 m2 Area = 1,634 m2
Floating head, carbon steel Floating head, carbon steelProcess stream in tubes Process Stream in Tubes
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Q = 25,176 MJ/hr Q = 19,238 MJ/hrE-111 E-112
Area = 25 m2 Area = 600 m2
Floating Head, carbon steel Floating head, carbon steelProcess Stream in Tubes Process Stream in TubesQ = 2,024 MJ/hr Q = 51,621 MJ/hrE-113
Area = 21 m2
Floating head, carbon steelProcess Stream in PipesQ = 1,056 MJ/hr
Table 3-7: Equipment Summary (continued)
Storage Tanks
V-105 V-106
Methanol Storage Fuel gas StorageVolume: 32784 m3 Volume: 1374 m3
Capacity for 3 days Capacity for 3 days
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Vertical tank on concrete pad Vertical tank on concrete padV-107 V-108
Propylene Storage Gasoline StorageVolume: 9331 m3 Volume: 10074 m3
Capacity for 3 days Capacity for 3 daysVertical tank on concrete pad Vertical tank on concrete padV-109
LPG StorageVolume: 5555 m3
Capacity for 3 daysVertical tank on concrete pad
Process Design and Simulation (references + in text citation)
The plant was designed and simulated using Aspen Plus simulator from
Aspen Technology Inc., version 8.8. The Aspen Plus design simulation of the
plant can be seen in Figure 4, at the end of this section. In general, Aspen
Plus and the heuristics from Turton were used to find the sizing parameters
needed for designing and costing purposes of the plant equipment.
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Prior to starting the simulation of the plant, a property method had to
be chosen. Due to the majority of the components used in the plant being
nonpolar, the Peng-Robinson Equation of State was chosen as the property
method for this plant design(1N) (See Appendix D for more information about
the process of selection of the property method).
The following is a summary of how each type of equipment in the plant
was designed and the assumptions made. Detailed design methods,
assumptions, and calculations for each unit can be found in appendix A.
Pumps Design
Pumps were designed and simulated using Aspen Plus via inputting the
desired pressure discharge. The pressure discharge was specified based on
the desired pressure for a certain stream. Aspen Plus calculates the break
power and pump efficiency.
Heat Exchanger Design
Heat exchangers were designed and simulated in Aspen Plus via
inputting exchanger specifications, pressure drop, and heat transfer
coefficient “U”. Heuristics were used in determining the pressure drop and
heat transfer coefficient “U” values, which varied based on the application of
the heat exchanger and the fluids passing through the shell and tube sides.
From the inputted information, Aspen Plus calculates the area and heat duty
of the heat exchanger, which was then used for designing and costing
purposes.
Compressor Design
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Compressors in the plant were designed and simulated in Aspen Plus
via inputting compressor type, discharge pressure, and the efficiency of the
compressor. The discharge pressure was determined based on the process,
while the type of compressor and the efficiency were obtained from
heuristics. From the inputted information, Aspen Plus is able to calculate the
break horsepower, which was then used for designing and costing purposes.
Flash Separator & Reflux Drum Design
The flash separator and reflux drums in the plant were designed and
simulated in Aspen Plus. The specified variables were pressure and duty. The
holdup time, the length to diameter ratio, and the orientation of the vessel
were all based on heuristics; from these values with the use of the
volumetric flowrate the volume of the vessel was calculated, which was then
used for design and costing purposes.
Distillation Column Design
The distillation columns were designed and simulated in Aspen Plus.
The amount of distillate/bottom product was specified, and based on the
desired purity the reflux ration was varied. Furthermore, the condenser
pressure was determined based on the process, with the appropriate
pressure drop from heuristics. The columns were then optimized following
the optimization process (Whitlow, 2016) to obtain the optimum number of
stages, reflux ratio, and feed stage. The type of trays were specified in Aspen
Plus, which led to determining the column diameter and number of passes.
Finally, tray spacing, tray efficiency, and column height were determined
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using heuristics. All of the previous variables were obtained and used for
designing and costing of purposes.
Reactor Design
The first reactor, DME reactor (R-101), was designed and simulated in
Aspen Plus. The reactor was designed to operate isothermally (Hong, 2008),
and was modeled as a heat exchanger with the feed flowing into the tube
side, where the aluminum oxide catalyst is packed (Lurgi, 2003), and cooling
water in the shell side (Farsi, 2010). The number of tubes, diameter of tube,
and reactor length were all obtained from literature (Farsi, 2010); they were
used to find the volume of the reactor for designing and costing purposes.
The second reactor, MTP reactor (R-102), was simulated in Aspen Plus.
This reactor was a challenge to simulate due to the lack of reaction kinetics.
Several attempts were made to accurately simulate this reactor, but the
complexity was high and it was hard to simulate on Aspen Plus (refer to
appendix D for further information about the different attempts tackled in
designing this reactor). From the stoichiometric study of the reaction
outputs, it was concluded that some of the side products were produced in
very small amounts, compared to the major products, and neglecting them is
a safe assumption. This assumption was then made to simplify the Aspen
Plus simulation. This reactor is a fixed bed with mordenite zeolite catalyst,
and operates isothermally. The reactor volume was determined using the
weighted hourly space velocity “WHSV” (Moreno-Pirajan, 2013); heuristics
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were used to find the length to diameter ratio, all of which were obtained
and used for designing and costing of purposes.
Storage Tank Design
Storage tanks were not simulated on Aspen Plus, yet they were
designed based on feed and product flowrate, and heuristics. Heuristics were
used to determine the holdup time and orientation of the tanks. Using the
holdup time and the flowrate, the volume of the tank can be determined,
which was then used for designing and costing purposes.
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Figure 4: Aspen Plus view of Plant Design Simulation of the Process
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Capital Cost
The following section discusses the capital cost of the plant using the
methodology discussed in the Analysis, Synthesis and Design of Chemical
Processes, by Turton(1); it consists of several sources and helpful parameters
in estimating the cost of process equipment. The capital cost is the sum of
the costs of all process units. It is important to note that the data used in the
calculations are based on a survey of equipment manufacturers that were
taken in the year of 2001; the average Chemical Engineering Capital Cost
Index (CEPCI) was used to account for inflation. In 2001, CEPCI value was
397; the CEPCI for the 2016 was provided by Dr. Whitlow as 605, since the
data was last updated in 2010 (Turton, 2012). The index was used to update
the total capital cost to estimate the 2016 value of the plant. There were
some assumptions made in the design, all of which are mentioned in the
following Table 1.
Table #: Assumptions Made in Calculating the Cost of certain Equipment
Unit AssumptionsOver Design Factor A safety over design factor of 10 %
Heat Exchangers
Some heat exchangers found to have capacity not within the range. The capacity was forced to be within the range by dividing by lowest possible number of exchangers. The final cost was multiplied also by the number of exchangers.
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Table () (Cont.): Assumptions Made in Calculating the Cost of certain Equipment
Unit Assumptions
Reactors
DME Reactor is modeled as a shell and tube heat exchangers – floating head
MTP Reactor is modeled as process vessels
A cooling jacket for the MTP reactor was accounted for as 25% of the cost of the MTP reactor. The cost of the jacket was added to the final price of the reactor.
Vessels
All of Towers were modeled as Process Vessels (vertical).
The assumptions were made to findFP, Vessel, FM, B1, and B2.
I. Capital Methodology
Purchased Equipment Cost
The following equation was used for calculating the purchased cost of
the equipment, assuming ambient operating pressure (Turton, 2012):
log10 Cpo=K1+ K2 log10 ( A )+K3 [ log10 ( A ) ]2
C po: Purchased cost
A: Capacity or size parameter for the equipmentK1, K2, and K3: Coefficients that depends on the type of the equipment, given constants (Turton, 2012)
Purchased Equipment Cost (for capacities out of the range)
Some of the equipment were found to have capacity not within the
range. The capacity was forced to be within the range by assuming there
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were more than one piece of the equipment. The final cost was multiplied by
the number of equipment.
Pressure Factors for Process Vessels
FP, Vessel
( P+1 )∗D2[850−0.6 (P+1 )]
+0.00315
0.0063
The previous equation was used to determine the pressure factors for
Vessels and Towers. P is the pressers in barg, and D is the diameter in meter.
There are three Towers; all of the towers operating at the same pressure but
different diameter. The values of FP, Vessels were found to effects the cost due to
the high pressure factors value.
Pressure Factor for other Process Equipment
The pressure factor, FP, for other equipment such as Pumps, Heat
Exchangers, Compressors, and Reactors in the plant was found using the
following equation:
log10 Fp=C1+C2 log10 ( P )+C3 [ log10 ( P ) ]2
P: Design pressure in barg
C1, C2, and C3: Coefficients can be found by the type of the equipment
(Turton, 2012)
Material Factors for Heat Exchangers, Process Vessels, and Pumps:
The values of the material factors, FM, for heat exchangers, process
vessels and pumps were obtained from Turton (Turton, 2012).
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Bare Module Factor for Heat Exchangers, Process Vessels, Pumps and
Compressor:
CBM=C po FBM=C p
o (B1+B2 FM Fp)
CPo: Purchased CostFBM: Bare module factorB1 and B2: given constants (Turton, 2012)FM: Material Factor used to find the cost for different materials of construction. Fp: Pressure Factor
Bare Module and Material Factors for the Remaining Process
Equipment
The values of the Bare Module and Material Factors, FBM and FM for the
remaining equipment were obtained from Turton (Turton, 2012).
Bare Module Cost for Sieve Trays
In the case of sieve trays, the bare Module cost was calculated
differently; the value of CBM is obtained using the following equation:
CBM=C po N FBM Fq
CPo: Purchased CostN: number of traysFBM: Bare module factorFq: Quantity factor for trays The quantity factor for trays, Fq, for N ≥ 20: Fq = 1
Using this equation if N ≤ 20: log10 Fq=0.4771+0.08516∗log10 (N )−0.3473 [ log10 ( N ) ]2
CEPCI Costing Correction to 2016
Ca=Cb(Aa
Ab)
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Where Ca is the cost of the equipment in 2016, Cb is the cost of the
equipment in 2001, Aa is the CEPCI in 2016 given by Dr. Whitlow to be 605,
as a fixed assumption, and Ab is the CEPCI in 2001 which is 397.
II. Capital Results
Table (): Cost of Each Piece of Equipment
Equipment Unit # Cost (2016 $)
PumpP-101 A/B $57,000P-102 A/B $58,100P-103 A/B $39,600P-104 A/B $66,000
Vessel V-101 $15,300,000V-102 $480,000V-103 $210,000V-104 $600,000
Heat Exchangers
E-101 $755,000E-102 $95,000E-103 $193,000E-104 $1,300,000E-105 $96,000E-106 $10,000E-107 $156,000E-108 $266,000E-109 $610,000E-110 $750,000E-111 $60,000E-112 $278,000E-113 $60,000
CompressorsC-101 A/B $29,320,000C-102 A/B $3,550,000C-103 A/B $3,530,000
TowersT-101 $9,470,000T-102 $900,000T-103 $3,480,000
Sieve Trays T-101 $680,000 AKA 35
T-102 $83,000T-103 $270,000
Reactors R-101 $63,000R-102 $653,000
Table ()(Cont): Cost of Each Piece of Equipment
Tanks
V-105 (Methanol Storage) $ 22,800,000
V-106 (Fuel Gas Storage) $ 1,600,000
V-107 (Propylene Storage) $ 6,600,000
V-108 (Gasoline Storage) $ 7,000,000
V-109 (LPG Storage) $ 3,900,000
The following figure () shows the total costs of the equipment used in the
plant.
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220000; 0.2% 16600000; 14.4%
4600000; 4.0%
36400000; 31.6%15000000; 13.0%
700000; 0.6%
41800000; 36.2%
Fixed Capital Cost
Pumps Vessels Heat Exchangers CompressorsColumns\Towers Reactors Tanks
Figure (): Total Cost of Equipment where are tanks?
The total capital cost was found to be $ 175,400,000. From figure 3, it
can be noticed that the storage tanks govern the majority of the capital cost
with 36.2%, the second large cost is for the compressors, occupying 31.6 %
of the total capital cost, and the least expensive cost is the pumps, which
occupy 0.2% of the total capital cost.
Manufacturing Cost
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After calculating the capital investment needed to build the production
of Propylene from Methanol plant, the operational investment is to be
determined. There are three types of manufacturing costs to take into
account: Direct Manufacturing costs, Fixed manufacturing costs, and General
Expenses.
Direct Costs are dependent on production rate, and it includes raw
materials, utilities, labor, waste treatment, supplies, maintenance, lab
charges, and patents & royalties. Fixed costs are independent of production
rate, and it includes taxes & insurance and plant overhead. Finally, general
expenses costs are loosely tied to the production rate, and it includes sales
and marketing, research & development and administrative costs.
The following sections shows the manufacturing cost for the production
of Propylene from Methanol plant, using the methodology stated in Turton
(Turton, 2012).
There are values that need to be found first to calculate the COM. The
First value is FCI (fixed capital cost), COL (Cost of operating labor), CUT (Cost of
Utility), CWT (Cost of wastewater), and CRM (Cost of raw material). The
Following equation was used to calculate COM without Depreciation:
COM=(0.18× FCI )+(2.73 ×COL)+(1.23 ×(CUT+CWT+CRM))
I. Manufacturing Methodology
Operating Labor
Labor Wages and Total number of operators are needed to calculate
the COL. Annual Labor wages were found to be 52500$ in 2014 (51-9011
AKA 38
Chemical Equipment Operators and Tenders, 2015). The Annual labor wages
in 2016 is $53550 by assuming 2 percent increasing from 2014. To calculate
the total number of operators is by using this equation
NOL׿ of operator hired for eachoperator .
NOL=√6.29+31.7 P2+0.23N np
The previous equation represents the number of operators per shift. P
is the number of steps involving particulate solids handling. Nnp is the number
of steps not involving particulate solids handling. P will be zero because
there are no solids that need handling such as no transportation or
Particulate removal. Nnp is the number of none particulate process includes
reactors, towers, compressor, and heat exchanger; Pump and Vessel are not
included (Turton, 2012). The number of operator hired for each operators is
found to be 4.3 and this number should be rounded to 4.5. Using the
following equation, The Cost of operating labor will be $963,900
C OL=The Annual labor wages ×Total number of operators
Cost of waste treatment
Wastewater: the only waste of the process is water. Using the mass
flow rate. The price found to be equal to 0.041 $/MT (Turton, 2012). The cost
of waste treatment is equal to $67,479 per year.
Utility Cost:
In this section, the expenses associated with electricity, cooling water,
process steam and many other utilities are accounted for. It is important to
note that the cost of utilities are dependent on both inflation and energy
AKA 39
cost. The main utilities needed in the plant are electricity, cooling water,
high-pressure steam, low-pressure steam, and refrigerant; these utilities are
used in the plant in the heat exchangers, reactors, compressors, and pumps.
Table 4 shows the total amount of each utility needed in the plant annually,
and the price and annual cost of each utility.
Table 4: Price, Total Amount, and Cost Annually Needed for Utilities
Cost (2016 $)
Total Amount Needed
Cost ($/yr) in 2016
Electricity ($/kW-hr) 0.0718 367,045,401 $26,400,000Cooling water ($/kg) 0.0000175 258,002,773,140 $4,500,000High Pressure Steam
($/kg) 0.01459 266,292,516 $3,900,000Low Pressure Steam
($/kg) 0.01348 1,595,698,056 $21,500,000Refrigerant ($/GJ) 11.2671 16,175 $182,000
The total utility cost, from Table 4, is $58,100,000. It can be noticed
from Table 4 that the cost of electricity occupies a large part of the total with
46.74 % of the cost. The next largest utility is low-pressure steam with a
total cost of $21,500,000, which is 38% of the total utility cost.
For the cost of electricity, the cost was linearly extrapolated using the
data found in the U.S. Energy Information Administration (Electric Power
Monthly, 2015) to find the estimated price in 2016. All the calculation that
are involved in the manufacturing cost of Methanol to Propylene plant are
presented in Appendix C. For cooling water, high pressure steam, low-
pressure steam, and refrigerant. Due to the dependence of cooling water on
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electricity, the change in cooling water cost and refrigerant cost were based
on the total annual increase in the cost of electricity between 2006 and
2015. Due to the dependence of high and low pressure steam on natural gas,
High pressure steam and low pressure steam change in cost were based on
the total annual increase between 2009 and 2015 for natural gas (Annual
Energy Outlook 2015, 2015) (See Appendix C). The data presented in
Appendix C shows the linear extrapolation that was used the electricity cost
and for the natural gas.
Cost of raw Material
The raw materials in the methanol to propylene production are
Methanol, and catalyst. The mass flowrate of methanol was 350000 kg/hr.
Moreover, the price of methanol was found to be 235 $/ton (Argaam
Petrochemical Index Loses 3.7 Pts as Polymers, 2015). Therefore, the mass
flowrate was converted in ton / year in order to find the final cost in unit of
$/year. The amount need for Aluminum Oxide Catalyst was 402.9 ton/yr for
the first reactor (DME), the life time for the catalyst is ten years. The amount
needed for Mordenite Zeolite Catalyst was 344.4 ton/yr for the second
reactor (MTP). the price of Aluminum Oxide Catalyst was found to be 1000
$/ton and the Mordenite Zeolite Catalyst was found to be 120 $/ton
(Aluminum Oxide price, 2016).
II. Manufacturing Results
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The sample calculations for the cost of Manufacturing can be found in
Appendix C. The following Table () shows a summary of the costs included in
the manufacturing of the plant.
Table (): Summary of the Costs included in the Manufacturing Cost
Direct Manufacturing Costs $791,600,000Direct Supervisory and Clerical
Labor $173,000Maintenance and Repairs $10,500,000Fixed Manufacturing Cost $12,600,000Local taxes and Insurance $5,600,000
Plant Overhead costs $6,900,000Raw Materials $691,300,000
Utilities $56,400,000Operating Labor $963,000Waste treatment $103,000
Lab Charges $145,000Patents and Royalties $28,700,000
Fixed Capital Investment $175,400,000Cost of Manufacturing $956,100,000
General Expenses $154,700,000Administration Costs $1,800,000
Distribution and Selling Costs $105,100,000Research and Development $47,800,000
Form Table 5, the total manufacturing cost of the plant is
$953,618,411 while the fix capital investment is $172,935,343. The direct
manufacturing cost is $789,675,600; the fixed manufacturing cost is
$12,442,044 and the general expenses have a total of $154,305,974.
Table (6): Direct Costs Distribution
Maintenance and Repairs
10,500,000 1.32%
Raw Materials 691,300,0 87.74%
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00
Utilities
56,400,000 7.16%
Operating Labor 963,000 0.12%
Waste treatment 103,000 0.01%
Lab Charges 145,000 0.02%
Patents and Royalties
28,700,000 3.63%
Table (6) above shows the distribution of the direct costs between its
elements; it can be noticed that Raw material take a large part of the pie
chart with an 87.74% of the total direct cost. The second largest cost is for
the utilities of the plant, which occupies 7.16% of the pie chart. The third
largest segment in the pie chart is Patents and Royalties occupying 3.63% of
the direct costs. Maintenance and Repairs occupy 1.32%, while operating
labor, waste treatment, and lab charges occupy 0.12%, 0.01% and 0.02%
respectively.
Profitability Analysis
I. Profitability Methodology: Profitability of the methanol to propylene plant was determined
through several steps. The product annual flow rate and the cost of the
product were calculated in order to find the revenue. A spreadsheet was
used to calculate the profitability analysis and some assumptions were made
in the profitability calculation; details are shown in Appendix D. The land cost
was assumed to be equal to 5 million dollars. In addition, the annual interest
AKA 43
rate was assumed to be 6 % (Turton, 2012). The revenue was assumed to
increases by 6 % annually based on products price trends (Dukandar, 2016),
and the operation cost by 2 % annually. The tax rate was assumed to be 20
% (Saudi Arabia: Tax System, 2016); while the working capital was assumed
to be 15% of the fixed capital investment(Turton, 2012). The construction
period was assumed to be two years, with an expected plant lifetime of ten
years (Turton, 2012).
Table 7: Annual revenue
ProductsAmount
Annually (MT/yr) Price ($/MT) TotalPropylene 477668.52 1250 $597,085,650Ethylene 55405.812 1000 $55,405,812
LPG 284446.008 45 $12,800,070Boiler Feed
Water 1741230.54 2.45 $4,266,015 (L/yr) Cost ($/L)
Gasoline 1175309856 0.3 $352,592,957
The most up to date prices for all products are shown in table (7).
Propylene price is 1250 dollar per MT (Dukandar, 2016).From Saudi Aramco,
liquefied petroleum gas (LPG) prices for September 2016 are 20-45$ /ton
(Argaam Petrochemical Index Loses 3.7 Pts as Polymers, 2015)The price of
the ethylene is 1177 $/MT (Dukandar, 2016). The price of gasoline depends
on the location, in Saudi Arabia the gasoline is considered one of cheapest
country comparing to other countries, the price of gasoline is 0.3 $/L (Petrol
AKA 44
Prices Across the World, 2016). Boiler feed water is produced in this plant,
the steam can be sold to other neighboring plant for 2.54 $/MT (Turton,2012)
II. Profitability Results:
0 1 2 3 4 5 6 7 8 9 10 11 12-$200,000,000
$0
$200,000,000
$400,000,000
$600,000,000
$800,000,000
$1,000,000,000
$1,200,000,000
$1,400,000,000
Cash Flow
Time (year)
Cash
Flo
w, M
illio
n US
Dol
lars
Figure 2: Cumulative Future vs. Time
Based on Figure 2 above, it can be concluded that the breakeven point
is going to be at fifth year of operation. The revenue in the fifth year will be $
26,700,000.
The discounted cash flow rate of return (DCFROR) was found to be at a
37.34% annually interest rate.
AKA 45
Sensitivity Analysis
AKA 46
Process Control
The process instrumentation diagram, PID, is shown in Figure #. The
diagram displays the control scheme that is proposed for the plant. It should
be noted that only the important controls are shown in order to avoid
complicity and to emphasis important controlling areas.
As illustrated on heat exchanger E-101, it utilizes a feedback control
loop that determines the outlet feed temperature and maintains the cooling
water stream; the cooling water valve is to fail open. Moreover, a feedback
control loop is used in all the condensers that are using cooling water and
the coolers that are used in the multistage compressors as well, yet that is
not shown in the P&ID to avoid complicity. The feedback control loop, as
shown on the condenser in Figure #, is to monitor the process stream’s
outlet temperature and manipulate the cooling water valve to adjust the feed
temperature.
As illustrated on heat exchanger E-105, when the stream is heated up,
a feed backward loop is used to regulate the outlet temperature of the feed;
the valve here is to fail close. In addition, advance controlling is applied on
the steam valve via cascade to manipulate the steam flowrate to control the
temperature. Likewise, this control loop is to be used in all the distillation
column reboilers.
On distillation columns and reflux drums, the level of the liquid is
controlled via feed backward loop that manipulates a fail open valve on the
AKA 47
liquid outlet. On distillation column condenser, the reflux ratio is manipulated
by a ratio controller. The ratio controller manipulates a fail open valve that
controls the flow ratio of the reflux and the product that goes to the storage
tank.
In the flash separator V-101, the pressure is controlled using a fail
open valve adjusted on the gas phase stream outlet, and the liquid level is
controlled by fail closed valve adjusted on the liquid stream output. For
advance controlling, the stage temperatures in all the distillation columns
are cascaded with the liquid output to insure achieving purities. Figure #
presents the detailed controlling on one of the distillation columns, which is
also applies to the rest. Finally, Figure # shows the water jacket design on
the MTP reactor with necessary controlling (Refer to appendix D for the
discussion on Relief Systems).
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Figure #: Process Instrumentation Diagram, PID
AKA 49
AKA 50
Figure #: Distillation Column Process Instrumentation Diagram
Figure #: MTP Reactor (R-102) with Water Jacket Process Instrumentation Diagram AKA 51
Environmental and Safety Considerations
Based on the analysis that presented on table 2 and 3, it could be
noticed that there are several consideration with regards to the environment
and safety impacts. The environmental and safety impacts of the chemical
plant could affect the employers as well as the people in the surrounding
area. These impacts could be resulted in different forms such as gases
vented to the atmosphere, the catalyst waste and the noise that could be
produced from the plant units. The main product of the plant and also the
side products are flammable hydrocarbons. Based on the simulation of the
process, the distillation columns are operating under high pressure to
achieve the needed purities. In the distillation columns, relief system was
designed to prevent inadvertent release of gases from the distillation
columns. In addition to that, the plant operates under high pressure
therefore, it might cause a pipe rupture which might lead to escape gas to
the environment. Pipe rupture due to high pressure can be prevented by
using proper thickness and insulate the pipes to prevent heating the surface
in the summer time. The lifetime of the mordenite zeolite catalyst is one
year. The waste catalyst is going to be disposed because it has no significant
effects on the environment and it is nonhazardous waste [N1]. It was assumed
that the catalyst will be likely disposed in the landfill. All unites in the
chemical plant are emanating noise which can annoy people around the
plant therefore, perimeter barrier is an ideal option to reduce the noise to
minimum. The environmental precautions in the case of accidental releases
AKA 52
are to, carefully contain and stop the source of the spill, if safe to do so.
Protect bodies of water by diking, absorbents, or absorbent boom, if possible.
Do not flush down sewer or drainage systems, unless system is designed and
permitted to handle such material.
As shown in table (N2), there are several safety consideration in the plant
due to the presence of high temperature, high pressure, toxicity of the
chemicals, and the flammability of the chemicals in the plant. As safety
procedures, a relief system should be designed in the vessels to prevent
rapture due to excessive pressure. Fail- open valves were placed in each
vessel to insure that no overheat occurs. In addition, water jacket was
designed in the MTP reactor to control the exothermic reactor temperature.
The main product and the side products of the plant are extremely
flammable and toxic. Therefore, the storage areas should be handled with
extreme care. All the employers I the plant should follow the regulations and
use the Personal Protective Equipment
Emergency planning is primarily for the protection of plant personnel
and people in nearby areas and the environment that could be affected by
plant problems. It should be considered early in the design and should be
coordinated with the existing site emergency plan. Emergency planning
includes tornado and storm shelters, flood protection, earthquakes, proximity
to public areas, and safe exit routes. It also includes planning for the effect
that an emergency in the "new process" would have on other plants, and the
effect that an emergency in another plant would have on the new process.
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The effects of potential spills on waterways and aquifers should be
considered [N5].
Designing relief-venting systems is important to ensure that flammable
or toxic gases are vented to a safe location. This will normally mean venting
at a sufficient height to ensure that the gases are dispersed without creating
a hazard. For highly toxic materials it may be necessary to provide a
scrubber to absorb and “kill” the material; for instance, the provision of
caustic scrubbers for heavy hydrocarbons. If flammable materials have to be
vented at frequent intervals; as, for example, in some refinery operations,
flare stacks are used [N6].
A deluge system is a water mist system using open spray heads
attached to a piping system that is connected to a water supply through a
valve that is opened by means of a detection system installed in the same
area as the spray heads. When the valve opens, water flows into the piping
system and discharges through all spray heads attached to the system.
Deluge systems are typically used for the protection of machinery with
flammable liquid fire hazard [N7].
References Needs to be alphabetized + add Nasser and Khalid
1 Chemical process safety, 2nd ed, daniel a. crowl, joseph f. louvar.
(n.d.).
2 - http://www.iza-online.org/natural/Datasheets/Mordenite/mordenite.htm
3-
https://www.fas.org/sgp/crs/homesec/R43070.pdf
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4 -
http://mci.gov.sa/en/LawsRegulations/SystemsAndRegulations/chemicals/
Pages/regulation.aspx
7- Deluge Suppression System. (n.d.). Retrieved April 23, 2016, from
http://www.marioff.com/fire-protection/hi-fogr-suppression-system-
types/deluge-suppression-system
Meyers, R. (2005) Handbook of Petrochemicals Production Processes. LURGI
MTP® TECHNOLOGY, AccessEngineering
Lurgi MTP Plant Process Description. (2003). CHE397Hotel
Farsi, M., Jahanmiri, A., & Eslamloueyan, R. (2010). Modeling and
Optimization of MeOH to DME in Isothermal Fixed-bed Reactor.
International Journal of Chemical Reactor Engineering, 8(1).
Galadima, A., & Muraza, O. (2015). Recent Developments on Silicoaluminates
and Silicoaluminophosphates in the Methanol-to-Propylene Reaction: A
Mini Review. Industrial & Engineering Chemistry Research Ind. Eng.
Chem. Res., 54(18), 4891-4905.
Hadi, N., Niaei, A., Nabavi, R., Farzi, A., & Navaei Shirazi, M. (2014).
Development of a New Kinetic Model for Methanol to Propylene Process
on Mn/H-ZSM-5 Catalyst. 28(1), 53-63.
Hong, S. (2008). Retrofit Design of Methanol-to-Propylene Process for the
Changes in Feedstock and Catalyst. Korea Advanced Institute of
Science and Technology.
AKA 55
IHS, Chemical Economics Handbook, Propylene. (2015, February). Retrieved
from https://www.ihs.com/products/propylene-chemical-economics-
handbook.html
Jasper, S., & El-Halwagi, M. (2015). A Techno-Economic Comparison between
Two Methanol-to-Propylene Processes. Processes, 3(3), 684-698.
Moreno-Pirajan, J. C., & Giraldo, L. (2013). Catalytic Conversion Process of
Methanol-To-Propylene (MTP) With Zeolites. Rasayan J. Chem., 6(3),
172-174.
Wen, M., Ding, J., Wang, C., Li, Y., Zhao, G., Liu, Y., & Lu, Y. (2016). High-
performance SS-fiber@HZSM-5 core–shell catalyst for methanol-to-
propylene: A kinetic and modeling study. Microporous and Mesoporous
Materials, 221, 187-196.
Whitlow, Jonathan. (2016). Using Aspen Plus for Column Sizing.
Canvas.FIT.edu/Files
Turton, Baillie, Whiting, Shaeiwitz & Bhattacharyya. (2012). Analysis,
Synthesis and Design of Chemical Processes. Check formatting
Engineering Toolbox. Ethylene Glycol Heat-Transfer Fluid. (n.d.). from
http://www.engineeringtoolbox.com/ethylene-glycol-d_146.html
Mindat.org. Mordenite, from http://www.mindat.org/min-2779.html
Works Cited51-9011 Chemical Equipment Operators and Tenders. (2015, December 2). Retrieved from U.S. Bureau
of Labor Statistics: http://www.bls.gov/oes/current/oes519011.htm
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Aluminum Oxide price. (2016, 3 15). Retrieved from Alibab.com Global trade : www.alibaba.com/showroom/aluminium-oxide-price.html
Annual Energy Outlook 2015. (2015, April 14). Retrieved from U.S. Energy Information Administration: http://www.eia.gov/forecasts/aeo/section_prices.cfm#natgas
Argaam Petrochemical Index Loses 3.7 Pts as Polymers. (2015, December 2). Retrieved from ArgaamPlus.
Dukandar, K. N. (2016). Alternative On-purpose Production Methods for Propylene. CB&I.
Electric Power Monthly. (2015, Agust). Retrieved from U.S. Energy Information Administration: http://www.eia.gov/forecasts/aeo/section_prices.cfm#natgas
Petrol Prices Across the World. (2016, March 19). Retrieved from Kshitij Consultancy Services: http://www.kshitij.com/research/petrol.shtml
Saudi Arabia: Tax System. (2016, April). Retrieved from Santander TradePortal: https://en.santandertrade.com/establish-overseas/saudi-arabia/tax-system
Appendix A: Equipment Design Methods, Calculations and
Assumptions
The following appendix presents the detailed calculations, assumptions
and methods used in designing and simulating the process equipment.
The material of construction for ALL units was preliminarily assumed to
be carbon steel because of its low cost, mechanical and chemical properties.
Pumps (P-101, 102, 103, and 104)
Pumps were designed and simulated using Aspen Plus via inputting the
desired pressure discharge. The pressure discharge was specified based on
the desired pressure for a certain stream. Aspen Plus calculates the break
power and pump efficiency.
Pump (P-101)
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o Pump for flowing the feed methanol to the process
o Discharge pressure of 2.35 bar was chosen to accommodate for pressure
drop in the equipment and result in a pressure of 1.6 bar in stream 7
(Hong, 2008)
o The pump is to be a centrifugal pump with an electric drive; The reason
for this selection is because they are most common type of pumps used,
and they are the best choice for low viscosity and high flowrate (Turton,
2012).
o From Aspen Plus, break power = 36.4 kW, and the efficiency is 82%
Pump (P-102)
o Reflux pump for Distillation Column (T-101)
o Discharge pressure of 28 bar was chosen to accommodate for pressure
drop in the equipment
o The pump is to be a centrifugal pump with an electric drive; The reason
for this selection is because they are most common type of pumps used,
and they are the best choice for low viscosity and high flowrate (Turton,
2012).
o From Aspen Plus, break power = 37.6 kW, and the efficiency is 81%
Pump (P-103)
o Reflux pump for Distillation Column (T-102)
o Discharge pressure of 28 bar was chosen to accommodate for pressure
drop in the equipment
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o The pump is to be a centrifugal pump with an electric drive; The reason
for this selection is because they are most common type of pumps used,
and they are the best choice for low viscosity and high flowrate (Turton,
2012).
o From Aspen Plus, break power = 17.1 kW, and the efficiency is 74%
Pump (P-104)
o Reflux pump for Distillation Column (T-103)
o Discharge pressure of 28 bar was chosen to accommodate for pressure
drop in the equipment
o The pump is to be a centrifugal pump with an electric drive; The reason
for this selection is because they are most common type of pumps used,
and they are the best choice for low viscosity and high flowrate (Turton,
2012).
o From Aspen Plus, break power = 48.0 kW, and the efficiency is 82%
Heat Exchangers (E-101 to E-113)
The heat exchangers in the plant were all simulated using the “HeatX”
block in Aspen Plus. The Exchanger specifications, pressure drop and heat
transfer coefficient “U” were specified based on the application of the heat
exchanger. The pressure drop and the heat transfer coefficient “U” were
both determined based on the application of the heat exchanger and the
fluids passing through the shell and tube sides using the heuristics (Turton,
2012). From the inputted information, Aspen Plus calculates the area and
heat duty of the heat exchanger. In general, the amount of utility needed
AKA 59
was determined via the sensitivity analysis function in Aspen Plus, the
sensitivity conditions vary per unit and utility type.
A simplified version of the “HeatX” block is the “Heater” block. In some
cases, this block was used in the main body of the plant simulation for
simplification purposes, all of which were designed as “HeatX” blocks
separately to determine the amount of utility needed, area of heat
exchange, and heat duty.
Heat exchangers E-101 through E-113 (except for E-106) have been
designed with a floating head construction. The reasoning behind this
selection is that a floating head construction can handle thermal expansion
and allows easier access to the inner and outer tubes for cleaning purposes,
since the bundle can be removed (Turton,2012). Heat exchanger E-106 was
designed with a double pipe construction due to the exchange area being
relatively small (between 1 – 10 m2).
Heat Exchanger (E-101)
o Feed goes in tube side of the heat exchanger
o Low pressure steam (5 barg, 160 oC) in the shell side of the heat
exchanger (Turton,2012)
o It is desired to vaporize the feed in this heat exchanger (Hong, 2008); the
feed should come out at 97 oC
o Pressure drop of 0.1 bar in both shell and tube side was assumed
(Turton,2012)
o Heat transfer coefficient “U” was assumed 200 Btu/hr-ft2-oF (Turton,2012)
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o Low pressure steam flowrate was determined using sensitivity analysis by
varying the flowrate of low pressure steam (input) and monitoring the
temperature of the output stream from the shell side such that it comes
out as boiler feed water (115 oC) (Turton,2012). This boiler feed water
stream is to be sold or reused in the plant. The low pressure steam
flowrate = 118,721 kg/hr
o Aspen Plus calculates the area and heat duty for this heat exchanger:
Area = 1,650 m2 and Q = 447,992 MJ/hr
Heat Exchanger (E-102)
o Process stream goes in both shell and tube side of the heat exchanger
o Process stream #3 goes in tube side and #4 out of tube side, while
process stream #9 goes in shell side and #10 out of shell side
o The purpose of this heat exchanger is to superheat stream #3 to 266 oC
(Hong, 2008) and cooldown stream #9.
o Pressure drop of 0.2 bar in both shell and tube side was assumed
(Turton,2012)
o Heat transfer coefficient “U” was assumed 150 Btu/hr-ft2-oF (Turton,2012)
o Aspen Plus calculates the area and heat duty for this heat exchanger:
Area = 133 m2 and Q = 106,285 MJ/hr
Heat Exchanger (E-103)
o Process stream goes in both shell and tube side of the heat exchanger
o Process stream #5 goes in shell side and #6 out of shell side, while
process stream #8 goes in tube side and #9 out of tube side
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o The purpose of this heat exchanger is to heat stream #5 to 420 oC (Hong,
2008) and cooldown stream #8
o Pressure drop of 0.2 bar in both shell and tube side was assumed
(Turton,2012)
o Heat transfer coefficient “U” was assumed 60 Btu/hr-ft2-oF (Turton,2012)
o Aspen Plus calculates the area and heat duty for this heat exchanger:
Area = 394 m2 and Q = 95,553 MJ/hr
Heat Exchanger (E-104)
o Feed goes in tube side of the heat exchanger
o Cooling water (3 bar, 30 oC) in the shell side of the heat exchanger
(Turton,2012)
o It is desired to partially condense the feed in this heat exchanger to
knockout water in the flash separator; a sensitivity analysis was
conducted by varying the temperature output of this heat exchanger and
monitoring the water fraction in the liquid phase; based on sensitivity
analysis, the feed should come out at 38 oC
o Pressure drop of 0.2 bar in both shell and tube side was assumed
(Turton,2012)
o Heat transfer coefficient “U” was assumed 150 Btu/hr-ft2-oF (Turton,2012)
o Cooling water flowrate was determined using sensitivity analysis by
varying the flowrate of cooling water (input) and monitoring the
temperature of the output stream from the shell side such that it comes
out at 45 oC (Turton,2012). The cooling water flowrate = 1.1*107 kg/hr
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o Aspen Plus calculates the area and heat duty for this heat exchanger:
Area = 2,767 m2 and Q = 742,877 MJ/hr
Heat Exchanger (E-105)
o Due to Aspen Plus limitations, stream 12 was not sent directly to
compressor C-102; the stream had to be preheated prior to entering the
compressor C-102 using this heat exchanger
o Feed goes in tube side of the heat exchanger
o High pressure steam (41 barg, 254 oC) in the shell side of the heat
exchanger (Turton,2012) was used to minimize area of heat exchanger
and flow of steam.
o It is desired to heat up the feed in this heat exchanger; due to simulation
limitations, the feed should come out at 104 oC
o Pressure drop of 0.2 bar in both shell and tube side was assumed
(Turton,2012)
o Heat transfer coefficient “U” was assumed 150 Btu/hr-ft2-oF (Turton,2012)
o High pressure steam flowrate was determined using sensitivity analysis
by varying the flowrate of high pressure steam (input) and monitoring the
temperature of the output stream from the shell side such that it comes
out as boiler feed water (115 oC) (Turton,2012). This boiler feed water
stream is to be sold or reused in the plant. The high pressure steam
flowrate = 18,568 kg/hr
o Aspen Plus calculates the area and heat duty for this heat exchanger:
Area = 136 m2 and Q = 45,728 MJ/hr
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Heat Exchanger (E-106)
o Feed goes in tube side of the heat exchanger
o Cooling water (3 bar, 30 oC) in the shell side of the heat exchanger
(Turton,2012)
o It is desired to cooldown the feed in this heat exchanger but not condense
it; this is such that there is no need for liquid knockout prior to the second
stage of compression; the feed is to be cooled down to 132 oC, based on
sensitivity analysis of varying temperature of the feed output and
monitoring the vapor fraction.
o Pressure drop of 0.2 bar in both shell and tube side was assumed
(Turton,2012)
o Heat transfer coefficient “U” was assumed 150 Btu/hr-ft2-oF (Turton,2012)
o Cooling water flowrate was determined using sensitivity analysis by
varying the flowrate of cooling water (input) and monitoring the
temperature of the output stream from the shell side such that it comes
out at 45 oC (Turton,2012). The cooling water flowrate = 18,145 kg/hr
o Aspen Plus calculates the area and heat duty for this heat exchanger:
Area = 4.2 m2 and Q = 1,231 MJ/hr
Heat Exchanger (E-107)
o Feed goes in tube side of the heat exchanger
o Cooling water (3 bar, 30 oC) in the shell side of the heat exchanger
(Turton,2012)
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o It is desired to condense the feed in this heat exchanger to 75 oC (Lurgi,
2003)
o Pressure drop of 0.2 bar in both shell and tube side was assumed
(Turton,2012)
o Heat transfer coefficient “U” was assumed 150 Btu/hr-ft2-oF (Turton,2012)
o Cooling water flowrate was determined using sensitivity analysis by
varying the flowrate of cooling water (input) and monitoring the
temperature of the output stream from the shell side such that it comes
out at 45 oC (Turton,2012). The cooling water flowrate = 1.05*106 kg/hr
o Aspen Plus calculates the area and heat duty for this heat exchanger:
Area = 298 m2 and Q = 70,956 MJ/hr
Heat Exchanger (E-108)
o Condenser for distillation column (T-101)
o Feed goes in tube side of the heat exchanger
o Cooling water (3 bar, 30 oC) in the shell side of the heat exchanger
(Turton,2012)
o It is desired to condense the vapor rising from the top tray in this heat
exchanger; the desired temperature was obtained from the profile of the
distillation column (T-101), and the temperature was 58.3 oC.
o Pressure drop of 0.2 bar in shell and 0.007 bar in tube side was assumed
(Turton,2012); the tube side pressure drop is equal to the pressure drop
between the trays of the distillation column, since tray 1 in aspen
represents the condenser and tray 2 is the top try of the column.
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o Heat transfer coefficient “U” was assumed 150 Btu/hr-ft2-oF (Turton,2012)
o Cooling water flowrate was determined using sensitivity analysis by
varying the flowrate of cooling water (input) and monitoring the
temperature of the output stream from the shell side such that it comes
out at 45 oC (Turton,2012). The cooling water flowrate = 792,672 kg/hr
o Aspen Plus calculates the area and heat duty for this heat exchanger:
Area = 572 m2 and Q = 52,871 MJ/hr
Heat Exchanger (E-109)
o Reboiler for distillation column (T-101)
o Feed goes in tube side of the heat exchanger
o High pressure steam (41 barg, 254 oC) in the shell side of the heat
exchanger (Turton,2012)
o It is desired to re-boil the liquid dropping from the bottom tray in this heat
exchanger; the desired temperature was obtained from the profile of the
distillation column (T-101), and the temperature was 236.4 oC.
o Pressure drop of 0.1 bar in shell side was assumed (Turton,2012); and a
pressure buildup 0.007 bar was assumed in the tube side, since the
pressure drops from the reboiler pressure to the condenser pressure by
0.007 bar per tray (Turton,2012)
o Heat transfer coefficient “U” was assumed 150 Btu/hr-ft2-oF (Turton,2012)
o High pressure steam flowrate was determined using sensitivity analysis
by varying the flowrate of high pressure steam (input) and monitoring the
temperature of the output stream from the tube side such that the
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desired temperature is achieved with the minimum amount of steam. The
high pressure steam flowrate = 13,133 kg/hr
o Aspen Plus calculates the area and heat duty for this heat exchanger:
Area = 1,329 m2 and Q = 25,176 MJ/hr
Heat Exchanger (E-110)
o Condenser for distillation column (T-102)
o Feed goes in tube side of the heat exchanger
o 50/50 Water-Ethylene glycol refrigerant (2 bar, -30 oC) in the shell side of
the heat exchanger (Engineering Toolbox)
o It is desired to condense the vapor rising from the top tray in this heat
exchanger; the desired temperature was obtained from the profile of the
distillation column (T-102), and the temperature was -20.5 oC.
o Pressure drop of 0.2 bar in shell and 0.007 bar in tube side was assumed
(Turton,2012); the tube side pressure drop is equal to the pressure drop
between the trays of the distillation column, since tray 1 in aspen
represents the condenser and tray 2 is the top try of the column.
o Heat transfer coefficient “U” was assumed 150 Btu/hr-ft2-oF (Turton,2012)
o Refrigerant flowrate was determined using sensitivity analysis by varying
the flowrate of cooling water (input) and monitoring the temperature of
the output stream from the tube side to find the minimum amount of
refrigerant. The refrigerant flowrate = 684,649 kg/hr
o Aspen Plus calculates the area and heat duty for this heat exchanger:
Area = 1,635 m2 and Q = 19,238 MJ/hr
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Heat Exchanger (E-111)
o Reboiler for distillation column (T-102)
o Feed goes in tube side of the heat exchanger
o Low pressure steam (5 barg, 160 oC) in the shell side of the heat
exchanger (Turton,2012)
o It is desired to re-boil the liquid dropping from the bottom tray in this heat
exchanger; the desired temperature was obtained from the profile of the
distillation column (T-102), and the temperature was 74.9 oC.
o Pressure drop of 0.1 bar in shell side was assumed (Turton,2012); and a
pressure buildup 0.007 bar was assumed in the tube side, since the
pressure drops from the reboiler pressure to the condenser pressure by
0.007 bar per tray (Turton,2012)
o Heat transfer coefficient “U” was assumed 150 Btu/hr-ft2-oF (Turton,2012)
o Low pressure steam flowrate was determined using sensitivity analysis by
varying the flowrate of low pressure steam (input) and monitoring the
temperature of the output stream from the tube side such that the
desired temperature is achieved with the minimum amount of steam. The
low pressure steam flowrate = 793 kg/hr
o Aspen Plus calculates the area and heat duty for this heat exchanger:
Area = 25 m2 and Q = 2,024 MJ/hr
Heat Exchanger (E-112)
o Condenser for distillation column (T-103)
o Feed goes in tube side of the heat exchanger
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o Cooling water (3 bar, 30 oC) in the shell side of the heat exchanger
(Turton,2012)
o It is desired to condense the vapor rising from the top tray in this heat
exchanger; the desired temperature was obtained from the profile of the
distillation column (T-101), and the temperature was 59.4 oC.
o Pressure drop of 0.2 bar in shell and 0.007 bar in tube side was assumed
(Turton,2012)
o Heat transfer coefficient “U” was assumed 200 Btu/hr-ft2-oF (Turton,2012)
o Cooling water flowrate was determined using sensitivity analysis by
varying the flowrate of cooling water (input) and monitoring the
temperature of the output stream from the shell side such that it comes
out at 45 oC (Turton,2012). The cooling water flowrate = 761,092 kg/hr
o Aspen Plus calculates the area and heat duty for this heat exchanger:
Area = 600 m2 and Q = 51,621 MJ/hr
Heat Exchanger (E-113)
o Reboiler for distillation column (T-103)
o Feed goes in tube side of the heat exchanger
o Low pressure steam (5 barg, 160 oC) in the shell side of the heat
exchanger (Turton,2012)
o It is desired to re-boil the liquid dropping from the bottom tray in this heat
exchanger; the desired temperature was obtained from the profile of the
distillation column (T-103), and the temperature was 117.7 oC.
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o Pressure drop of 0.1 bar in shell side was assumed (Turton,2012); and a
pressure buildup 0.007 bar was assumed in the tube side, since the
pressure drops from the reboiler pressure to the condenser pressure by
0.007 bar per tray (Turton,2012)
o Heat transfer coefficient “U” was assumed 150 Btu/hr-ft2-oF (Turton, 2012)
o Low pressure steam flowrate was determined using sensitivity analysis by
varying the flowrate of low pressure steam (input) and monitoring the
temperature of the output stream from the tube side such that the
desired temperature is achieved with the minimum amount of steam. The
low pressure steam flowrate = 450 kg/hr
o Aspen Plus calculates the area and heat duty for this heat exchanger:
Area = 21 m2 and Q = 1,056 MJ/hr
Reactor
DME Reactor (R-101)
The reactor was simulated in Aspen Plus using an “REquil” block. The
reaction inputted was as follow (Farsi, 2010):
2CH3 OH⟺CH 3O CH3+H 2 O
The reactor operates isothermally at 300 oC (Hong, 2008), and is modeled as
a heat exchanger with the feed going into the tube side, where the
aluminum oxide catalyst is packed (Lurgi, 2003), and cooling water in the
shell side to maintain the reactor temperature (Farsi, 2010). A pressure drop
of 0.35 bar was assumed to reach to the desired pressure in stream 7.
Furthermore, the number of tubes, diameter of tube, and reactor length were
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all obtained from literature (Farsi, 2010); they were used to find the volume
of the reactor for designing and costing purposes.
o Number of tubes = 2000
o Tube diameter = 0.09 m
o Length of reactor = 8 m
o Volume of reactor = 2000 ×8× π (0.09)2
4=102m3
o Form Aspen Plus, the estimated amount of cooling water needed in the
shell side of this reactor is 3.65*106 kg/hr
MTP Reactor (R-102)
The reactor was simulated in Aspen Plus using “RStoic” block since the
reaction kinetics were unavailable. This reactor was a challenge to simulate
due to the unavailability of reaction kinetics, yet several attempts to
accurately simulate it were attempted (refer to appendix D for further
information about the different attempts tackled in designing this reactor).
After several attempts, an assumption had to be made to simplify the
simulation. This assumption was that only the major reactions are happening
in this reactor and those reactions are the ones producing the major product.
The products are Ethylene, Propylene, Butene, Pentene, Hexene, Heptene,
Octene, and Water. Due to the limitations of Aspen Plus, two “RStoic” blocks
in series (R-102A and R-102B) were used to model the single MTP reactor.
The reactions inputted into the first reactor (R-102A) are as follow:
General Form: nCH 3O CH3 →2Cn H2n+n H2O for n=2,…,8 (Meyers, 2005)
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Table #: List of Reactions inputted in MTP Reactor (R-102A)
n Reaction2 2CH3 OCH 3 →2C2 H 4+2 H 2O3 3CH 3O CH3 →2 C3 H 6+3 H 2O4 4 CH3 OCH 3 →2C4 H 8+4 H 2 O5 5CH3 O CH3 →2 C5 H 10+5 H 2O6 6CH 3O CH3 →2C6 H12+6 H 2O7 7CH 3O CH3 →2C7 H14+7 H2 O8 8CH 3O CH3 →2C8 H 16+8 H 2 O
The reactions inputted into the second reactor (R-102B) are as follow:
General Form: nCH 3OH →Cn H 2n+n H 2O for n=2 ,…,8 (Hadi, 2014)
Table #: List of Reactions inputted in MTP Reactor (R-102B)
n Reaction2 2CH3 OH →C2 H4+2 H2O3 3CH 3OH →C3 H 6+3 H2O4 4 CH3 OH →C4 H8+4 H 2O5 5CH3 OH →C5 H 10+5H 2 O6 6CH 3OH →C6 H 12+6 H2O7 7CH 3OH →C7 H 14+7 H 2O8 8CH 3OH →C8 H 16+8 H 2O
The reactor is designed as a fixed bed process vessel with mordenite zeolite,
HMOR, as the catalyst. The reactor operates isothermally at 452 oC (Hong,
2008). A cooling jacket, with cooling water flowing in it, was planned to
maintain the temperature of the reactor. A pressure drop of 0.9 bar was
assumed across the MTP reactor, 0.45 bar in both reactors R-102A & R-102B,
to reach the desired output pressure of 1.6 bar in the exiting stream, stream
7. The volume of the reactor was determined using the weighted hourly
space velocity “WHSV” (Moreno-Pirajan, 2013); then using the heuristics
from Turton, the length to diameter ratio was chosen, and both values were
calculated.
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o WHSV = 1 hr-1 = Mass flowrateof feedWeight of catalyst
=350,000 kg
hrWeight of catalyst
→Weight of catalyst=350,000 kg
o Mordenite zeolite density = 2135 kg/m3 (Mindat.org)
o Volume of reactor = Weight of catalystDensity of catalyst
= 350,000 kg2135 kg /m3 =164 m3
o L/d ratio = 3, in other words L = 3 d (Turton, 2012)
o Diameter of reactor: 164 m3=(3d ) × π ( d )2
4→d=4.1m
o Length of reactor: L = 3 d = 12.3 m
o Form Aspen Plus, the estimated amount of cooling water needed in the
cooling jacket is 13.5*106 kg/hr
Compressors (C-101, 102, and 103)
The compressors in the plant were simulated using the “Comp” block in
Aspen Plus. Based on Turton’s heuristics, the chosen compressor type for all
compressors is isentropic. All compressors are reciprocating compressors
simply because the required head is so high than an undesirable large
number of stages needed (Heuristics). Isentropic type of compressor was selected
because the compression is taking place with no flow of heat energy either
into or out of the gas (Heuristics). The discharge pressure and the efficiency for
the compressors were determined based on the process and heuristics from
Turton, respectively. The efficiency in C-101 is 85% because the compression
ratio is roughly 3.8. The efficiency in C-102 and C-103 is 75 % because the
compression ratio is roughly 2.2(Heuristics) Aspen Plus is then able to calculate
AKA 73
the break horsepower that can be then used in costing the compressors. The
table below shows all the compressors with their corresponding parameters.
Table (!): design compressors and parameters
Compressor
Inlet Pressure
(bar)
Discharge Pressure
(bar)Pressure
RatioBreak
horsepower(kW)
Efficiency
C-101 1.6 6.1 3.8 39,299 85 %C-102 5.3 11.6 2.2 2,425 75 %C-103 11.5 25.2 2.2 2,400 75 %
Flash Separator Design (V-101)
The flash separator in the plant was designed and simulated in Aspen
Plus. The input of the flash separator V-101, stream (11) was cooled down
prior to enter the flash separator at 38 oC (100 oF) and 5.5 bar. It was
assumed that the flash duty is zero. In addition, it was assumed that the
flash operates at 5.5 bar similar the feed pressure to achieve the desired
purities. Water was knocked out with purity of (99.97 mole faction). Waste
water goes to nearby treatment facility for further purification due to the
methanol contamination. All hydrocarbons are leaving the flash separator
from the top. The flash separator was designed and simulated as vertical
based on heuristics in Turton.
o Assuming holdup time for half full = 5 min
o Flow rate in = 195565 Lmin
o Assuming Ld=3
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195565 Lmin × 1m3
1000 L = 195.567 m3
min
Volume of the vessel = 195.567 m3
min × 5 min × 2 = 1955.65 m3
Volume = π d2
4× L = π d2
4× 3d = 1955.65 m3
From the volume of the flash: diameter = 9.39784 m and height = 28.1935
m
Distillation Columns (T-101, 102, and 103)
The distillation columns in the plant were simulated using the
“RadFrac” block in Aspen Plus. The amount of distillate or bottom product
was determined based on the amount of product in the feed going into the
distillation column. The reflux ratio was varied and determined using Aspen
to obtain the desired purity. The optimum number of stages, feed stage, and
reflux ratio were then determined using the optimization method from
(Whitlow, 2016). Furthermore, the condenser pressure was determined from
the process; however, the pressure drop was determined from Turton’s
heuristics. The type of trays used in all distillation columns are sieve trays,
mainly because they have higher entrainment than other types of trays (2N).
From inputting the type of tray in Aspen Plus and estimating a number of
passes, an estimated dimeter for the column can be obtained. Using the
maximum liquid flowrate and the estimated diameter from Aspen Plus in
Figure #13.7 from the Koch Flexitray Design Manual, the number of passes
can be confirmed, thus the exact diameter of the column can be obtained.
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The tray spacing, tray efficiency, and height of the distillation columns were
determined using Turton’s heuristics as well. The following is the sample
calculation of determining the number of passes in the first distillation
column (T101).
o Maximum liquid flow rate found to be 11574.9 gal/min on stage
32
o Figure 13.7 was used to determine the number of passes.
In the sizing and rating option, the number of passes and type of trays
were the inputs. The column diameter found to be 4.8m using Aspen Plus.
After that, it was assumed that 2 foot tray spacing in distillation columns.
Additional 20 % of the total height was added to the distillation column. The
height of the column was estimated by L = 1.2 (NT – 2) × 2 where NT is the
number of trays. Below is a sample calculation of T-101 height.
L = 1.2 (NT – 2) × 2
L = 1.2 (46 – 2) × 2
L = 1.5.6 ft = 32.2 m
The volume of the distillation column was calculated using the
following formula: Volume = π d2
4× L
The following is sample calculation of the volume for the first
distillation column T-101:
Volume = π (4.81m)2
4× 32.2m = 585 m3
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There are some specific procedures to finalize the column design such
as minimizing the capital cost by reducing the theoretical number of stages.
In addition, the reflux ratio and reboiler duty minimize the operating cost.
The following is a detailed explanation of distillation columns optimization
using T-102 as example. The optimization study was similar for the rest of
the columns.
1. Varying the number of stages and monitoring the reflux ratio
The following is example of T-102
Number
of Stages
Feed
Stage
Reflux
Ratio
20 10 21.60
6
30 15 11.90
2
50 25 8.600
60 30 8.023
70 35 7.690
75 36 7.531
85 38 7.367
95 41 7.319
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It could be noticed that the reflux ratio is almost stable at 7.319. Based
on the heuristics in table 13 the economical optimal reflux ratio is 1.2 higher
than the found value. The minimum reflux ration is found to be 8.782
2. Varying the number of stages to minimum
This step basically was done by reducing the number of stages until
aspen crashes and then calculate the economic optimum number of stages
which is nearly twice the minimum value. The flowing is an example of the
case study on T-102.
Number
of Stages
Feed
Stages
Reflux
Ratio
17 8
51.08
3
18 9
33.11
9
25 12
13.83
8
35 11 8.970
The minimum number of stages found to be 17. The theoretical
number of stages is roughly 35 stage.
3. Varying the feed stage and monitoring the heat of reboiler and
condenser
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The feed stage was varied to find the minimum reboiler and condenser
heat duty. The following table shows the study for T-102.
Feed
Stage
Reboiler
Heat (MW)
Condenser
Heat (MW)
Reflu
x Ratio
10 6.2235 -5.38955
9.05
4
11* 6.17844 -5.3449
8.97
0
12 6.21465 -5.38067
9.03
8
13 6.29864 -5.46319
9.19
0
*Optimum
The optimum feed tray found to be on stage 11 because it typically
minimize the reboiler and conducer duty required
Reflux Drums (V-102, 103, and 104)
Reflux drums were designed and simulated in Aspen Plus as “Flash2”.
It was assumed that no duty is taking place in the flash and the pressure in
the flash is nearly close to the stream pressure. In the main simulation part,
the reflux drum is not shown. Reflux drums are designed and simulated in
the condensers modeling part for all the distillation columns. The following
assumptions were addressed when designing the reflux drums.
o Horizontal vessels
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o Half full holdup time = 5 min
o Assuming Ld=3
The volumes of the reflux drums was calculated as follow:
o 6270.1 Lmin × 1m3
1000 L × 5 min × 2 = 72.7 m3
o Volume of reflux drums = π d2
4× L = π d2
4× 3d = 72.7 m3
from the volume of the drum: diameter = 2.97 m; height = 8.93 m
The assumptions and calculations that were addressed above are also
followed to design and simulate all the reflux drums in the process.
Storage Tanks (V-105 to V-109)
Storage tanks were not simulated on Aspen Plus, yet they were designed
based on the product flowrate, and heuristics. Heuristics were used to
determine the capacity and orientation of the tanks. Using the capacity and
the flow rate, the volume of the tank can be determined, which was then
used for designing and costing purposes.
o Capacity = 3 days
o Storage tanks are operating on 3 bar
o Assuming Ld=3
Volume, diameter, and height were calculated as follow:
Flow rate of propylene = 2159.856 Lmin
2159.856 Lmin × 1m3
1000 L 60min
1hr × 24hr1day × 3 days = 9330.6 m3
AKA 80
Volume of storage tank = π d2
4× L = π d2
4× 3d = 9330.6 m3
From the volume of the tank: diameter = 18.1m and height = 36.2 m
The same calculations are applied for all the storage tanks. The table below
shows all the parameters for each storage tank.
Table (1): Storage Tanks Parameters
Equipment Volume(m3) Diameter(m) Height (m)Methanol Storage Tank 32784 27.53 55
Propylene Storage Tank
9331 18.1 36.2
LPG Storage Tank 5555 13.3 39.9Fuel Gas Storage Tank 1374 8.98 17.9Gasoline Storage Tank 10074 18.5 37.15
Appendix B: Capital Cost Sample Calculations
1B) Calculation for Pump P-101 A/B Bare Module Cost:
Table (): Bare Module Pump Costing Coefficients
Centrifugal
Capacity (kw)
Discharge
pressure(bar)
K1 K2 K3 B1 B2 C1 C2 C3FM
(Carbon Steel)
36.4 3.685 3.3892
0.0536
0.1538 1.89 1.3
5 0 0 0 1.6
From table 1, Log (Cpo) and Log (Fp) can be calculated using the following equations:
log10 C po=K1+ K2 log10 ( A )+K 3 [ log10 ( A ) ]2=3.3892+0.0536 × log10 (36.4 )+0.1538 ׿¿
C po=7041.95
For the P<10, C1, C2, and C3 will be zero
log10 Fp=C1+C2 log10 ( P )+C3 [ log10 ( P ) ]2=0
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F p=1
CBM=C po ( B1+B2 F M F p )=7041.95 × (1.89+ (1.35 × 1.6× 1 ) )=$28,520
2B) Calculation for Vessel V-101:
Table (): Bare Module Process Vessel Costing Coefficients
Process vessel Vertical
Diameter (M)
Capacity (m3) K1 K2 K3 B1 B2
FM(Carbon Steel)
Pressure(barg)
9.398 488.92 3.4974
0.4485
0.1074 2.25 1.8
2 1.6 4.944
From table 2, Log (Cpo) and Fp can be calculated using the following equations:
log10 C po=K1+ K2 log10 ( A )+K 3 [ log10 ( A ) ]2=3.4974+0.4485× log10 (488.92 )+0.1074 × ¿¿
C po=302160.1
FP, Vessel
( P+1 )∗D2[850−0.6 (P+1 )]
+0.00315
0.0063=
(4.944+1 ) × 9.3982[850−0.6 ( 4.944+1 )]
+0.00315
0.0063=5.7
CBM=C po (B1+B2 F M F p )=302160.1 × (2.25+(1.82 ×1×1 ) )=$3,835,378
3B) Calculation for Heat Exchanger H-103:
Table (): Bare Module Heat Exchanger Costing Coefficients
Floating Head
Capacity (m3)
Q ( MJh
)K1 K2 K3 B1 B2
FM(Carbon Steel)
Pressure(barg)
394.19 106285
4.8306
-0.85
10.318
7 1.63 1.66 1
5.61
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From table 3, Log (Cpo) and Fp can be calculated using the following equations:
log10 Cpo=K1+ K2 log10 ( A )+K3 [ log10 ( A ) ]2=4.8306+(−0.851)× log10 (394.19 )+0.3187 ׿¿
C po=58777
For the P<10, C1, C2, and C3 will be zero (Turton,2012)
log10 Fp=C1+C2 log10 ( P )+C3 [ log10 ( P ) ]2=0
F p=1
CBM=C po (B1+B2 F M F p )=58777 × ( 1.63+ (1.66 ×1× 1 ) )=$ 193,378
4B) Calculation for Compressors C-102:Table (): Bare Module Compressor Costing Coefficients
Reciprocating
Power (KW )
Pressure (barg) K1 K2 K3
FBM(Carbon Steel)
2425 11.7 2.2897
1.3604 -0.103 3.4
From table 3, Log (Cpo) and Fp can be calculated using the following equations:
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log10 C po=K1+ K2 log10 ( A )+K 3 [ log10 ( A ) ]2=2.2897+1.3604 ×log10 (2425 )+(−0.103)׿¿
C po=$522008.6
For the P<10, C1, C2, and C3 will be zero
log10 Fp=C1+C2 log10 ( P )+C3 [ log10 ( P ) ]2=0
F p=1
CBM=C po ( FBM )=522008.6× 3.4=$ 1,774,829
5B) Calculation for Column T-103:Table (): Bare Module Column Costing Coefficients
Tray Vertical Towers
Diameter (M)
Capacity (m3) K1 K2 K3 B1 B2
FM(Carbon Steel)
Pressure(barg)
3.30 300 3.4974
0.4485
0.1074
2.25
1.82 1 26.4
From table 2, Log (Cpo) and Fp can be calculated using the following equations:
log10 C po=K1+ K2 log10 ( A )+K 3 [ log10 ( A ) ]2=3.4974+0.4485× log10 (300 )+0.1074 ׿¿
C po=$184885.871
FP, Vessel
( P+1 )∗D2[850−0.6 (P+1 ) ]
+0.00315
0.0063=
(26.4+1 ) ×3.302[850−0.6 (26.4+1 )]
+0.00315
0.0063=9.1
CBM=C po ( B1+B2 F M F p )=184885.871 × (2.25+(1.82 ×1×13.1 ) )=$3,477,566
6B) Calculation for Sieve Trays T-103:Table (): Bare Module Sieve Trays Costing Coefficients
Sieve Trays
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Diameter (M)
Capacity (m2) K1 K2 K3 N( #
Trays)FBM
(Carbon Steel)Fq
3.30 8.53 2.9949
0.4465
0.3961 48 1 1
Where is: N: Number of traysThe quantity factor for trays, Fq, for N ≥ 20: Fq = 1
From table 2, Log (Cpo) and Fp can be calculated using the following equations:
log10 C po=K1+ K2 log10 ( A )+K 3 [ log10 ( A ) ]2=2.9949+0.4465 × log10 (8.53 )+0.3961× ¿¿
C po=$5676.5
CBM=C po N FBM Fq=5676.5 × 48×1 ×1=$ 272,471
7B) Calculation for Reactor R-101:Table (): Bare Module Reactor Costing Coefficients
Floating HeadTube
Diameter(M)
N (# of Tube )
Capacity (m2) K1 K2 K3 B1 B2 FM
Pressure
(Barg)0.09 2000 12.72 4.830
6-
0.85090.318
7 1.63 1.66 1 1.87
Note: This reactor was design as heat exchanger.
From table 2, Log (Cpo) and Fp can be calculated using the following equations:
log10 Cpo=K1+ K2 log10 ( A )+K3 [ log10 ( A ) ]2=4.8306+(−0.8509)× log10 (12.72 )+0.3187 ׿¿
C po=$19035.1
For the P<10, C1, C2, and C3 will be zero
log10 Fp=C1+C2 log10 ( P )+C3 [ log10 ( P ) ]2=0
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F p=1
CBM=C po (B1+B2 F M F p )=19035.1 × (1.63+(1.66 ×1×1 ) )=$ 62,625
8B) Calculation for Reactor R-102:Table (): Bare Module Reactor Costing Coefficients
Process Vessel Vertical
Diameter (M)
Capacity (m3) K1 K2 K3 B1 B2
FM(Carbon Steel)
Pressure(barg)
4.1 164 3.4974
0.4485
0.1074
2.25
1.82 1 0.66
Note: This reactor was design as Process Vessel.
From table 2, Log (Cpo) and Fp can be calculated using the following equations:
log10 C po=K1+ K2 log10 ( A )+K 3 [ log10 ( A ) ]2=3.4974+0.4485× log10 (164 )+0.1074 × ¿¿
C po=$104138.9
FP, Vessel
( P+1 )∗D2[850−0.6 (P+1 )]
+0.00315
0.0063=
(0.66+1 )× 4.12[850−0.6 ( 0.66+1 )]
+0.00315
0.0063=1.138
CBM=C po ( B1+B2 F M F p )=184885.871 × (2.25+(1.82 ×1×1.38 ) )=$562,578
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Appendix C: Manufacturing Cost Sample Calculations
Operating labor Cost Calculation:
NOL=√6.29+31.7P2+0.23 N np
P= 0
Nnp= 22
NOL=√6.29+31.7 02+0.23 ×22=3.369≈ 4
NO=4.5×NOL
¿4.5× 4=18
COL=NO × AW
AW= 53,500COL=18× $53,500=$ 963,900
As shown in Table (), there are 52 weeks in one year, 3 weeks for
vacation, 8 hours in each shift, and 5 shift per week. To calculate the total
hours per year, the number of week should be 49 by subtracting 52 from 3.
Calculating Total hour is by Multiplying8×5× 49=1960 and total hour/year is
24× 350=8400. The number of operator hired for each operators is 84001960= 4.3
and this number should be rounded to 4.5.
Table (): Operating labor cost variable
Number of week in year 52Number of weeks for vacation 3
Number of shift per week 5Hours each shift 8Total hours /year 1960
Total hours of operation 8400Number of operator hired for each
operator 4.5
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NOL 4Annual mean Wages in 2016 53,550Total number of operators 20
COL $1,071,000
Calculation For Waste Water Cost:
CWT=Flow rate (MTYR )×Price( $
MT)
Flowrate = 1645837.2 MTYR
Price = 0.0625 $MT
CWT=1645837.2 ×0.0625
Calculation for utility Cost
Calculation for Electricity Cost
The price of Electricity is 0.0718 $KW−hr
The total amount of electricity needed is 367,045,401 KW−hryr
CElectricity=amount of eletricity needed × priceof eletricity
CElectricity=367,045,401× 0.0718=26,535,860 $yr
Calculation for Cooling water cost
The price of cooling water is 0.0000175 $kg
The total amount of Cooling Water needed is 258,002,773,140 kgyr
CCW=amount of CW needed × price of CW
CCW=258,002,773,140× 0.0000175=4,502,697 $yr
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Calculation for High Pressure Steam cost:
The price of HPS is 0.01459 $kg
The total amount of HPS is 266,292,516 kgyr
CHPS=amount of HPS needed × priceof HPS
CHPS=266,292,516× 0.01459=3,885,247 $yr
Calculation for Low Pressure Steam
The price of LPS is 0.01348 $kg
The total amount of LPS is 1,595,689,056 kgyr
CLPS=amount of LPS needed× price of LPS
CLPS=1,595,689,056 ×0.01348=21,516,967 $yr
Calculation for Refrigerant Cost:
The price of Refrigerant Duty is 11.2671 $GJ
The total amount of Refrigerant Duty is 161,597 GJyr
CRefrigerant=amount of Refrigerant duty needed× priceof Refrigerant Duty
CRefrigerant=161,597 ×11.2671=1,820,726 $yr
Total Utility cost calculation: CUT= C Electricity + CCW + CHPS + CLPS + C Refrigerant
CUT= 26,535,860 + 4,502,697 + 3,885,247 + 21,516,967 + 1,820,726
CUT= $ 58,079,297
Calculation For Raw Material Cost:
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Feed of the process:
The Amount of Methanol needed is 2640000 MTyr
The price of Methanol is 235 $kg
CMethanol=amount of Methanol needed× priceof Methanol
CMethanol=2640000× 23=$690,900,000
R-101 ( Aluminum Oxide Catalyst)
The Mass of Aluminum Oxide Catalyst needed for the R-101 is 402.9 MT
The price of Aluminum Oxide catalyst is 1000 $MT
C Al2O3Catalyst=Mass of Al 2O 3catalyst needed × price of Al2O3Catalyst
C Al2O3Catalyst=402.9× 1000=$402,900
R-102 ( Mordenite Zeolite Catalyst)
The Mass of Mordenite Zeolite catalyst (HMOR) needed for the R-102 is 344.4
MT
The price of Mordenite Zeolite catalyst (HMOR) is 120 $MT
CHMOR=Massof HMOR catalyst needed × price of HMORCatalyst
CHMOR Catalyst=344.4×120=$41.328
Total Row Material Cost CRM=CMethanol+C Al 2O 3Catalyst +CHMOR=$691,344,228
Calculation for Cost of Manufacturing (COM):COM=0.180× FCI+2.73× COL+1.23(CUT +CWT+CRM)
COM=0.180×$ 175,416,007+2.73×$ 963,900+1.23($58,079,897+$ 102,834+$691,344,228)
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COM=$ 965,123,749
Where FCI is the fixed capital cost, it was discussed in previous section (Appendix B)
Direct Manufacturing Costs (DMC):DMC=CRM+CWT+CUT+1.33×COL+0.03×COM+0.069× FCI
DMC=$ 791,595,762
Direct Supervisory and Clerical Labor:
Direct Supervisory∧Clerical Labor=0.18× COL
Direct Supervisory∧Clerical Labor=$173,502
Maintenance and Repairs:
Maintenance and Repairs was calculated using the formula below.
Maintenance∧Repairs=0.06× FCI
Maintenance∧Repairs=$10,524,960
Fixed Manufacturing Cost (FMC):
¿ Manufacturing Cost=0.708×COL+0.068× FCI
FMC=$12,610,729
Local taxes and Insurance:
Local taxes∧Insurance=0.032× FCI
Local taxes∧Insurance=$5,613,312
Plant Overhead costs:
Plant Overhead costs=0.708 ×COL+0.036 × FCI
Plant Overhead costs=$6,997,417
Lab Charges:
Lab Charges=0.15×COL
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Lab Charges=$144,585
Patents and Royalties:
Patents∧Royalties=0.03×COM
Patents∧Royalties=$28,683,712
General Expenses:
General Expenses=0.177×COL+0.009× FCI+0.16 ×(COM)
General Expenses=$ 154,729,154
Administration Costs:
AdministrationCosts=0.177 ×COL+0.009×(FCI )
AdministrationCosts=$ 1,749,354
Distribution and Selling Costs:
Distribution∧SellingCosts=0.11×COM
Distribution∧SellingCosts=$105,173,612
Research and Development:
Research∧Development=0.05×(COM )
Research∧Development=$ 47,806,187
Table (): Electricity Price Extrapolation (3)
year cent/kW-h
2005 5.732006 6.162007 6.392008 6.962009 6.832010 6.772011 6.82
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2012 6.672013 6.892014 7.012015 6.892016 7.18
The data in the table
was used to plot the
correlation in the
figure above and
extrapolate linearly to
find the cost of electricity in 2016.
Natural Price data (12)
Natural Gasyear Price ($/MBtu)2005 10.082006 7.582007 7.642008 9.532009 4.212010 4.612011 4.132012 2.792013 3.732014 4.372015 369.00%
Total Annual Change -51.32%Annual Change -5.70%
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2004 2006 2008 2010 2012 2014 20165.0
5.5
6.0
6.5
7.0
7.5
f(x) = 0.0919090909090909 x − 178.09R² = 0.591464134435103
Price of Electricity
Year
Price
in C
ents
/kW
-hr
Appendix D: Profitability Analysis Sample Calculations
Appendix E: Literature Review
Figure #: Propylene Downstream Uses??
AKA 94
Figure #: Global Propylene Consumption (IHS, 2015)
Figure #: Propylene and Ethylene Price Trends in the Middle East??
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Figure #: Process Routes to Producing Propylene (Jasper, 2015)
Discuss the stages we went through to designing the MTP reactor
Relief system
There are several safety Precautions that need to be considered in any
chemical plant. Equipment failure or operation error can cause increase in
the process pressure beyond the safe level. In the case that pressure
increases beyond the safe level in a distillation column, tank, reactors and
pipelines, it could result in rupture in the units which lead to the release of
toxic or flammable chemicals. Designing a relief system is a significant
procedure to insure plant safety. There are several steps to install a relief
system around the plant.
1- Install safety valves in the relieving locations
2- Choosing the relief type
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3- Developing a relief scenarios
4- Determining the wort case scenario and sizing the valves
5- Design the relief system
Fire and explosion
Fires and explosions occur when the triangle of fire is completed as shown
in figure (1). Both fire and explosion can be prevented by removing any leg
from the fire triangle. In the design, the fuel is mainly Propylene, methanol
and gasoline, the oxidizer is oxygen and the ignition sources could be sparks,
flames, static electricity and heat from hot surface. The ignition sources of
major fires are shown in table (1). It can be observed that the major sources
of ignitions are electrical, smoking
and others. These sources of
ignition can easily be controlled by adopting stringent safety rules
and following training guideline.
Source Present of Accident
Electrical 23Smoking 18Friction 10
Overheated Materials 8Hot Surfaces 7
Burner Flames 7Others 27
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Figure (1): Fire triangle
Table (1): Ignition Sources of Major Fires [1]
Plant Environment
The geographical location of the final plant can have a strong influence on
the success of an industrial venture because it is located in aljubail industrial
area in Saudi Arabia. An ideal location is where the cost of the product is
kept to minimum, with a large market share, the least risk and the maximum
social gain. There is only one waste in the process which is waste water. The
waste is literally pure(99.97% mole fraction) but it contains methanol which
is flammable and toxic. It was assumed that the waste water will be send to
a neighbor treatment facility for further processes due to the methanol
contamination. The high pressure steam and the low pressure steam outlet
temperatures are kept to 115 oC. Economical wise, the product of the heating
units are manipulated to be boiler feed water to reduce the cost.
Identification of Hazards
Physical Hazards
Vibration and noise are examples of physical hazards. As a factor within
the environment that can harm the body even without necessarily physical
touching. A physical hazard arises when use of a chemical is potentially
dangerous. For example, to the possibility of explosion, fire or violent
reaction.
Health Hazards
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In today‘s environment there are a number of potential health hazards
that you need to be aware of, and control properly, to help reduce the risk to
your health and the health of people around you. For example, the air we
breathe can contain emissions from motor vehicles, industry, heating and
commercial sources, as well as household fuels. Air pollution can be harmful
to human health, particularly in those people who are already vulnerable
because of their age or existing health problems.
Permissible Exposure Limits
We are exposed to all kinds of goods and materials daily. Different
substances involve different risks. The risk of fire or explosion may be
present at the same time as the danger of being exposed to poisoning or
suffocation. The permissible exposure limit (PEL) is the time-weighted
average threshold limit a person working an 8 hour shift can be exposed to a
chemical without suffering any ill effects [2].
Safe Handling
Handling and storage of Propylene and all the side products is an issue that
must be not to be forgotten or not to deal with it in a proper way. However,
in handling propylene and all the side products, it is recommended to keep it
away from fire, sparks and heated surfaces. Also no smoking near areas
where material is stored or handled. The product should only be stored and
handled in areas with intrinsically safe electrical classification. Based on
literature, the only emission on the process is the catalyst regeneration gas,
which basically consists of nitrogendiluted air with a somewhat elevated CO2
AKA 99
content. It catalyst regeneration gases are vented to the atmosphere
because the amount is not significant.
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Table #: Hazards and Safety Practices of Chemicals
Chemical Physical Hazards Health Hazards Safe Handling Controlling
Propylene
At room temperature and atmospheric pressure it is a colorless
Flammable gas relatively
nontoxic gas
Propylene is nontoxic
Contact with the liquid phase or with the cold gas escaping from cylinder may cause frostbite
Cylinders should be stored and used in dry, well - ventilated areas away from sources of heat or ignition.
Do not store with oxidizers
In the case of leakage, Shut off all ignition sources and ventilate the area
Gasoline Extremely
flammable gas Contact may
cause eye, skin and mucous membrane irritation
Harmful if absorbed through the skin
Inhalation may cause irritation
Keep away from flame, sparks, excessive temperatures and open flame
Use approved vented containers
Keep containers closed and clearly
In the case of inhalation, remove person to fresh air. If person is not breathing, ensure an open airway and provide artificial respiration
AKA 101
labeled
LPG
Extremely flammable gas
Contains gas under pressure
may explode if heated
Exposure could cause irritation but only minor residual injury even if no treatment is given.
Keep away from heat, sparks, open flames or hot surfaces
Store in a well-ventilated place where temperature does not exceed 125 oF
Leaking gas fire: Do not extinguish, unless leak can be stopped safely
In the case of fire, Evacuate all personnel from the danger area
Ethylene
Extremely flammable gas
May form explosive mixtures with air
Could explode if heated
central nervous system depression, difficulty breathing
Store and handle in accordance with all current regulations and standards. Protect from physical damage. Store in a cool, dry place.
EYE CONTACT: Contact with liquid: Immediately flush eyes with plenty of water for at least 15 minutes.
INGESTION: If a large amount is swallowed, get medical attention.
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Methanol
Very Flammable Stable in normal
Conditions Explode at normal
Temperature
Hazardous in case of skin contact (irritant), of eye contact (irritant), of ingestion, of inhalation
Slightly hazardous in case of skin contact (permeator)
Severe over-exposure can result in death.
Keep locked up
Keep away from heat
Keep away from sources of ignition
Ground all equipment containing material
Do not ingest
Do not breathe gas/fumes/ vapor/spray
Store in a segregated and approved area
Provide exhaust ventilation or other engineering controls to keep the airborne concentrations of vapors below their respective threshold limit value
AKA 103
Risk Assessment
Risk assessment, in this context, is a tool used in risk management to help
understand risks and inform the selection and prioritization of prevention and
control strategies. With risk assessment, risks can be ranked on a relative
scale and technical/organizational/policy options can be evaluated, so that
results can be maximized in terms of increased safety. This helps in the
choice of options. Risk assessment also provides information to policymakers
to help them develop risk acceptability or tolerability criteria against which
different objectives or programmers can be assessed.
The following table shows the risk assessment of chemical plants.
Table (3): Risk Assessment of Chemical Plant [3]
Risk Assessment
What is the
hazard
Who could be harmed
ExistingProcedures
Needed actions
How the assessment could be transferred to
an actionwhom when
Chemicals
Hazards
Staff who works in the lab. Getting
skin problems
or irritation to eyes
All staff wears PPE.
Special chemicals
put in shelves
and stored properly. Staff are trained in the risks.
Remind staff to
report any health
problem. Remind staff to
clean gloves and wear
PPE
Supervisor Every day
Electrical Hazards
Electrical operators
. Electrical shocks. Faulty
Insulating electrical
wires. Staff trained in electrical
safety
Remind staff to
check any electrical
equipment before using
Supervisor
During installation preventive
maintenance
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electrical equipme
ntit.
Valves handling
Operators. Valves may leak
and release
chemicals.
Operators wear PPE. Valves are
coated with
insulated materials
Remind staff to
wear PPE. Check valve
before handling it.
Safety manager
During operation
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Table (3): Environmental impact assessment of methanol to propylene plant
component
TypeComposition
(Mole fractions)
ReservoirKSA Regulations
[4] Actions neededProduct
Side Product
Storage
TankTreatment
Unit
Propylene
Polymer grade of Propylene
99.6%
Royal Decree No. 38/ Dated 16.06.1427 - 12/7/2006
Article # 4 Article # 6 Article # 9
See Appendix A
All Instructions are presented in
the MSDS
Gasoline
Pentene 21.9 %
Hexane 18.9 %Heptene 22.9
%Octene 35.7 %
LPG Butene 91.2 %
Ethylene Ethylene 99.9 %
Methanol Methanol
Royal Decree No. 38/ Dated 16.06.1427 - 12/7/2006
See Appendix AWaste Water
Water 99.9 %
Royal Decree No. 38/ Dated 16.06.1427 -
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12/7/2006See Appendix A
Appendix F: Project Timeline
Table #: Project Tasks Performed During Spring 2016
Week # 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15Proposal ReviewLiterature ReviewSimulationOptimizationCapital CostOperating CostPoster DesignProfitability AnalysisSensitivity AnalysisFinal PresentationFinal Report
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