REFINERY PROJECT2018
30,000 BPD full conversion refinery
REFINERY PROJECT
UNITS UNITS DESIGNMAX
m3/D
CRUDE 4,700
NHT 1,800
PLATFORMER - UOP 1,307
PENEX - UOP 500
DHT 1,275
FCCU - UOP 2,000
POLY -UOP 402
FCC MEROX - UOP 868
LDL MEROX - UOP 846
SAT LPG MEROX - UOP 138
UNSAT LPG MEROX -UOP 509
REFINERY PROJECT
• SITE ACERAGE
•
• ACRES Hectares•
• TERMINAL 6.52 2.63• TANK FARM 169.21 68.48• PROCESS AREA 46.24 18.72
• ADMINISTRATION 6.26 2.54• PONDS 21.00 8.49•
• TOTALS 249.20 100.86
Full Conversion Refinery
• The purpose of a full conversion refinery is to utilize as much of the crude oil in to make as much clear product as possible. Clear product is gasoline and diesel.
• These units are also designed to treat each individual product to that it meets or exceeds the required specification.
• A full conversion plant will make the products:
• Off gas- used to fire the heater furnaces
• Propane and Butane. Butane can be added to gasoline for specifications and propane is sold.
Full Conversion Refinery
• LSR – Light Strait Run Gasoline that is hydrotreated and then octane is improved through the Penex unit and then goes to the gasoline pool.
• HSR – Heavy Straight Run Gasoline is hydrotreated and then sent to the Reformer for Octane specification.
• Light Diesel-Kerosene-Jet Fuel goes into the diesel pool or is sold as individual products.
• Regular Diesel is hydrotreated and sent to storage for distribution.
• Atmosphic Gas Oil- AGO is sent to the FCCU again to split the bottom product into LPG’S, two different cuts of gasoline and a diesel product. All of these products are put into the gasoline and diesel pools.
Full Conversion Refinery
• The bottom of the crude tower will then go to the vacuum tower where Light vacuum gasoil, heavy vacuum oil along with the bottom of this tower will go to the FCCU unit.
• All of these different products will have specification and limitation as per the actual design of the refinery.
• This is just a very brief summary of the operation and capabilities of the refinery package.
• The following sheet is a simplified process flow sheet showing the product flows.
C
R
U
D
E
U
N
I
T
Saturated
Gas Plant
Naphtha
Hydrotreater
Kerosene
Merox
Distillate
Hydrotreater
Fluid
Catalytic
Cracker
Amine
Treating
Merox
Treating
Penex
Unit
Platformer
LPG.
Merox
FCCU Gas
Merox
Fuel Gas
Butane and
Propane
Gasoline
Diesel Fuel
Heavy Fuel
Oil
AsphaltVacuum
Unit
Deasphalter
Unit
Sulphur
Plant
Butane
Polymerization
Unit
Refinery Simulation
• The following slides will show a simply refinery Simulation program for optimization purposes.
• The initial crude feed is critical to determine optimization of the plant.
• The following is a example of a full distillation of a crude.
CRUDE FEED
Bonny Light Whole Crude Properties
G ravity, API° 35.30
G ravity SG 0.85
Sulfur, wt% 0.15
Total Nitrogen, ppm 1084.85
Acid Number, mg KOH /g 0.23
Pour Point, °C -11.48
Charact. Factor (K-FACTOR) 11.72
Viscos ity, cSt at 40°C (104°F) 3.28
Viscos ity, cSt at 50°C (122°F) 2.73
Vanadium, ppm 0.44
Nickel, ppm 4.13
MCR, wt% 1.24
Ramsbottom Carbon, wt% 1.02
Asphaltenes, (H .C7) wt% 0.01
Bonny Light SUMMARY OF MAJOR CUTS
Whole Light Medium H eavy Kero Atm Light H eavy Vacuum Atm
Crude Naphtha Naphtha Naphtha G as Oil VG O VG O Res id Res id
TBP Temp At Start, °C Start 10 80 150 200 260 340 450 570 340
TBP Temp At End, °C End 80 150 200 260 340 450 570 End End
TBP Temp At Start, °F Start 55 175 300 400 500 650 850 1050 650
TBP Temp At End, °F End 175 300 400 500 650 850 1050 End End
Yield at Start, vol% 2.2 8.6 25.9 35.4 48.2 68.5 87.2 95.3 68.5
Yield at End, vol% 8.6 25.9 35.4 48.2 68.5 87.2 95.3 100.0 100.0
Yield of Cut (wt% of Crude) 5.1 15.6 9.1 12.8 21.0 20.2 9.1 5.7 35.0
Yield of Cut (vol% of Crude) 6.5 17.2 9.5 12.8 20.4 18.7 8.1 4.7 31.5
G ravity, °API 35.3 81.6 53.5 43.4 36.0 30.6 23.4 16.7 7.0 19.0
Specific G ravity 0.85 0.66 0.76 0.81 0.84 0.87 0.91 0.96 1.02 0.94
Sulfur, wt% 0.15 0.00 0.00 0.01 0.05 0.13 0.23 0.35 0.61 0.32
Mercaptan Sulfur, ppm 0 1 2 3
Nitrogen, ppm 1085 0 0 1 8 93 875 3248 10428 3041
H ydrogen, wt% 16.1 14.2 14.0 13.4 12.9 12.5 11.8
Viscos ity @ 40 °C (104 °F), cSt 3.28 0.42 0.62 1.04 1.93 4.65 33.51 1.18E+03 2.E+07 2.08E+02
Viscos ity @ 50 °C (122 °F), cSt 2.73 0.40 0.57 0.91 1.65 3.72 21.93 5.14E+02 2.E+06 1.14E+02
Viscos ity @ 100 °C (212 °F), cSt 1.32 0.31 0.40 0.57 0.89 1.58 5.07 3.32E+01 5.E+03 1.50E+01
Viscos ity @ 135 °C (275 °F), cSt 0.93 0.28 0.35 0.46 0.67 1.04 2.63 1.10E+01 4.E+02 6.31E+00
Freeze Point, °C 34 -125 -100 -74 -44 -6 30 53 71 51
Freeze Point, °F 92 -192 -147 -101 -48 22 85 128 159 123
Pour Point, °C -11 -131 -105 -76 -47 -10 27 49 75 35
Pour Point, °F 11 -203 -157 -106 -53 14 80 120 167 95
Smoke Point, mm (ASTM) 10 36 32 27 20 14 8 4 2 4
Aniline Point, °C 68 71 54 54 58 67 79 85 91 82
Aniline Point, °F 154 160 129 129 136 153 174 185 195 180
Total Acid Number, mg KOH /g 0.2 0.0 0.0 0.0 0.0 0.1 0.2 0.2 0.2 0.2
Cetane Index, ASTM D4737 33 39 48
Diesel Index 54 131 69 56 49 47 41 31 14 34
Characterization Factor (K Factor) 11.7 12.6 11.6 11.5 11.5 11.6 11.6 11.7 11.6 11.6
Research Octane Number, Clear 75.5 65.1 37.4
Motor Octane Number, Clear 73.1 63.2
Paraffins , vol% 83.3 39.7 28.7 24.2
Naphthenes , vol% 16.7 46.4 57.2 57.1
Aromatics , vol% 0.0 13.9 14.1 18.7
Thiophenes , vol%
Molecular Weight 196 102 114 140 172 218 306 437 693 347
G ross H eating Value, MM BTU/bbl 5.83 4.85 5.39 5.63 5.81 5.95 6.14 6.32 6.57 6.26
G ross H eating Value, kcal/kg 10915 11584 11189 11038 10911 10816 10668 10508 10215 10562
Gross H eating Value, MJ/kg 45.7 48.5 46.8 46.2 45.7 45.3 44.6 44.0 42.7 44.2
H eptane Asphaltenes, wt% 0.0 0.2 0.0
Micro Carbon Res idue, wt% 1.2 20.0 3.5
Ramsbottom Carbon, wt% 1.0 16.4 2.9
Vanadium, ppm 0 8 1
Nickel, ppm 4 72 12
Iron, ppm 1 20 3
Date Assayed
2/7/2010
Crude
Bonny Light Whole Crude Properties
Gravity, API° 35.30
Gravity SG 0.85
Sulfur, wt% 0.15
Total Nitrogen, ppm 1084.85
Acid Number, mg KOH/g 0.23
Pour Point, °C -11.48
Charact. Factor (K-FACTOR) 11.72
Viscosity, cSt at 40°C (104°F) 3.28
Viscosity, cSt at 50°C (122°F) 2.73
Vanadium, ppm 0.44
Nickel, ppm 4.13
MCR, wt% 1.24
Ramsbottom Carbon, wt% 1.02
Asphaltenes, (H.C7) wt% 0.01
Bonny Light SUMMARY OF MAJOR CUTS
Whole Light Medium Heavy Kero Atm Light Heavy Vacuum Atm
Crude Naphtha Naphtha Naphtha Gas Oil VGO VGO Resid Resid
TBP Temp At Start, °C Start 10 80 150 200 260 340 450 570 340
TBP Temp At End, °C End 80 150 200 260 340 450 570 End End
TBP Temp At Start, °F Start 55 175 300 400 500 650 850 1050 650
TBP Temp At End, °F End 175 300 400 500 650 850 1050 End End
Yield at Start, vol% 2.2 8.6 25.9 35.4 48.2 68.5 87.2 95.3 68.5
Yield at End, vol% 8.6 25.9 35.4 48.2 68.5 87.2 95.3 100.0 100.0
Yield of Cut (wt% of Crude) 5.1 15.6 9.1 12.8 21.0 20.2 9.1 5.7 35.0
Yield of Cut (vol% of Crude) 6.5 17.2 9.5 12.8 20.4 18.7 8.1 4.7 31.5
Gravity, °API 35.3 81.6 53.5 43.4 36.0 30.6 23.4 16.7 7.0 19.0
Specific Gravity 0.85 0.66 0.76 0.81 0.84 0.87 0.91 0.96 1.02 0.94
Sulfur, wt% 0.15 0.00 0.00 0.01 0.05 0.13 0.23 0.35 0.61 0.32
Mercaptan Sulfur, ppm 0 1 2 3
Nitrogen, ppm 1085 0 0 1 8 93 875 3248 10428 3041
Hydrogen, wt% 16.1 14.2 14.0 13.4 12.9 12.5 11.8
Viscosity @ 40 °C (104 °F), cSt 3.28 0.42 0.62 1.04 1.93 4.65 33.51 1.18E+03 2.E+07 2.08E+02
Viscosity @ 50 °C (122 °F), cSt 2.73 0.40 0.57 0.91 1.65 3.72 21.93 5.14E+02 2.E+06 1.14E+02
Viscosity @ 100 °C (212 °F), cSt 1.32 0.31 0.40 0.57 0.89 1.58 5.07 3.32E+01 5.E+03 1.50E+01
Viscosity @ 135 °C (275 °F), cSt 0.93 0.28 0.35 0.46 0.67 1.04 2.63 1.10E+01 4.E+02 6.31E+00
Freeze Point, °C 34 -125 -100 -74 -44 -6 30 53 71 51
Freeze Point, °F 92 -192 -147 -101 -48 22 85 128 159 123
Pour Point, °C -11 -131 -105 -76 -47 -10 27 49 75 35
Pour Point, °F 11 -203 -157 -106 -53 14 80 120 167 95
Smoke Point, mm (ASTM) 10 36 32 27 20 14 8 4 2 4
Aniline Point, °C 68 71 54 54 58 67 79 85 91 82
Aniline Point, °F 154 160 129 129 136 153 174 185 195 180
Total Acid Number, mg KOH/g 0.2 0.0 0.0 0.0 0.0 0.1 0.2 0.2 0.2 0.2
Cetane Index, ASTM D4737 33 39 48
Diesel Index 54 131 69 56 49 47 41 31 14 34
Characterization Factor (K Factor) 11.7 12.6 11.6 11.5 11.5 11.6 11.6 11.7 11.6 11.6
Research Octane Number, Clear 75.5 65.1 37.4
Motor Octane Number, Clear 73.1 63.2
Paraffins, vol% 83.3 39.7 28.7 24.2
Naphthenes, vol% 16.7 46.4 57.2 57.1
Aromatics, vol% 0.0 13.9 14.1 18.7
Thiophenes, vol%
Molecular Weight 196 102 114 140 172 218 306 437 693 347
Gross Heating Value, MM BTU/bbl 5.83 4.85 5.39 5.63 5.81 5.95 6.14 6.32 6.57 6.26
Gross Heating Value, kcal/kg 10915 11584 11189 11038 10911 10816 10668 10508 10215 10562
Gross Heating Value, MJ/kg 45.7 48.5 46.8 46.2 45.7 45.3 44.6 44.0 42.7 44.2
Heptane Asphaltenes, wt% 0.0 0.2 0.0
Micro Carbon Residue, wt% 1.2 20.0 3.5
Ramsbottom Carbon, wt% 1.0 16.4 2.9
Vanadium, ppm 0 8 1
Nickel, ppm 4 72 12
Iron, ppm 1 20 3
Simulation Model
• The following is a typical model looking at the production, costs and product amounts for optimization of the process equipment.
REFINERY ECONOMICS REVIEW
REFERENCE PRICE
Bonney Light 0 PLATFORMING OPERATION
0 Enter the desired factor
POF (2) 0.83
BUY Volume m3/d Tons/d COST US/m3 TOTAL US
Bonney Light 4770.0 3776.9 0.0 0.00
0.0 0.0 0.0 0.00
Others
TOTAL 4770 3776.9 0.00 Capacity Utilization
CRUDE FEED 100.0 OK
VACUUM 98.3 OK
SELL Volume m3/d Tons/d PRICE US/m3 TOTAL US FCC FEED 79.5 OK
Propane 125.3 63.6 0.0 0.00 CC in FCC feed 0.66 OK
Butane 162.1 94.7 0.0 0.00
Premium Gasoline 212.1 168.3 0.0 0.00 NHT 80
Regular Gasoline 1918.7 1523.1 0.0 0.00 Diesel HTU 97
Low Oct. Gasoline 0.0 0.0 0.0 0.00 Platforming 68.1
Jet 751.5 607.3 0.0 0.00 Penex 111
Diesel 1253.3 1056.8 0.0 0.00 Poly 72
Mazut (1) 157.3 166.7 0.0 0.00
Asphaltenes 130.8 137.4 0.0 0.00 Overall Yield % 98.8
TOTAL 4711.0 3817.9 0.00
PRODUCT MARGIN 0.00
MARGIN/m3 CRUDE 0.00
NOTES:
(1) Mazut: Cat slurry oil + Vacuum Bottoms. Does not meet Mazut specifications.
(2) Platforming Operation Factor = RON 97 Platf operation / Platf operation
(3) Assumed price for Asphaltenes is 105 US/M3
REMARKS: No Extra Vacuum Capacity
CRUDE DISTILLATION UNIT
OVER HEAD 1589 OK
MAX CAP 2000
MIN CAP 1000
T end °C Yields %vol Vol
3.50 167
95 11.66 556
Bonney Light % 175 18.14 865
4770 100.0
250 15.76 752
4770 360 19.87 948
0 0.0
375 2.22 106
MAX CAP 4770
MIN CAP 3800
OK
Cap util 100.0 Con SG
510 16.40 782 0.01 1.217 0.10
SG 0.7918 550 4.06 194 0.65 0.957 1.20
550 + 8.40 401 12.75 0.999 51.07
28.86
VACUUM 1377 OK
MAX CAP 1400
MIN CAP 1000
Cap util 98.3
NOTES: 0
(1) All volumes in m3/d Con SG
0 12.54 1.1167
0.0
LPG
LN
KER
HDSL
LVGO
HVGO
VRC
CDUFEED
HN
AGO
To Mazut
To FCC
FLUID CATALYTIC CRACKING UNIT
Yields %vol Volume
Volume 106
C Carbon 0.01
SG 1.1486
7.6121 102.9
Volume 782 1.7279 23.4
C Carbon 0.01 287.5 7.08642 95.8
SG 1.2166 21% 3.73409 50.5
1.10949 15.0
Volume 194
C Carbon 0.65 52.15 704.8
SG 0.9570
21.7 293.3
Feed 1351
VCR C Carbon 0.66
Volume 68 SG 1.1234 11.64 157.3
C Carbon 12.75
SG 0.9990 Max Feed 1700
Min Feed 1200 OK
Aspheltene Content1.25 %w Max C Carbon 3.09
Min C Carbon 0.05 OK
DAO
Volume 202 Abottoms
C Carbon 0.01 VCR Volume 361.21 299.883
SG 0.9500 Feed 1644.4 1477.362
C Carbon 2.62 2.43
Atmospheric Bottoms SG 1.1012 1.2081
Volume 0.0
C Carbon 12.54 Cap util 79.5
SG 1.1167
NOTES:
(1) All volumes in m3/d
(2) Maximizing VRC to FCC, limitation ConCarbon Content
LVGO
HVGO
VRC
FEED
FCC
F GAS
C3
N CRAC
LCO
SLURRY
1. To Calculate DAO and Max Atmospheric Bottoms as a feed to FCC regarding
ConCarbon content and FCC Cap
C4=
C3=
iC4
nC4
Unsat LPG
AGO
2. To Calculate MAX VRC as a feed to FCC regarding
ConCarbon content and
FCC Cap
% Vol yield Volume To FCC
60.7 201.7 202
Feed
401 332.5 0.0
Resid From Vacuum
Tower
SG 0.999
Asphaltenes 1.25
39.3 130.8
68.3
68.32
0.0 0.0
NOTES: Max Cap 332.5
(1) All volumes in m3/d
De Asphalting
Unit
DAO
Asphaltenes
To Mazut
To FCC
To Mazut
DIESEL HYDROTREATER UNIT
Yields %vol Volume
Volume 948
SG 0.8200
Sulphur 0.550 2.0 24.8
2.0 24.8
Volume 293
SG 0.8709
Sulphur 0.500 101.0 1253.3
Feed 1241
SG 0.8320
S 0.54
Cap util 97.3
NOTES:
(1) All volumes in m3/d
HDSL
LCOHTU
LPG
To Naphtha HTU
DSL
CATALYTIC POLYMERIZATION UNIT
23.4
50.5
15.0
Flow 88.8
Volume
102.9 99.3
23.4
95.8
50.5
15.0
Cap util 71.5
NOTES:
(1) All volumes in m3/d
C3
C4=
C3=
iC4
nC4
Unsat LPGPOLY
LPG
Poly Gasoline
C3iC4
nC4
C5/C6 PENEX UNIT
551
556
Max Capacity 500
Capacity util 111
NOTES:
(1) All volumes in m3/d
ISOMER
ISOMERATE
LN
Case 2: Octane 97 2 Yields %vol Volume
0.745 5.5 776.1
0.529 3.9
Cap utilization 68.1
714 0.466 3.4
20
86.0 631.5
OCTANE 97
POF (2) 0.83
PLATFHN
C3
iC4
nC4
Platformate
nC4
Platformate
Nafta fromDHTU
LPG
Volume
167 125.27
24.8
13.9 162.1
88.8
NOTES:
(1) All volumes in m3/d
From CDU
From Diesel HTU
From Platformer
From Poly
C3's
C4'sLPG
BENZENE BLEND
Benzene - Premium 95.0
% Volumes to blend
14.1 From FCC 29.9
14.1 From Poly 29.9
66.9 From Platf. RON97 141.9
0.0 From Platf. RON90 0.0 212.1
0.0 From Platf. RON60 0.0
4.9 From Penex 10.3
Benzene - Regular 91.0
% Volumes to blend
40.9 From FCC 674.8
4.2 From Poly 69.4
29.7 From Platf. RON97 489.6
0.0 From Platf. RON90 0.0 1650.6
0.0 From Platf. RON60 0.0
25.2 From Penex 416.8
Benzene - Premium RON 95
Benzene - RegularRON 91
Benzene
Benzene
PLOT PLAN
Construction
• The refinery complex should be constructed as close to possible to utilize all the engineering and drawings as possible.
• Tank farm. The original plant had about 1.3 million barrels of total capacity. The refinery package has about one half of this capacity that will have to be constructed.
• We have a new AutoCAD drawing of the tank farm but before this is finalized, a technical review should be completed for optimized utilization of this area.
• The following is a Construction schedule.
0
100
200
300
400
500
600
700
800
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18
Manmonths
Months
CONSTRUCTION SCHEDULE
• All the utilities will have to be connected – steam, sewer system, fire water hydrant system, DCS system, flare.
• Tankage. There is about 400,000 barrel capacity included. Rolled
• Laboratory equipment for testing. Octane testing equipment, distillation machine, sulphur indication, cloud and pour cooler, flash equipment and may others.
• It is standard to have a product release form and retain program.
• There are chemicals that can be added to increase the octane such as MTBE, MMT, TAME. Here are may fact’s that must be considered as maximum addition rates, government regulations, cost and availability.
DRAWINGS AND DOCUMENTATION
• 3200 drawings of piping locations, undergrounds, electrical, instrumentation, foundations.
• Another 1500 drawings of vendor or as built drawings.
• Spool drawings
• Isometric drawings.
• P&ID drawings, mechanical drawings and as built,
• These drawings are not replaceable so that we must have control at all times so that they are under strict control.
• A copy machine will have to be available fro copying these drawings.
Piping Specifications
• Line list of all lines and specifications.
• Detailed list of all specifications related to material required for these line requirements.
• On P&IDs all lines have 36” PBA and number. These numbers can be related back so that you can see exactly the service of the line and what it is used for.
• We also have the engineering Specification book that is used for quality control in all aspects of the refinery equipment.
Match Marking
• When the refinery was taken down an engineering company did the match marking for the complete faculty.
• Pictures of all different pieces.
• Detailed location of the pieces.
• Set of drawings to match the pictures and documentation.
• All this information can be cross referenced.
Undergrounds
• We have a complete set of these drawings.
• We must use these drawings as a guideline but then incorporate the other areas that we must include.
• We must also look at what is required to complete these systems.
• There were some fire water hydrants brought with the refinery package but a review will have to be completed so that the full scope if covered to complete these systems for the refinery and the extra equipment that will be added.
Environmental
• We have the following for reference.
• Water permit usage and release.
• Flare release guidelines.
• Fugitive emissions permit and release guidelines.
• We have completed a emission study of the products and tanks emissions.
• Chemical usage
Catalysts and chemicals
• Catalysts for the equipment will be important. We will use the catalyst and chemical suppliers to give us the best product for the material and specifications that we require.
Spare Parts
• Spare parts inventory will be very important.
• We have the inventory records that were kept by part number and this can be referenced to each individual piece of equipment by equipment numbers.
• This information also indicates the frequency that they parts were used.
Storage Tanks
• A refinery of this size will have about 1.3 million barrels of capacity but will depend on many things.
• How is the crude coming in.
• How is the product going out.
• What tanks are needed for normal operations.
• An evaluation should be done when we know all of this information.
• We have to have a tank monitoring system – System like a Varec system or do in put it onto the Honeywell system.
Laboratory Equipment.
• What do we need to complete all tests.
• We must know the regulations or specifications required.
• We have a list of all equipment that was used in the past.
Buildings
• Office building
• Maintenance building
• Lunch rooms, washrooms.
• Control Building.
• We have the floor plan drawings for these buildings.
Utilities
• Water requirements
• Power requirements
• Fuel gas requirements over and above the amount that is produced in the plant.
• Nitrogen
• Hydrogen
Security and people
• Fence to isolate the facility.
• Security for the plant.
• How do handle fire protection and what is required.
• Foam systems deluge systems.
• These plants require trained experienced personal to operate them correctly.
Operation
• We have a team of individuals that have worked at the plant that will help with the construction, commissioning and start up of the facility.
• These individuals will train and work with in country employees.
• All start up, shut down and emergency procedures are available.