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SRU Pocket Manual Flipbook PDF
SRU Pocket Manual
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Al Zour Refinery
Sulfur Recovery Unit Unit 43
Pocket Manual www.kipic.com.kw
Index Contents
Page
Introduction 1 KIPIC Golden Rules
2
PPEs 3 Information on H2S 4 H2S Awareness 5 Major Unit Hazards
6-7
Main Process Description
8-16
Process Flow Diagram
17
Feed and Product Properties
18
Battery Limit Lines Conditions
19-21
Equipment List 22-27
Introduction In the process of refining crude oil to produce low sulfur products, sulfur in the form of hydrogen sulfide (H2S) is removed from the refinery gas and product streams using a circulating amine solution. Stripped H2S from amine solution and sour off-gas from Sour Water Stripper Unit are sent to Sulfur Recovery Unit (SRU) to convert H2S to elemental sulfur in the SRU as a refinery by product. The new SRU of Al Zour Refinery uses the modified Claus process to produce elemental sulfur and Shell Global Solutions provided the licensed technology and process design for this SRU plant. Unit 43 (Sulfur Recovery Unit) consists of 3 trains which are identical in design and common facilities comprising of Solvent Storage, pumped LP condensate cooling system and utility distribution system. This document describes train-1 as train-2 and train-3 are identical to train-1. Here, all references are made to the first train which is identified as SRU Train-1 (tag no 43-V0101, 43-PT-01022), while the other trains are identified as SRU Train-2 (tag no 43-V-0201, 43-PT-02022) and SRU Train-3 (tag no 43-V-0301, 43-PT-03022). The SRU is designed with a design capacity of 3000 MTPD of sulfur with three operating trains. These trains are identical, each having a design capacity of 1000 MTPD. This unit is designed for normal case of three trains operating as 3 x 33% units. During normal operation, two SRU trains will operate on feed flow control and one SRU train will operate on acid gas header pressure flow cascade control to accommodate pressure fluctuations in the feed gas headers and minimize flaring of acid gas.
01
Sr. No. Golden Rules 1
Obtain Work Permit.
2
Control Lifting Activities And Working at Height Risks.
3
Excavation Risks Shall be Controlled.
4
Confined Space Work Shall Be Authorized.
5
Conduct Gas Test When Required.
6
Use Required Work Related PEEs.
7
All Incidents Shall be Reported.
8
Know Your Roll During Emergency.
9
Enhance Safe Driving Culture.
10
Mind All Moving And Energized Equipment At Your Work Vicinity.
11
Do Not Smoke Outside Designated Smoking Areas.
12
Implement Waste Management.
KIPIC HSE Golden Rules
02
Head Protection
Eye Protection
Hearing Protection
High Visibility Clothing
Hand Protection
Head Protection
NO EXCUSES 1. Personnel H2S monitor to be worn whenever inside the unit. 2. Selection of special PPEs based on activity
03
Hydrogen Sulfide (H2S) Information Effect Period Threshold detectable odor Threshold limit value 8hrs/day Dizziness, light irritation to eyes < 8 hrs PEL / STEL Irritation to eyes & respiratory tract I hour / IDLH Sense of smell is lost 3-15 min Instantly fatal Produces irritating effect on skin LEL 4% UEL 46% Auto Ignition Temp 260°C Fire / Highly flammable, burn with a blue flame. Explosion Sensitive to static discharge and cause a flash fire Hazard Small fire DCP, CO2 Extinguishing media Large fire Use water spray, fog or foam Health 3 NFPA Hazard ratings Flammability 4 Reactivity 0 Chemical splash protective goggles, rubber Non respiratory hand gloves, over all clothing and shoes. Recommended Escape Set 10 minutes duration PPE Respiratory: SCBA 30 minutes duration Air Line Mask Continuous use of breathing air Remove the victim to fresh air area; provide Inhalation artificial respiration or oxygen if needed. Seek Emergency immediate medical attention. / First Immediately flush eyes with running water for at Aid Eyes least 15 minutes, keeping eyelids open Measures Remove contaminated clothing. wash the Skin affected area with plenty of water and soap. Portable Hand Held Detectors Alarm Leak Name of Equipment Range Low/High Detection Mini H2S responders 0-500 ppm 10/15 ppm System Multiwarning detector 0-100 ppm 10/15 ppm ppm 0.01 -0.15 10 20-50 50-100 100-150 Above 1000
(3 in 1)
04
What is H2S? • Colorless (transparent), flammable gas • Heavier than air and tends to accumulate in low-lying areas • Poisonous = Paralize the breathing system / can kill in minutes. • Highly toxic and Very corrosive • Rotten Egg –smell P.E.L. = Permissible Exposure Limit Defined as the maximum concentration you can be exposed to in an 8-hour period, 40 hours per week, without respirator problems. P.E.L. for H2S: 10ppm S.T.E.L. = Short-Term Exposure Limit Based on a 15-minute time period, S.T.E.L. for H2S: 15ppm I.D.L.H. = Immediately Dangerous to Life and Health I.D.L.H. for H2S = 100ppm and above What to Do? • Place H2S monitor below your face/Calibrate the monitors as per schedule. • Know the wind direction/Be aware of your surroundings. • SCBA to be used above IDLH concentration for rescue operation.
05
H2S Awareness
1. Failure of TDS Control in the Claus Waste Heat Boiler & Incinerator Waste Heat Boiler: In case of inadvertent closure of blowdown valve, there will be Total Dissolved Solids (TDS) build-up in waste heat boilers, which is a very slow and gradual process. This is easily readable in the online analyzers available to measure pH and conductivity. These can also be measured in the sampling point (43-SC-0112 & 0114) located in the blow-down line. Sampling frequency is once per week per Licensor (PDP package analytical manual) recommendation. Based on which, the operator will take action to reduce the TDS build up by opening the blowdown valve.
2. Fire in Sulfur Pit: Fire inside a sulfur pit is often caused by static electricity or by the potential build-up of H2S vapor is the scenario of loss of degassing for a prolonged period. A fire in the sulfur pit is detected by the temperature alarms in the vapor space of the sulfur pit. The fire should be extinguished by injection of smothering steam.
Major Unit Hazards
06
3. Fire Inside the Claus Reactors: During the shutdown phase and hot standby operation rapid temperature rise in one of the catalyst beds (temperature runaway) may occur when too much air is supplied to the main burner. Then the sulfur, absorbed in the catalyst, reacts violently with the oxygen in the air, resulting in a fire. When this happens, the air supply to the main burner should be decreased and or the fuel gas supply should be increased to stop the air break-through from the burner (the main burner should be operated sub stoichiometric). The corresponding steam reheater should be stopped. LP steam may be introduced directly into the reactor. When the temperature is dropped, the reheaters can be restarted.
4. Potential H2S Release: Due to the abundance of H2S rich gas streams in SRU, there is a possibility of H2S release from any potential leakages in the Unit. Adequate H2S detectors have been placed across the unit, and proper safety guidelines (usage of PPEs, etc.) have been included.
07
Major Unit Hazards
5.1 Claus Section The amine gas from the three trains of upstream amine regeneration unit (Unit-39) and the acid gas resulting from the SCOT regenerator are combined and routed to the acid gas knock-out vessel, 43-V-0101 to separate entrained water. Off-gas from the three trains of Sour Water Stripper section (Unit-35) passes the SWS gas knock-out vessel, 43-V0102, which further preheated to 1500C.The amine and SWS gas streams are then combined into one stream before entering main burner. In case, a high liquid level occurs in any of the knockout vessels, the sour water is pumped to the Sour Water Stripper Unit. The air supplied to the burner, 43-F-0101 is exactly sufficient to accomplish the complete oxidation of all hydrocarbons and ammonia present in the feed gas. Simultaneously, with an amount of H2S is burnt to obtain a ratio of (H2S: SO2) as 2:1 at the outlet of the second reactor stage. The air to the main burner, 43-F-0101 is mainly supplied by the main air blower, 43-K-0101 A/B. The main air blower also supplies air to the degassing section. The combustion temperature in the combustion chamber has to be sufficiently high (above 1250 °C) in order to obtain proper NH3 destruction.
Main Process Description
08
To remove the heat generated in the main burner and reaction furnace, 43-F-0102, the process gas passes through the tube bundle located in waste heat boiler, 43-E-0101. The process gas is cooled with high pressure boiler feed water thereby generating saturated MP Steam (45 barg steam). Part of the steam is used for heating the process gas in the reheaters, the surplus is superheated in the steam superheater, 43-E-0132 in the incinerator section, then let down to the MP steam grid and sent to the refinery MP steam system. Then, the process gas is introduced into first sulfur condenser, 43-E-0102, where it is further cooled and the sulfur vapor is condensed; liquid sulfur is drained to the pit via a sulfur lock 43-V-0107. The process gas outlet temperature is determined by the condenser design and the pressure of the LP steam generated in the condenser. Further conversion into sulfur is achieved by using a catalytic process in two subsequent reactors, 43-R-0101 and 43-R-0102 containing a highly reactive catalyst. Prior to entering the first reactor, 43-R-0101, the process stream is heated in the first steam reheater, 43-E0106 to the optimum temperature for catalytic conversion. The reaction between H2S and SO2 restarts until equilibrium is reached.
09
Main Process Description
The effluent gas is passed to the corresponding sulfur condenser, 43-E-0103 where the sulfur is condensed and drained to the pit via its sulfur lock 43-V-0108. After the first stage, approximately 86% of the sulfur present in the feed gas has been recovered. To increase the recovery rate, a second reactor stage has been incorporated, consisting of steam reheater, 43-E-0107, reactor, 43-R-0102 and condenser, 43-E-0104. The condensed sulfur is drained to the pit via its sulfur lock 43-V-0109. After the second reactor stage approx. 95% of the sulfur has been recovered. The heat released by cooling the gas and condensing the sulfur results in the production of LP steam. Vane packs are installed in the outlet channels of the sulfur condensers to recover any entrained sulfur mist from the process gas stream. The Claus tail gas is routed via sulfur coalescer, 43-V0106 to the SCOT section. The coalescer is provided with a mist mat to recover entrained sulfur mist from the process gas while any sulfur collected here is drained to the pit via its sulfur lock 43-V-0110.
Main Process Description
10
5.2 SCOT Section The Claus tail gas is heated to the SCOT reactor inlet temperature (220-240°C) in the SCOT reheater, 43-E0121. After leaving the SCOT reheater, 43-E-0121 the hot gas enters SCOT reactor, 43-R-0121, which contains a reducing catalyst. In the reactor all sulfur components are catalytically converted into H2S by the reducing components in the process gas. The process gas normally contains sufficient reducing components (CO and H2). If not, then external hydrogen can be supplied. The residual hydrogen content in the process gas downstream the SCOT reactor is measured by means of an analyser in the gas outlet of quench column, 43-C-0121. The gas temperature rises at the reactor outlet due to exothermic reaction inside the reactor. The process gas leaving the SCOT reactor is cooled to 45°C by direct contact cooling with a counter-current flow of water in quench column, 43-C-0121. Water is circulated on flow control from the bottom of the column via quench water pump, 43-P-0121A/B to the top of the column. The water vapor in the process gas is partly condensed and mixed with the circulating cooling water. The quench water is partly filtered in quench water filter, 43-S-0121 and the excess is sent to the Sour Water Stripper on level control.
11
Main Process Description
The circulating water is cooled from approximately 75 to 65°C in quench water air cooler, 43-E-0122 A/B/C, then it is cooled further to 43°C using cooling water in quench water trim cooler, 43-E-0123 A/B and sent to the top of the quench column. To prevent corrosion (when the pH is less than 6), provisions are available for NH3 injection into the circulating water stream. The overhead gas from the quench column is routed to H2S absorber, 43-C-0122. In the absorber, the process gas is contacted counter-currently with a lean 35%wt MDEA solution supplied to the top of the column by means of flow control. Here, all H2S is removed from the gas and approximately 13% of the CO2 present in the process gas is co-absorbed in the solvent. The treated gas ex absorber (so-called SCOT off-gas) is sent to the incinerator section. The rich solvent leaving the absorber bottom is pumped by 43-P-0122 A/B via lean/rich heat exchanger, 43-E-0124 A/B to the regenerator, 43-C-0123. In the lean/rich heat exchanger, the cold rich solvent is heated by the hot lean solvent from the regenerator bottom. In the regenerator, H2S and CO2 are stripped from the solvent. The required heat is delivered by reboiler, 43-E-0125 A/B, in which rich solvent is heated and steam is generated by means of condensing LP steam.
Main Process Description
12
The released H2S, CO2 and residual steam are routed from the regenerator top via overhead condensers, 43-E-0126A/ B/C/D/E (air cooler) and 43-E-0127 A/B (water cooler) to the reflux vessel, 43-V-0122. The condensed water is separated in this vessel from the acid gas, which is recycled to the Claus section. The liquid from the reflux vessel is introduced as reflux to the regenerator top. The water balance of the solvent is maintained by bleeding water to the Sour Water Stripper. Lean solvent from the regenerator bottom is pumped by lean solvent pump, 43-P-123A/B to the lean/rich heat exchanger. The cooled lean solvent is partly filtered to maintain amine quality. The slip stream flows through three stage filtration systems: Solvent Mechanical filter (43-S-0122), Solvent carbon filter (43-S-0123) and carbon fines filter(43-S-0124). Mechanical filter removes FeS particles and other fine particles from lean solvent. It is followed by Solvent carbon filter to remove surface-active contaminants. Carbon fines filter is provided downstream of the carbon filter to capture carbon fines. The filtered amine is mixed with lean solvent main stream at upstream of lean solvent cooler (43-E-0128), after which it is further cooled (to 40°C) by lean solvent cooler, 43-E-0128. The cooled lean solvent is routed to the H2S absorber top.
13
Main Process Description
For each train a solvent drain system has been provided, consisting of drain vessel, 43-V-0123, pump, 43-P-0125 and filter, 43-S-0125. Additionally, a sour water drain vessel, 43-V-0124 with associated pump, 43-P-0127 are provided. Solvent make-up and storage facilities consisting of a solvent tank, 43-T-0001 with associated pump, 43-P-0001A/B and condensate cooler, 43-E-0001 are installed common to the three trains. There are phosphoric acid dosing and antifoam dosing systems available in the SCOT Section. The phosphoric acid is added during the first solvent preparation stage and helps to improve the regeneration of the solvent. The antifoam dosing chemical is used for reducing foaming problems in the Regenerator and is injected as required.
5.3 Sulfur Degassing Section The sulfur as it is produced in the sulfur recovery plant contains about 300 ppm wt% H2S. Sulfur stripping has been incorporated to reduce the H2S content to less than 10 ppm wt%. It takes place in the stripping section of the sulfur pit, 43-T-0141.After entering the pit, sulfur from the locks is cooled in sulfur cooler, 43-E-0141. Since, the viscosity of degassed sulfur increases rapidly at temperatures above 155°C, it is to be cooled prior to degassing to avoid degassing and pumping problems.
Main Process Description
14
The sulfur temperature in the pit is maintained at around 150°C. There are five bubble columns, 43-A-0141 A/B/C/ D/E located in the stripping section which are identical and have a rectangular cross section. There top and bottom parts are open and are provided with Air distribution spargers at their bottom sides. The stripping air to this sparger is supplied by main air blower. The function of this air is to obtain forced sulfur circulation in and around the bubble columns to strip the dissolved hydrogen sulfide from the liquid sulfur and to oxidize the major part of H2S to sulfur. Furthermore, the removal of H2S from the sulfur promotes the decomposition of polysulfides into dissolved H2S and sulfur. In this way, sulfur with an H2S content of less than 10 ppm wt% is obtained. Besides the stripping air, an additional amount of sweep air is added via the air inlet located on the cover of the degassing section. The total air together with the H2S released from the sulfur is drawn off by the steam driven pit ejector, 43-J-0141 A/B. The Off-gas from the sulfur pit is discharged to the incinerator section with the help of the ejectors 43-J-0141 A/B. The alternate route to the Claus Main burner, 43-F-0101 is now blinded and shall not be used. The sulfur level in the Sulfur pit is constant by pumping degassed sulfur to storage by the sulfur pump, 43-P-0142 A/B. This sulfur pit is equipped with steam coils, 43-E-0143 to maintain temperature of the sulfur in order to avoid pumping issues.
15
Main Process Description
5.4 Incinerator Section The SCOT tail gas (or Claus tail gas in case the SCOT section is bypassed), vent gas from the sulfur pit, vent gas from Sulfur Storage (Unit-96) contains residual H2S and other sulfur compounds which cannot be released directly to the atmosphere. These gases are therefore thermally incinerated in furnace, 43-F-0132 at 800°C to convert residual H2S and sulfur compounds into SO2. The gases to be incinerated are heated by mixing with hot flue gas, obtained by combustion of fuel gas in incinerator burner, 43-F-0131. Here, the air is supplied in three stages: primary, staged and secondary air supplied by incinerator air blowers, 43-K-0131 A/B. The primary air flow rate is 80% of the amount required for stoichiometric combustion of the fuel gas. This reduces the formation of NOx in the burner. The total stoichiometry after the staged air inlet is 130%. The staged air flowrate is therefore adequate to supply sufficient oxygen to burn the unburnt fuel gas and to supply air to incinerate the combustibles in the process gas. The remaining air required for incineration of combustibles plus air required for creating excess oxygen (2 vol%) is supplied by the secondary air. Here, Excess oxygen always ensures (in combination with the high temperature) that the flue gas contains less than 10 ppm vol. H2S. The flue gas leaving the incinerator is cooled to about 505 °C in the incinerator waste heat boiler, 43-E-0131, prior to entering the steam superheater, 43-E-0132. Here the flue gas is further cooled (to 285 °C), thereby producing superheated MP 45 barg steam before releasing flue gases to atmosphere via stack.
Main Process Description
16
17
Feed Specifications : Component
Amine Acid Gas
SWS Acid Gas
Mole %
K mole/h
Mole %
K mole/h
H HS CO CH CH CH NH HO
1.00 90.2 2.0 0.20 0.20 0.10 -6.3
39.10 3526.88 78.20 7.82 7.82 3.91 -246.33
1.0 38.0 ----38.0 23.0
9.78 371.46 ----371.83 224.83
Total Stream Percent of total feed
100.00%
3910.06
100.00
80 %
977.52 20 %
Product Specifications : Parameter
Specification
Purity, wt%
99.8 min (dry basis)
Inorganic Ash, wt%
0.05 max
Carbon, wt%
0.05 max
Color
Bright yellow
Arsenic, ppmw
Nil
Selenium, ppmw
Nil
Tellurium, ppmw
Nil
Chlorides, as NaCl % mass max.
0.005
Acidity, as HSO % mass max.
0.01
Moisture, % mass max.
0.50
The liquid sulfur product after degassing should contain less than 10 ppmw HS.
18
19
1 2 3 4 5 6 7 8 9
Sr. No
Amine Gas Sour Water Stripper Gas HR-PSA/ - 3.5 120 Fuel Gas Reducing Gas (H2 Rich) Solvent Vent Gas Sour Water Liquid Sulfur Solvent
Stream
0.83 0.83 2.3 2.4 6.2 0.27 3.6 3.3 2.5
Normal 0.83 0.83 2.5 2.4 6.2 0.27 3.6 3.3 2.5
Max.
Pres (bar g)
43 82 50 50 40 188 75 150 40
Normal 43 82 50 50 40 188 82 150 40
Max.
Temp(°C)
Operation Conditions
42,892 7,684 2,177 NNF NNF 1,653 26,827 41,647 NNF
42,892 10,507 2,395 266 15,330 3,767 36,992 41,647 15,500
Max.
Flow(Kg/h) Normal
SRU Battery Limit Conditions
3.5 3.5 3.5 3.5 15.5 3.5 15 10.0 15.5
Pres (bar g)
170 170 120 85 85 235 170 180 100
Temp(°C)
Design Conditions
20
Stream
Combustion Air (From Claus Air Blower) Cooling Water Supply Cooling Water Return Potable Water Supply Potable Water Return Utility Water Instrument Air Plant Air Nitrogen LP Steam MP Condensate LP Condensate
Sr. No
10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21.
0.807 4.8 3.4 7.1 2.3 6 7.4 7.5 2.5 4.1 4.5 2.5
Normal 0.807 4.8 3.4 7.2 2.3 11 7.4 8.5 2.9 4.5 5 3
Max.
Pres (bar g)
100 36 50 25 25 40 46 46 46 190 157 138
Normal 100 36 50 36 36 40 46 46 46 210 160 145
Max.
Temp(°C)
Operation Conditions
122,261 104,941 1,722,232 1,722,232 1,722,232 1,722,232 10,000 500 500 500 4,500 420 380 1,543 NNF 990 245 56,575 23,468 20,978 13,810 3,500 3,500
Max.
Flow(Kg/h) Normal
SRU Battery Limit Conditions
3.5 6.9 6.9 14.5 14.5 14.5 10.5 10.5 3.5 6/FV 52/FV 6/FV
Pres (bar g)
150 60 60 85 85 85 85 85 85 235 400 235
Temp(°C)
Design Conditions
21
22. 23. 24. 25. 26. 27. 28. 29. 30.
Sr. No
Cooled Pumped Condensate Pumped Condensate Wet Slops Acid Gas Flare LP BFW HP BFW Intermittent Blow Down 45 barg Steam Continuous Blow down
Stream
3 7.9 4.5 0.1 15.5 96.2 6.5 31.4 6.5
Normal 3 8 6 0.7 20 108 6.5 31.5 6.5
Max.
Pres (bar g)
50 141 50 50 120 120 167 360 167
Normal 50 145 154 154 130 130 167 370 167
Max.
Temp(°C)
Operation Conditions
NNF 38,010 11,856 13 26,840 134,719 118,613 1,336
10,600 45,600 11,856 27,648 31,840 148,937 5,700 118,613 5,700
Max.
Flow(Kg/h) Normal
SRU Battery Limit Conditions
12 22 3.5 3.5 32 121 52/FV 52/FV 52/FV
Pres (bar g)
235 235 180 180 165 165 280 400 280
Temp(°C)
Design Conditions
Equipment List Columns / Reactors / Vessels Mech. Mech. Design Design Temp. Press. o [ C] [bar(ga)]
Size IDxTL-TL [mm]
Internals or other specials
Eqmt. Tag
Eqmt. Name
43-C-0121
QUENCH COLUMN
250
3.5/FV @ 250°C
4,700 × 9,000
43-C-0122
HS ABSORBER
100
3.5/FV@ 160 °C
3,650 × 16,135
43X Mellapak 250Y (9030 mm H)
43-C-0123
REGENERATOR
170
3.5/FV@ 170 °C
2,800 × 29,800
31 Hi-Fi CS Trays / Conventional DC
43-R-0101 43-R-0102
FIRST REACTOR SECOND REACTOR SCOT REACTOR
340 340
3.5 3.5
4,700 × 19,400 4,700 ×19,400
340
3.5/FV
4,700 ×19,400
ACID GAS K.O. VESSEL SWS GAS K.O. VESSEL STEAM VESSEL FOR E-0101 SULFUR COALESCER 1ST SULFUR LOCK 2ND SULFUR LOCK 3RD SULFUR LOCK
170
3.5/FV@ 160°C 3.5/FV@ 160°C 52/FV
1,850 x 3,400
43-R-0121 43-V-0101 43-V-0102 43-V-0103 43-V-0106 43-V-0107 43-V-0108 43-V-0109
170 280 220
Remarks
Sulzer Mellapak 250X or equal packing (3760 mm H)
1,200 x 3,700 2,134 × 12,192 3,900 x 4,550
200 200
3.5/FV@ 160°C 3.5 3.5
200
3.5
100 x 4,500
Part of 43-E-0101
150 x 4,500 150 x 4,500
22
Equipment List Columns / Reactors / Vessels Mech. Mech. Design Design Temp. Press. [oC] [bar(ga)]
Eqmt. Tag
Eqmt. Name
43-V-0110 43-V-0122
4TH SULFUR LOCK REFLUX VESSEL
200 170
43-V-0123
SOLVENT DRAIN VESSEL
170
43-V-0124
SOUR WATER DRAIN VESSEL
43-V-0125
Size IDxTL-TL [mm]
3.5 3.5/FV@ 160°C 3.5/FV@ 160°C
100 x 4,500 2,800 x 5,750
120
3.5/FV@ 160°C
1,250 x 4,000
REBOILER CONDENSATE VESSEL FLARE K.O DRUM
235
6/FV@ 160°C
1,300 x 3,800
180
2,500 x 6,500
43-V-0131
STEAM VESSEL FOR 123-E-0131
280
3.5/FV@ 160°C 52/FV
43-V-0133
FUEL GAS KO VESSEL
120
3.5/FV@ 160°C
500 x 2,932
43-V-134
STEAM DRIER ANTIFOAM POT FOR REFLUX SYSTEM ANTIFOAM POT FOR LEAN SOLVENT SYSTEM
400
52/FV
940 × 4,114
170
15
150 x 250
170
15.5
150 x 250
43-V-0128
43-V-0143
43-V-0144
23
Internals or other specials
Remarks
1,800 x 5,200
2,286 × 3,050
Part of 43-E-0101
Equipment List Pumps Eqmt. Tag
43-P-0001
43-P-0101 43-P-0121 43-P-0122
43-P-0123 43-P-0124 43-P-0125
43-P-0126
43-P-0127 43-P-0128 43-P-0141 43-P-0142
Eqmt. Name
Design Differential Capacity Head [m3/h] [m liq]
SOLVNT 15 TRNSFER PUMP FEED DRAINS TRANSFER 4 PUMP QUENCH 888 WATER PUMP RICH 282.1 SOLVENT PUMP LEAN 297 SOLVENT PUMP 25.2 REFLUX PUMP SOLVENT DRAINS 18 RETURN PUMP REBOILER 49.3 CONDENS PUMP SOUR WATER 7 DRAINS PUMP FLARE K.O. 12 DRUM PUMP SULFUR 23.5 SULFUR 25.8 TRANSFER PUMP
Installed Power [kW]
Driver: Motor/ Turbine
Type of Pump
83.5
15
MOTOR
Centrifugal
33.2
7.5
MOTOR
Centrifugal
82.9
315
MOTOR
Centrifugal
86.5
110
MOTOR
Centrifugal
85.2
110
MOTOR
Centrifugal
64.0
15
MOTOR
Centrifugal
92.9
30
MOTOR
Centrifugal
83.4
30
MOTOR
Centrifugal
44.9
7.5
MOTOR
Centrifugal
68.8
18.5
MOTOR
Centrifugal
13.9
11
MOTOR
Centrifugal
30.9
30
MOTOR
Centrifugal
Remarks
24
25
SOLVENT TANK
SULFUR PIT
0.23
43-T-0141
69,039
0.82
43-T-0001
INCINERATOR AIR BLOWER
43-K0131
96,356
Eqmt. Name
CLAUS AIR BLOWER
43-K0101 Motor
Motor
Driver: Motor/ Turbine
85 200
ATM
0.056
Type of Control
Centrifugal
19,600 x 5,000 x 3,310
8,000 x 5,000
IDxH or LxWxH [mm]
Internals or other specials
Common to 3 trains
Remarks
Centrifugal Capacity Modulation with variable IGV
Type of Compressor
Tanks and Pits and Pits Size
860
3700
Installed Power [kW]
Mech. Mech. Tanks Design Design Temp. Press. [oC] [bar(ga)]
Differential Pressure [Barg]
Compressor and Blowers (K items)
Eqmt. Tag
Eqmt. Name
Eqmt. Tag
Design Capacity [m3/h]
Remarks
Equipment List Heat Exchangers Eqmt. Tag
43-E-0001 43-E-0101 43-E-0102 43-E-0103 43-E-0104 43-E-0105 43-E-0106 43-E-0107 43-E-0121 43-E0122A-C 43-E0123A/B 43-E0124A/B 43-E0125A/B 43-E0126A-E
Eqmt. Name
PUMPED LP CONDENSATE COOLER CLAUS WASTE HEAT BOILER FIRST SULFUR CONDENSER SECOND SULFUR CONDENSER THIRD SULFUR CONDENSER ACID GAS PREHEATER FIRST REHEATER SECOND REHEATER SCOT REHEATER QUENCH WATER COOLER(AIR) QUENCH WATER COOLER (CW) LEAN / RICH HEAT EXCH
Design Duty [kW]
Type : S&T/ AC
8,853
S&T EXCH S&T EXCH S&T EXCH S&T EXCH S&T EXCH S&T EXCH S&T EXCH S&T EXCH S&T EXCH AC EXCH
19,438
PHE
19,515
PHE
REBOILER
27,255
OVERHEAD CONDENSER (AIR)
16,925
S&T EXCH AC EXCH
1201 72714 8578 6459 2955 1480 2,701 2,296 3,453
Shell DP [barg]
Tube DT [°C]
DP [barg]
235
9.3
85
52/FV
280
3.5
370
6.5/FV
180
3.5
220/370
6.5/FV
180
3.5
220/370
6.5/FV
180
3.5
220/370
3.5
280
52/FV
400
3.5
280
52/FV
400
3.5
280
52/FV
400
3.5/HV
280
52/FV
400
-
-
15
120
15
120
15
85
15.5
150
15.5
150
6/FV
235
3.5/ FV
170
-
-
12/FV
3.5
DT [°C]
Remarks
170
26
Equipment List Eqmt. Tag
Eqmt. Name
Design Duty [kW]
Type : S&T/ AC
43-E-0127 A/B
OVERHEAD CONDENSER (CW)
725
S&T EXCH
43-E-0128
LEAN SOLVENT COOLER
6,030
INCINERATOR WASTE HEAT BOILER
15,086
STEAM SUPER HEATER
10,037
43-E-0131 43-E-0132
495
43-E-0141
SULFUR COOLER
43-E-0142
AIR COOLER FOR E-0141
480
43-E-0143
SULFUR PIT STEAM COIL
111
PHE S&T EXCH SUPER HEATER S&T EXCH AC EXCH STEAM COIL
Shell
Tube
DP [barg]
DT [°C]
DP [barg]
DT [°C]
5.4/FV
170
6.9
170
15.5
100
15.5
85
52
280
0.1
370
0.1
400
52
550
6/FV
180
4.7
200
-
-
6/FV
180
6
235
N/A
N/A
Remarks
Fired Heat Trabsfer Equipment Eqmt. Tag
Eqmt. Name
Fired Design Duty [kW]
Desig Pressure [Barg]
Design Temp. [°C]
Type of refractory
Type of burners
Remarks
43-F-0101
CLAUS MAIN BURNER
35,000
3.5
340
Refractory Bricks
Forced draught
Burner part of 43-F-0102.
43-F-0102
CLAUS REACTION FURNACE
3.5
340
3.5
340
Refractory Bricks
Low NOx
Burner part of 43-F-0132.
3.5
340
43-F-0131 INCINERATOR BURNER 43-F-0132 INCINERATOR FURNACE
27
35,000
21