2. Some Basics
Technology M.W. Kellogg
Year of built 1970
Capacity 815 MTPD
BMR 1991
Steam per Ton NH3 4.9 MT
Steam per Ton urea 1.4 MT
NH3 per ton of urea 0.58 MT
4. Natural Gas
Natural gas is received from SNGPL.
Its contents are;
CH4 87 %
N2 9.2 %
CO2 1.8 %
Other HC 0.4 %
T. Sulfur 7ppm
5. Natural Gas
N.G. Pressure at battery Limit = 590psig
PRe-35 indicates & records the battery limit pressure.
It is increased by a Positive Displacement Compressor
1102-J.
It is double acting single stage reciprocating PD
Compressor.
It is provided with a knock out drum to prevent
Naphtha to enter into the compressor.
PICe-202 is provided to control discharge pressure.
7. Feed Gas
Feed Gas is to heat at required temperature.
After 1102-J feed gas passes through 1139-C and then
through Feed Pre Heat Coil of 101-B.
At this stage temperature = 700°F
After feed pre heat coil feed gas is passed through 103-
B (Feed Gas Preheater).
Then gas is entered into Hydrotreater 101-D.
8. Hydrogen Injection
H2 is injected into Feed Gas for Hydrotreating.
H2 is injected from LP discharge of Syn Gas
Compressor 1103-J.
There are three pints for H2 injection.
1. Before 1139-C
2. After 1139-C
3. After Feed Pre Heat Coil.
Now a days before 1139-C point is used.
9. Hydrotreating
This is the first step to remove Sulfur from natural gas.
Sulfur compounds in N.G are reacted with H2 to form
H2S.
This reaction is carried out in HYDROTREATER 101-D
The reactions are;
RHS + H2 → H2S + RH
COS + 3H2 → H2S + CS3OH
10. Hydrotreater 101-D
Catalyst Cobalt Molebdenum (CoMo)
Inlet Temperature 700ºF
Pressure 580#
ΔP across 101-D 4.5#
Total volume of catalyst 750 ft3
Height 30 ft
Diameter 6 ft
11. Desulphurization
H2S produced in Hydrotreater is reacted with ZnO
catalyst in Desulphurizers. (102-DA/DB)
The reaction is;
H2S + ZnO → ZnS + H2O
Total life expectancy
of catalyst is one year.
102-D out pressure is 565psig.
After 102-D in feed gas
Total Sulfur = 0.05 ppm
H2S = NIL
12. Desulphurizers 102-DA/DB
Catalyst Zinc oxide (ZnO)
Inlet Temperature 680°F
Pressure 575#
ΔP across 101-D 4 - 5#
Total volume of catalyst 410 ft3
Height 19.5 ft
Diameter 8.5 ft
13. The second raw material Steam is mixed in DS Gas and
mixed feed is entered in Primary Reformer 101-B
575# Steam
FRCe-102
DS Gas
Primary
Reformer
101-B
16. Primary Reformer
After Mixed Feed Coil, feed gas is entered in Primary
Reformer 101-B
Mixed Feed
Coil
101-B
850°F
17. Primary Reformer
It is Induced Draft Furnace
Headers 6
Tubes in each header 44
Tubes 264
Burner rows 7
Burners 140
An induced draft fan is
provided to pull out flue
gases from out of furnace
and thus create draft in
furnace.
18. Primary Reformer
In primary reformer steam is reacted with methane to give CO2
and H2O.
The reactions are;
CH4 + H2O → CO + 3H2 (Endothermic)
CO + H2O → CO2 + H2 (Exothermic)
CH4 + 2H2O → CO2 + 4H2 (Endothermic)
Overall reaction is endothermic, so a lot of heat input is
required for reforming reactions.
Ni
Ni
19. Primary Reformer Convection
Section Coils Auxiliary
Heater
Steam Air
Coil
Mixed Feed
Coil
HOT
SUPRHTR
BFW HT
BFW LT
Feed Preheat
Fuel
Preheat
Saturator
Coil
COLD
SUPRHTR
Flue Gases
Arch Burner Rows
Tunnel Burners
S.H Burners
ID Fan
22. H2 + O2 → H2O (Exothermic)
CH4 + 2H2O → CO2 + 4H2 (Endothermic)
Secondary Reformer
Two reactions occurred in 103-D.
Ni
23. Secondary Reformer
In first portion, combustion of H2 takes place as air is
entered in the vessel on high temperature.
This reaction is highly exothermic and H2O is
produced along-with a lot of heat.
Then produced steam is reacted with the methane
coming from 101-B.
The second reaction is similar to as primary reforming
reaction.
Heat produced in 1st reaction is used for the 2nd
endothermic reaction.
24. Secondary Reformer
Catalyst Nickel (Ni)
Catalyst Volume 710 ft3
Inlet temperature 1485°F
Outlet temperature 1780°F
The vessel is water jacketed to keep the metal
temperature in safe limit.
In normal steam condensate is in water jacket.
In emergency conditions, cooling water or fire water
may be used.
25. Waste Heat Boiler
The effluent of 103-D contains a huge amount of heat.
This quantity of heat is used to produce 1500psig
steam.
A Waste Heat Boiler 1101-C / 1101-F is provided for this
purpose.
By this 320,000 lb/hr steam is generated.
27. K
O
D
Feed
Pre Heat
Coil
1102-J 1139-C 103-B
101-D
102-D
A
102-D
B
Mixed
Feed
Coil
FRCe-101
FRCe-102
101-B
103-D
1101-F
1101-C
Mixed
Feed
Coil
FRCe-103
MICe-10
1500#
steam
102-D
B
103-D
102-D
A
102-D
B
103-D
101-D
102-D
A
102-D
B
103-D
103-B
101-B
28. Shift Conversion
At the exit of 103-D, feed gas contains 11.6% CO
We are to convert this CO into CO2.
Conversion of CO into CO2 is called shift reaction.
The reaction is;
CO + H2O → CO2 + H2 (Exothermic)
This shift reaction is carried out in two separate vessels.
1. High Temperature Shift Converter (104-D)
2. Low Temperature Shift Converter (108-D)
29. High Temperature Shift Converter (104-D)
Feed gas at temp. of 640°F is entered in HTS.
TRCe-610 controls the temp. of HTS in.
HTS reaction is exothermic.
Catalyst in HTS Fe
Catalyst Volume 1450 ft3
Outlet temp. 740°F
ΔP across vessel 6 psig
After HTS CO 2%
30. Low Temperature Shift Converter (108-D)
After HTS feed gas temp is 740°F,
At the inlet of LTS, 400°F temp is required.
So feed gas is passed through a series of Heat Exchangers.
Catalyst in LTS Cu
Catalyst Volume 1490 ft3
After HTS CO 0.15 %
Max. allowable temp. 500°F
Poisons for catalyst Chlorine and Sulphur
32. CO2 Removal System
After LTS, feed gas contains;
CO2 18%
CO 0.15%
H2 60%
N2 20%
This CO2 is to be separated from the feed gas.
CO2 is removed in CO2 Removal System.
33. CATACARB System
After LTS, feed gas of temp 435°F is passed through
De-Super Heater.
Steam condensate is injected and temp of gas is
lowered to 356°F.
Then gas exchanges its latent heat in CO2 Stripper
Gas Exchanger 1105-CA/CB.
After 1105-C, Raw Gas Separator (102-F) collects
process condensate from the Gas Stream.
Then Gas enters into the CO2 Absorber.
34. CO2 Absorber 101-E
In CO2 Absorber, gas flows upward through 4 beds of
Polypropylene packing.
From top of Absorber, catalyzed solution of Potassium
Carbonate (CATACARB Solution) is showered and
contacts counter currently with the up coming Gas.
CO2 is absorbed in Catacarb Solution (Rich Solution)
and this rich soln. is transferred to the top of CO2
Stripper (102-E).
Level of Absorber is controlled with LICe-6 A, C & D
valves.
35. CO2 Absorber 101-E
Catalyzed solution of potassium carbonate absorbs
CO2 by chemical reaction;
CO2 + H2O → H2CO3
H2CO3 + CO2 → 2HCO3
This reaction takes place under high pressure (400#)
and low temperature (180°F top, 256°F bottom)
conditions.
36. Factors Affecting CO2 Absorption
High
Pressure
400psig
Low
Temperature
180°F top
256°F bot.
Solution
Strength
Normality
Catalyst
Volume
11-12 %
38. CO2 Absorber 101-E
Temperature Top 178°F
Bottom 256°F
Operating Pressure 410#
Setting of PSV 435#
No. of Beds 4
Rings material
1st bed Poly Propylene Pall Rings
2nd, 3rd & 4th bed Stainless Steel
39. CO2 Stripper (102-E)
CO2 absorbed in Catacarb Solution is separated in
CO2 stripper (102-E).
Rich Solution enters into the stripper from its top.
While coming down through the stripper, CO2 is
separated from the solution under high temperature
(222°F top, 265°F bottom) and low pressure (5#).
CO2 product is exited from the top of the Stripper at a
pressure of 5psig.
Pressure is controlled by PICe-24.
40. CO2 Stripper (102-E)
Reflux water is entered at the top of the Stripper above
first bed.
This reflux water prevent any carry over of Catacarb
Solution with CO2 product.
CO2 product is cooled in 110-C1A/B and C2A/B.
113-F collects the condensate from CO2 Product.
This condensate is pumped with 108-J/JA as reflux
water at the top of the Stripper..
41. CO2 Stripper 102-E
Temperature Top 222°F
Bottom 265°F
Operating Pressure 5#
Setting of PSV 435#
No. of Beds 5
Rings material
1st, 2nd & 3rd bed Stainless Steel
4th & 5th beds Poly Propylene Pall Rings
43. 107-JHT
Hydraulic turbine 107-JHT is installed for energy
conservation point of view.
High pressure energy of Absorber is used to run the
Hydraulic Turbine while solution transfer to low
pressure Stripper.
JT
JHT 107-J
A steam turbine is also provided with 107-J Semi-Lean
Solution Pump to support JHT
44. Flasher 1103-E
Rich solution is entered into Flasher after discharge of
Hydraulic Turbine.
The purpose of Flasher is to decrease H2 in CO2
Product.
H2 in CO2 Product;
When Flasher is in service 0.20 %
When Flasher is out of service 1.0 %
47. Absorber Over Head
Gas free of CO2 is exited from the top of the 101-E.
Entrained Catacarb Solution is separated in 116-F.
This gas contains;
CO2 0.25%
CO 0.2%
H2 74%
N2 24%
48. Why CO2 slippage is dangerous?
Oxides are poison for NH3 Converter catalyst.
Ammonium Carbamade is produced in 9th wheel of
103-J HP case which is highly corrosive.
So
It is necessary to convert CO & CO2 into CH4 which is
inert for NH3 Converter catalyst.
This process is called Methanation.
49. Methanation
From top of Absorber syn gas is to be entered in
Methanator.
CO & CO2 present in it are converted into CH4 which is
inert for NH3 converter catalyst.
Methanation reaction is;
CO + H2 → CH4 + H2O
CO2 + H2 → CH4 + H2O
These reactions are highly exothermic.
50. Methanator 106-D
Manufacturer DESCON Engineering
Design pressure 435psig
Design temperature 850°F
Catalyst volume 600 ft3
Catalyst poison Sulfur & Chlorine
Methanator is tripped in case of high beds
temperature.
HTA-12 & 13 are provided which closes V-17 (inlet valve
of Methanator) at 750°F.
52. Methanator Effluent
After Methanator, syn gas contains;
H2 74 %
N2 24 %
CO2 7ppm
After 106-D, syn Gas temp is 650°F which is cooled
upto 105°F in 114-C & 115-C.
53. Synthesis Section
After Methanator, synthesis gas is to be compressed up
to required pressure for NH3 synthesis reaction i.e. 1880
psig.
1103-J Synthesis Gas Compressor is provided for this
purpose.
High temperature Methanator effluent gas is to be
cooled before suction of 1103-J.
114-C, 115-C & a K.O.D 104-F are provided for cooling
and removing moisture from the syn gas.
55. Synthesis Gas Compressor 1103-J
It is two stage centrifugal compressor driven by two
steam turbines, one is condensing and the other is
non-condensing.
Its LP case receives syn gas at pressure of 370# and
105F.
Discharge pressure of LP case is 970# and 340F
56. 1103-J
Suction Pressure 370#
Suction Temperature 105°F
Discharge Pressure 940#
Discharge Temperature 340°F
No. of wheels 1st stage 9
No. of wheels 2nd stage 9
RPM 10200
57. Molecular Sieve Drier 1109-D
After LP case discharge, syn gas is cooled in a series of
exchangers i.e. 1136-C, 116-C & 129-C.
Then it passes through Molecular Sieve Drier 1109-
DA/DB
It is to remove any moisture or CO2 content present in
syn gas.
After 1109-D,
Moisture 0.05 ppm (on AR-820)
CO2 4 ppm
58. Ammonia Converter 1105-D
Synthesis gas at pressure 1880# and temperature 270F
enters in to the Ammonia Converter 1105-D.
Ammonia Synthesis reaction;
N2 + 3H2 → 2NH3
Efficiency of Ammonia Converter is 14%.
Ammonia Converter Catalyst is Fe.
62. Ammonia Converter 1105-D
Manufacturer Halder Topsoe
Model S-200
Type Radial Flow Type
Catalyst beds 2
Catalyst in 1st bed KMR
Volume 14.6 m3
Catalyst in 2nd bed KM1
Volume 59.8 m3
63. After Converter
After converter, Ammonia which is almost 15% in
converter effluent gases, is separated from converter
effluent gases.
This separation is done by refrigeration of the effluent
gases.
For this purpose, a refrigeration system is designed in
which Ammonia is used for refrigeration.
After separation of Ammonia, remaining gas is
recycled to 103-J HP Case 9th wheel for synthesis.
65. Product Ammonia
Refrigerated Ammonia is collected in 106-F at -13°F &
1650 psig.
From 106-F, it is transferred to 107-F through LC-12
and its pressure reduced to 225 psig.
From 107-F, ammonia is transferred to 111-F & 112-F
through FICe-14 & LC-13.
SCOPE MANAGEMENT – Ensuring all the appropriate work within the project scope is completed and only the work within scope is being conducted
TIME MANAGEMENT – Schedule Management
COST MANAGEMENT – How costs are controlled and incurred costs are paid
QUALITY MANAGEMENT – Quality Assurance Plan – How quality control is measured and satisfied
HUMAN RESOURCE MANAGEMENT – Development of the project team, reporting structure, resource capacity
COMMUNICATIONS MANAGEMENT – How project communications will be handled to ensure all project stakeholders are informed
RISK MANAGEMENT – Risk Management plan to have all project stakeholders in agreement on how project risks will be handled (aversion, mitigation or assumption)
PROCUREMENT MANAGEMENT – Procurement process, contract processes
INTEGRATION MANAGEMENT – Integration of all areas of project management to develop a cohesive project plan
Issues not easily resolved are escalated for resolution.
Issues are typically identified throughout the project and logged and tracked through resolution.
In this section of the plan the following processes are depicted:
Where issues will be maintained and tracked
The process for updating issues regularly
The escalation process
The vehicle by which team members can access documented issues
Issue… already impacting the cost, time or quality
Risk… POTENTIAL negative impact to project
Resource Planning - Full Time Employees, Professional Services, Cost, and Contingency
Resource Planning - The physical resources required (people, equipment, materials) and what quantities are necessary for the project
Budget
Budget estimates
Baseline estimates
Project Actuals
What is Quality - conformance to requirements’ - Crosby
‘fitness for use’ - Juran
‘the totality of characteristics of an entity that bear on its ability to satisfy stated and implied need’ - ISO 8402:1994
Customer-Based -> Fitness for use, meeting customer expectations.
Manufacturing-Based -> Conforming to design, specifications, or requirements. Having no defects.
Product-Based -> The product has something that other similar products do not that adds value.
Value-Based -> The product is the best combination of price and features. 5. Transcendent It is not clear what it is, but it is something good...
via:
Quality Planning, Quality Assurance, and Quality Control
Clearly Defined Quality Performance Standards
How those Quality and Performance Standards are measured and satisfied
How Testing and Quality Assurance Processes will ensure standards are satisfied
Continuous ongoing quality control
Communications planning: Determining the needs (who needs what information, when they need it, and how it will be delivered)
Information Distribution: Defining who and how information will flow to the project stakeholders and the frequency
Performance Reporting: Providing project performance updates via status reporting.
Communications planning
Information Distribution
Performance Reporting
Define the schedule for the Project Meetings (Team, OSC, ESC), Status Meetings and Issues Meetings to be implemented
Formal change control is required for all of the following
Scope Change
Schedule changes
Technical Specification Changes
Training Changes
All changes require collaboration and buy in via the project sponsor’s signature prior to implementation of the changes