Catalyst Catastrophes in Syngas Production - II
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Transcript of Catalyst Catastrophes in Syngas Production - II
Gerard B. Hawkins, Managing Director
This follows our earlier Catalyst Catastrophes in Syngas Production - I that concentrated on major plant disasters
This paper covers more frequent but still costly incidents related to catalysts with the focus of pulling together recommendations to avoid repetition of the same losses
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Review of incidents by reactor ◦ Primary reforming ◦ Secondary reforming ◦ HTS ◦ LTS ◦ Methanator
Reactor loading Support media Some general comments on alternative actions
when a plant gets into abnormal operation
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Most common incidents: ◦ Poor furnace balancing from catalyst loading
◦ Reformer damage caused by burners lighting
procedure on start-up ◦ Carbon deposition
◦ Steam condensation/rapid drying
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UNIDENSETM is now established as key to an even reformer loading
However UNIDENSE requires some care to achieve its full potential
A reformer in South America was loaded by an inexperienced team and ……….
Lesson – check experience of UNIDENSE loading supervisors
UNIDENSE is a trademark of Yara International ASA
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Lighting burners during start-up is a critical activity
The clear requirement is to increase the number of lit burners as the plant rate is increased ◦ and ensure the pattern of burners always gives an
even heat input Obvious – but was one component leading to
this:
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Lesson – light only the number of burners you need at each stage of start-up and keep the pattern/heat generation even
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Carbon deposition will occur when excess hydrocarbons are introduced
There are several ways to do this: ◦ Inadequate purging during a plant trip can lead to feed
being stored in the desulfurization vessel/ pipe work Then introducing nitrogen purge pushes this
hydrocarbon into the reformer ◦ Naphtha fed plants have a high risk of feed
condensing and sitting in dead legs until some motive force pushes this into the furnace ◦ Erroneous feed flow measurement – more critical in
low steam ratio plants
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Introduction of nitrogen during a start-up increased the reformer pressure drop from 1.4 to 7 bar in 2 minutes
The nitrogen feed line was 100mm diameter and around 1km long, capable of holding up to 10te of naphtha
A spectacle plate was not swung during earlier operation
On previous occasions a drain valve was opened on the nitrogen compressor – this time the valve was not operable
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Situation After Plant Trip
Steam to Reformer
Flow Feed CV
Feed ESDV
Steam to Preheat Coil
FM
Final ZnO Bed
Feed
To Collector or Flare
PCV
S Pt
Trapped Feed After Plant Trip
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A couple of ammonia plants in South America had problems before the natural gas condensate removal plant was installed
These plants took their feed off the bottom of the supply line and hence took any liquids that were present
The liquid did not register in the flowmeters which were orifice plate type – thereby reducing the actual steam to feed ratio
Non-alkalized catalysts lasted as little as 6 weeks
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Lessons ◦ Gas flowmeters largely ignore the presence of
condensed higher hydrocarbons ◦ Note also that during startup flowmeters may read in
error if not compensated for temperature and pressure ◦ Commercial alkalized reforming catalysts give very
significant additional margin against carbon formation in primary reformers
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A plant in North America was the sole user of gas that came down a branch that went under a river
During a start-up after an extended shutdown - when lighting burners – liquid was seen flowing from a few burners onto tubes
While the operator exited and radioed the control room to shut off the fuel - a tube burst leading to significant damage to the furnace/tubes
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It was thought that hydrocarbons had condensed in the cooler section of pipe under the river
Lessons: ◦ Consider potential for condensation of higher
hydrocarbons, especially If lines are cooled below normal If levels of higher hydrocarbons increase
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We have another example of catalyst breakage from condensation on start-up
A naphtha fed plant was not able to provide nitrogen purge for the initial phase of start-up and so heated the reformer using steam
Around 20 start-ups from cold eventually led to breakage of catalyst, poor flow distribution, hot spots and required catalyst change
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Lesson: ◦ Reforming catalyst should be warmed up to 50°C
above the dew point before introduction of steam
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All incidents on secondary reformers are related to the burners
The problem of increasing plant rate to the point that there is inadequate mixing zone is well understood but requires detailed CFD modelling to predict
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Cost of Problems:
7-10 day turnaround
Short Catalyst life $65K/yr less than 10yr
Mechanical repairs
Estimated $65K/year
Poor mixing Burner failure
Bed damage Refractory damage
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Small flame cores from all nozzles
No flame attachment to rings
Good mixing of the process gas and air
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The main problem with HTS reactors is upstream boiler leaks
We have another case where dehydration of the catalyst has lead to an exotherm on startup
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This is a potential problem on ammonia plants with high pressure boilers upstream of the HTS
Boiler leaks put stress onto the HTS catalyst by: ◦ rapid wetting/drying and ◦ pressure-drop build-up from accumulated boiler solids
These leaks are inevitable with steam pressures of 100bar ◦ A serious leak will occur approximately every 12 years
Selecting a catalyst with high in-service strength significantly improves probability of survival
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A plant in Europe suffered a complete tube failure that tripped the plant ◦ Catalyst was unaffected by this incident:
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Dec-02Jan-03
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A plant in Europe had kept a charge of HTS catalyst in a spare reactor for 1 year – but had left this reactor open to the air – so the catalyst had adsorbed water
The start-up required nitrogen heating for 2 days to dry the whole bed – and in doing so dehydrated the catalyst in the top/bulk of the bed
100% steam was switched into the reactor against our advice of 5%
An exotherm started and then (unrelated) the plant tripped (site power trip) which held the reactor with 100% steam
The exotherm reached 530°C, and look several hours to cool down with N2
The final activity when on-line looked good, with expected low pressure-drop.
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Do not leave catalysts exposed to damp atmospheres
VULCAN HTS catalyst give the best survival of boiler leak and over-reduction incidents
Incorporate the GBH Enterprises procedures when over-reduction is suspected
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A plant in North America had to top skim its LTS bed due to high pressure drop
The main cause was poor atomization of quench water
This was not helped by the (non VULCAN) catalyst installed which developed very poor strength when wetted
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Lessons: ◦ Ensure quench water nozzles are on the shutdown
inspection list ◦ Check for adequate pipe length for vaporization
◦ Use catalyst with good strength after wetting
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The main hazards when methanation reactors are shutdown are nickel carbonyl (see earlier presentation) and self heating when exposed to air
An example of self heating comes from a methanator on an olefine cracker
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The plant was shut down and purged with nitrogen
The inlet and exit valves and thermocouples were removed for repair
Open ends were covered in plastic sheet
Catalyst was in reduced state, with N2 purge
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A reading of 454°C/850°F was seen on re-connection of the thermocouples ◦ The plastic sheeting was not adequate isolation ◦ Air entered the vessel and
A downward purge of nitrogen then gave a reading
of 649°C/1200°F on the bottom thermocouple
Decided to change catalyst as needed 5 yr run
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Reduced methanation catalyst becomes very hot when exposed to air
Secure isolation/inert purge is essential for
maintenance on vessels containing reduced catalyst
With little or no gas flow, thermocouples do
not show the peak temperature
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Don’t spoil a ship for a few cents worth of tar! Below Bed: ◦ Support media does a key job preventing catalyst
pass through the exit collector – and doing this with low pressure-drop
Above Bed: ◦ Support media placed on top of the bed protects
catalysts from high inlet gas velocities - which have the potential to break catalysts through disturbance and milling ◦ High voidage media can also be used to reduce the
effects of boiler solid build-up
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A plant decided to use some old support balls that had been stored outside for some years
This was a LTS duty so either alumina or silica-alumina would be suitable
Shortly after start-up the reactor pressure-drop started to increase
This eventually required a shutdown to address
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Investigation showed failure of the support media
The catalyst had to be replaced Cause is believed to have been rapid drying of
support that had got wet during storage
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Silica-alumina support is cheaper A plant decided to use silica-alumina balls in a
high temperature shift bed It was thought that this would be a low enough
temperature for silica migration not to be an issue
Not true – silica migrated downstream and collected on the tubes of the exchanger before the LTS – which required regular shutdowns to clean
A recent enquiry associated with HDS and HTS catalysts simply specified ‘ceramic balls’
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For the most severe duties, including secondary reformers GBH Enterprises recommends fused alumina lumps
◦ High density ◦ High strength ◦ Inert (high purity alumina) ◦ Difficult to blow around!
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Lessons: ◦ Store support media to the same standard as
catalysts – the cost will be the same if they fail! ◦ Only use high purity alumina support above 300°C in
steam environments ◦ Use VULCAN ‘Shift Shield’ for protection against
accumulation of boiler solids from boiler leaks ◦ Use fused alumina lumps for the ultimate protection
against bed disturbance
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Don’t be tempted to put that last bit in! A methanol plant with a water cooled reactor
experienced an increasing pressure-drop on a new charge of catalyst
Eventually the plant had to be shut down Inspection showed that catalyst had been loaded on
top of the tube-sheet as well as in the tubes Removal of the catalyst on top of the reactor and
150mm down the tubes restored the pressure-drop to normal
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A hydrogen plant in Europe implemented a plant up-rate and as part of this increased the HTS volume (we advised it could be lowered)
In order to maximize the catalyst volume the hold-down system was removed!
Milling then increased the pressure-drop A reactor ‘inlet distributor’ is better described as ‘inlet
gas momentum destruction device’
Lesson – gas distribution/bed protection requires careful design along with the rest of a plant up-rate
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A plant with a HTS reactor with two beds (one vessel) went with a short load and split the short load equally between each of the two beds.
The net effect was a bed L/D of 0.2 – a long way below the minimum recommendation of 1.0
The charge had to be replaced after 2 years One can debate the merits of two beds with L/D
of 0.2 with gas mixing in-between or one bed with an L/D of 0.4
The key is neither – but to load the bed(s) carefully:
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The ideal catalyst loading method is by sock with the minimum or raking
Any raking will introduce density differences that will lead to early discharge of the catalyst due to the uneven flow distribution produced
Lesson: allowing your loading company to rake catalyst is equivalent to throwing catalyst away
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There is no universal advice – but some up-front thinking can lead to faster more confident decisions
A number of incidents have involved
exotherms on catalysts which threatened the integrity of their reactors
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Hydrogen was being removed from a process stream using a copper oxide catalyst
During commissioning a hydrogen stream was mistakenly introduced and the catalyst temperature rose to 1000°C
Technical support staff on site advised immediate depressurization
Vessel damage was avoided There were problems later on downstream mol
sieve driers from water produced which accumulated in a dead leg
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With the previous example in mind it is worth reflecting on the merits of depressurization and purging
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Several advantages: ◦ It decreases the partial pressure of reactants which
may help slow the temperature rise ◦ It reduces the stress on equipment enabling the
handling of higher temperatures ◦ No motive force is required – so it is reliable ◦ Lowering the pressure makes purging more effective
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Risks ◦ Depressurization can generate high gas velocities –
enough to fluidize catalyst beds ◦ Fluidized catalyst beds can lose their top protective
layer (into the bed) and suffer: flow distribution problems or pressure drop increase if loss of the top layer allows
milling
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Advantages ◦ Can maintain plant pressure (but is better if pressure
reduced) ◦ Fluidization risks to catalyst beds much lower
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Disadvantages ◦ Difficult to achieve high flow-rates – steam is often
the purge gas with highest availability ◦ Steam can deactivate catalysts through oxidation
and in some cases sintering ◦ Nitrogen is a good inert material – but often the
available flow is limited ◦ Need to consider trace oxygen in nitrogen Ideal is nitrogen with enough hydrogen to ensure
reducing conditions
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A broad conclusion from the first set of catalyst catastrophes was the value of having a system to force a ‘stop and think’ when the plant gets away from familiar operating regime
The incidents here suggest: ◦ Selecting the right catalyst has a significant impact
on the ability of a plant to continue operation through an unplanned event ◦ Operator training/procedures are key to avoiding
incidents
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