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Console General Information > Feed Streams Information > Flashcards

Feed Streams Information Flashcards

1
Q

What are the feed streams for the 634 unit?

A
  • 533 Crude Unit Resid (Currently not in use)
  • 536 Crude Unit Heavy Vacuum Gas Oil (HVGO)
  • 536 Crude Unit Light Vacuum Gas Oil (LVGO)
  • 537 Crude Unit HVGO
  • 537 Crude Unit LVGO
  • 537 Crude MVGO
  • 736 Coker Heavy Gas Oil (CHGO) (not normal)
  • 737 Coker Heavy Gas Oil (CHGO) (not normal)
    The 736 and 737 CHGO are cold feed streams from the Coker processes and are not normal feed streams.
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2
Q

What are the feed streams for the 636 unit?

A
  • 736 Coker heavy gas oil (CHGO)
  • 737 Coker heavy gas oil (CHGO)
  • 537 Crude Unit atmospheric gas oil (AGO)
  • 536 Crude Unit heavy vacuum gas oil (HVGO)
  • 537 Crude Unit heavy vacuum gas oil (HVGO)
  • 537 Crude Unit medium vacuum gas oil (MVGO)
  • FCCU light cycle oil (LCO) (not a normal feed)
  • Cold feed from Oil Movements (OM)
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3
Q

What are the feed streams for the 633 unit?

A
  • Off-Test Re-Run Diesel (633 Feed Page - Tk 609 ; Mislabeled 619)
  • Off- Test Diesel (633 Feed Page - Tk 100
  • 732 FCCU Light cycle oil (LCO)
  • 736/737 Coker light gas oil (CLGO)
  • 536 Crude AGO
  • 537 Crude LVGO
  • 636 HDS Low Sulfur Diesel
    ha (636 Fractionator)
  • 633 LCGO-Coker Feed (633 Feed)
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4
Q

What are the feed streams for the 635 unit?

A
  • 536 Crude Unit Diesel
  • 537 Crude Unit Diesel
  • 537 Crude Unit LVGO
  • 636 HDS Unit Diesel (only when 633 HDS Unit is down)
  • 736 Coker Unit LGO
  • 737 Coker Unit LGO
  • FCCU LCO (not a normal feed stream but can be run)
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5
Q

What are the effects on each unit of adding cold feed? Reducing cold feed? What points would you want to see the impacts on each unit?

A

Adjustments will affect unit total feed rates, drop feed temperatures and increase feed filter fouling.
Consequences of Deviating High
The potential effect if this variable is not controlled is a decrease in feed temperature which will require increased Reactor Feed Heater firing.
Consequences of Deviating Low
The potential effect if this variable is not controlled is decreased Feed Surge Drum level and possibly decreased feed rate.

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6
Q

What are the effects of increasing and decreasing the heater outlet temperature?

A

Consequences of Deviating High
The potential effect if this variable is not controlled is furnace over-firing leading to flame impingement. Flame impingement may lead to heater tube failure resulting in danger to personnel and an environmental release. Also, a high outlet temperature could cause excessive Reactor temperatures and possible coking and catalyst damage.
Consequences of Deviating Low
The potential effect if this variable is not controlled is low reaction temperatures, resulting in off spec product due to high sulfur content.

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7
Q

What are the ways to change the heater outlet temperature on each unit?

A

Increasing/Decreasing Fuel Gas Pressure or Adding/Removing Burner from service

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8
Q

How do you confirm your Heater O2 analyzer? How do you know if your combustibles analyzer is reading correctly?

A

Discuss with Michelle. Could not find clear-cut answer in manuals. Advised that I could potentially, reduce feed pre-heat, which would cause the heater to fire harder to maintain heater outlet set point. This harder firing of heater would reduce combustibles and confirm analyzer accuracy.

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9
Q

How do feed preheats affect the heater on each unit?

A

Preheats increases temperature of feed to be heated prior to entering heater, assisting the heater in acquiring the set heater outlet temperature set point (using less fuel gas)

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10
Q
  1. What is the WABT? What is the normal temperature range for the WABT on each unit? How does the WABT temperature range change with the age of the Catalyst? How do reactor quenches affect the WABT?
A

WABT - (Weighted Average Bed Temperature)

-633 = 640 - 735 degrees
-634 = 600 - 700 degrees
-635 = 650 - 700 degrees
-636 = 680 - 690 degrees

As the catalyst ages a higher WABT is needed to produce the same chemical reaction as newer catalysts.

Quenches help to control the temperature profiles between the reactor beds

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11
Q

How does the WABT affect product specifications?

A

Operation of this process is important to the refinery overall because it reduces the sulfur in the diesel stream to meet product specifications for ultra low sulfur diesel and low sulfur diesel blending.

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12
Q

Name the stripping mediums and where they are used on each unit. How do they affect the product specification? What happens when you loose your stripping medium in each unit?

A

633 = Combined Hydrogen (used in Stripper)
634 = 125 Steam (used in Stripper)
635 = hydrogen, NG & N2 (used in Stripper)
636 = 125 Steam (used in Stripper)
636 = 125 Steam (used in Fractionator)
636 = Rising Hot Vapor from Diesel Stripper Reboiler (used in Diesel Stripper)

Loss of Stripping Medium will cause the production of off test products (higher sulfur & h2s in product)

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13
Q

Condensate: How do you know you have enough? What do you look for when doing a condensate swap? Why do we perform condensate swaps?

A

Observation of the BPH or GPM flow on the HDS schematic confirms enough condensate flow. Observing Ammonium bisulfide calculations vs target. Remove build-up in exchanger tubes during condensate swap.

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14
Q

How do you know the proper overhead temperature and tower pressure and how do you maintain them on each unit?

A

633, 635 & 636 all have temperature and pressure control regulators. Set Points can be found on the schematics. (634 does not)

633,635 & 636 can control Fractionator (633 & 636) or Stripper (635)overhead temperatures, by increasing/decreasing overhead fans in service, or by increasing/decreasing reflux to top of tower
(634 has no controls)

633,635 & 636 can control overhead pressures by manipulating setpoint on pressure control regulators coming off of overhead accumulators.

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15
Q

How do you increase or decrease overhead make? In what circumstances would you increase or reduce overhead product make on each unit?

A

Overhead make can be adjusted by increasing/decreasing the temperature of the tower, or by increasing/decreasing the pressure on the vessel.

Increasing make i beneficial when attempting the remove high H2S/Sulfur from bottoms product

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16
Q

How do you know when to load and unload a compressor on each unit?

A

Need Research

17
Q

What compressors can you change RPMs? When do you increase or decrease a compressor’s RPM’s?

A

Need Research

18
Q

How does high-purity hydrogen affect a compressor?

A

High purity hydrogen can dilute hydrogen density. If the density becomes too diluted the compressor won’t be able to effectively compressor gas

19
Q

What is the purpose of a compressor spillback? What happens if it opens? What happens if it closes? When do you need to make adjustments on each unit?

A

-Compressor spillbacks regulate the amount of forward gas flow vs the amount of gas flow recycled to the front of the compressor stage.

-When the spillback is opened gas recycles to the suction of the compressor stage

-If the spillback closes all compressed gas flows forward

-To control unit pressure, To control compressor temperatures

20
Q

What is the purpose of the back pressure regulator, and how do you control the pressure? What do you do if the pressure is too high? what do you do if the pressure is too low?

A

-Back pressure regulator helps to regulate pressure on line that purges gas off the unit.

-To increase purge line pressure, the back pressure regulator would open to release higher pressured compressed gas to purge line.

-To decrease purge line pressure, the back pressure regulator would close to restrict the flow of higher pressured compressed gas to purge line.

21
Q

Beyond the EOP, what would you expect to see if you lost a compressor? How would that affect the unit? How would that affect the other units? how would that affect the plant line? What moves would you have to make?

A

-Loss of H2 flow to the unit
-Decrease of unit pressure
-Loss of compressor could impact other units that are dependent on the H2 purge from the unit
-Plant line could see an increase in pressure due to a unit’s compressor failure and sudden stop from drawing h2 from the header.
-Hold unit pressure until compressor can be restarted.

22
Q

Where does hydrogen purge out of the Hydrogen header? When does hydrogen purge from the plant line?

A
  • Hydrogen purges to the fuel gas mixing pot
  • When there is an excess /high pressure on the plant header
23
Q

Who are the three main suppliers of hydrogen?

A

Air Products, Praxair & Equistar Channelview

24
Q

How do you know which supplier is in pressure control and which are in flow

A
25
Q
A

Console General Information (3 decks)

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