Plunger Lift Test (August 2022)

  1. To maximize production, flowing bottom-hole pressure should be as high as possible.
    • True
    • False
  2. Plunger lift wells with long close and long open times are probably optimized.
    • True
    • False
  3. If a plunger rise velocity is too fast, which would you do first?
    • Add more afterflow
    • Reduce close time
    • Add close time
  4. When the well is closed, how would you determine the pressure created by the volume of liquid in the tubing?
    • Tubing pressure minus line pressure
    • Casing pressure minus line pressure
    • Casing pressure minus tubing pressure
  5. Plunger fall time:
    • Should always be based on the plunger fall velocity listed on the manufacturers data sheet
    • Is not really important as long as the plunger is on the bottom before the well opens
    • Is best determined by tracking the plunger with Echometer
  6. Which pressure lifts a plunger to the surface?
    • Low Pressure
    • Casing pressure
    • Tubing pressure
  7. Which motor valve trim type is best for plunger lift?
    • Snap
    • Equal Percentage
    • Nominal
  8. What is the purpose of afterflow?
    • Maximize gas sales
    • Control plunger fall velocity
    • Bring the same volume of liquid into the tubing
  9. When is a single outlet lubricator acceptable for plunger lift?
    • When afterflow is long
    • When using a continuous flow plunger
    • When afterflow is zero
  10. Which of the below affect how fast a plunger falls?
    • Plunger type
    • Tubing pressure
    • Plunger depth in the tubing
  11. List the 4 stages of conventional plunger lift.
  12. When would you consider using a continuous run plunger?
    • Flow rate is less than 500 mcf/d
    • Casing pressure is greater than 200 psi
    • CP is great enough to surface the plunger without closing the well
  13. Flowing bottom-hole pressure is affected by which of the following?
    • Volume of liquid in the tubing
    • Number of 90 degree elbows at the surface
    • Trim size in the motor valve
  14. Which wells would benefit from Gas Assisted Plunger Lift?
    • When close times are long
    • When line pressure is low
    • When there’s too much liquid in the well for the available reservoir
  15. Which open condition (trigger) does not compensate for natural well variations from cycle to cycle?
    • Time
    • Pressure
    • Flow Rate
  16. When should a 2 3/8” plunger be replaced?
    • When the plunger OD is less than 1.88
    • Before the worm plunger affects production
    • Every 90 days
  17. What’s the best plunger rise velocity?
    • 750 feet per minute
    • Depends on the plunger
    • The one that maximizes production without damaging equipment
  18. What causes a plunger to change speed as it falls in the tubing?
    • Hole in tubing
    • Higher pressure
    • Liquid column
  19. When should a strong horizontal plunger lift well be closed?
    • After the liquid slugs following the plunger to the surface clears the wellhead
    • As soon as the plunger arrives
    • As soon as flow rate nears critical
  20. Which items should be included in a preventative maintenance plan?
    • Plunger, lubricator, pressure transducers, bottom hole spring
    • Those that cause unplanned down time
    • Only those that are easy to check
  21. Which is the “best” open condition (trigger)?
    • The one that keeps production on the natural decline curve
    • Tubing pressure
    • Casing pressure
  22. If casing and tubing pressure equalize near the end of the close stage, what might that indicate?
    • Liquid is coming into the tubing
    • Liquid is being pushed out of the tubing
    • Hole in the tubing
  23. If tubing pressure is higher than line pressure when the well is open and flowing, what might that indicate?
    • A surface restriction
    • Close time is too long
    • Too much liquid
  24. What considerations should go into selecting a plunger?
    • Price
    • Sand or H2S in the well
    • Time for the well to build to its required opening pressure
  25. What is a reasonable goal for volume of liquid in the tubing for each plunger cycle?
    • 2 bbls
    • 1 ½ bbls
    • ¼ bbl
  26. When should a standing valve be considered?
    • If casing and tubing pressure equalize during the close cycle
    • Only if sand is in the well
    • Only when a continuous run plunger is used
  27. The ball valve on the lower outlet of the lubricator should always be partially closed.
    • True
    • False
  28. Which continous run plunger is best with sand?
    • Dart style plunger
    • Dual row pad plunger
    • Ported ball and sleeve plunger
  29. How much liquid has a well with a ball and sleeve plunger produced?
    • Less than 100 barrels per day
    • Less than 200 barrels per day
    • Over 400 barrels per day
  30. What is critical flow rate?
    • The flow rate for a well to be profitable
    • The flow rate required to lift all the liquid in the well to the surface
    • The flow rate as measured at the meter run
  31. The critical flow rate in the lateral leg of a horizontal well is not important for plunger lifted wells.
    • True
    • False
  32. How long should the sleeve be held in the lubricator for a ball and sleeve plunger?
    • 30 seconds
    • About 5 minutes
    • Untill the ball reaches the bottom-hole spring
    • None of the above
  33. The process used to optimize production should be left up to each plunger lift well operator.
    • True
    • False
  34. The screen layout and content for SCADA systems doesn’t affect production or productivity very much.
    • True
    • False
  35. How do you know if a well is optimized?