Plunger Lift “Test” (August 2020)

  1. If a plunger rise velocity is too fast, which would you do first?
    • Add more afterflow
    • Reduce close time
    • Add close time
  1. Plunger fall time:
    • Should always be based only on well depth and data sheet plunger fall velocity value
    • Is not very important in optimizing production
    • Is best determined for each well by tracking the plunger with Echometer
  1. When the well is closed, how would you determine the pressure created by the volume of liquid in the tubing?
    • TP-LP
    • CP-LP
    • CP-TP
  1. Which pressure pushes a plunger to the surface?
    • Low Pressure
    • CP
    • TP
  1. Which motor valve trim type is best for plunger lift?
    • Snap
    • Equal Percentage
    • Nominal
  1. What is the purpose of afterflow?
    • Maximize gas sales
    • Control plunger fall velocity
    • Bring the same volume of liquid into the tubing
  1. When is a single outlet lubricator OK for plunger lift?
    • When afterflow is long
    • When using a continuous flow plunger
    • When afterflow is zero
  1. Which of the below affect how fast a plunger falls?
    • Plunger type
    • Tubing pressure
    • Plunger depth in the tubing
  1. List the 4 stages of conventional plunger lift:

 

  1. When would you select 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
  1. Should flowing bottom hole pressure be high or low to maximize production?
    • High
    • Low
  1. 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 pressure
  1. Which opening trigger does not compensate for cycle to cycle well variations?
    • Time
    • Pressure
    • Flow Rate
  1. When should a 2 3/8” plunger be replaced?
    • When the plunger OD is less than 1.88
    • Before production is lost due to a worn plunger
    • When the plunger OD is less than 1.87
  1. What’s the best plunger rise velocity?
    • 500 to 1000 fpm
    • The one that maximizes production without damaging equipment
    • Depends on the plunger
  1. When should a strong horizontal plunger lift well be closed?
    • As soon as the plunger arrives
    • After the liquid slug following the plunger to the surface clears the wellhead
    • When flow rate nears critical
  1. What causes a plunger to change speed as it falls in the tubing?
    • Hole in tubing
    • Higher pressure
    • Liquid column
  1. Which items should be included in a preventative maintenance plan?
    • Plunger, lubricator, pressure transducers, bottom hole spring
    • Those that have or can cause lost production time
    • Plunger, arrival sensor, dump valves, lubricator, bottom hole spring
  1. Which is the “best” opening trigger?
    • CP-LP
    • The one that keeps production on the natural decline curve
    • Time
  1. If CP and TP equalize while the well is closed, what might that indicate?
    • Liquid is coming into the tubing
    • Liquid is being pushed out of the tubing
    • Hole in the tubing
  1. If TP is higher than LP when the well is open and flowing, what might that indicate?
    • A surface restriction
    • Close time is too long
    • Too much liquid
  1. What considerations should go into selecting a plunger?
    • Price
    • Time for well to build to opening pressure
    • Sand in the well
    • Total cost
  1. Which is a reasonable goal for volume of liquid in the tubing for each plunger cycle?
    • 2 bbls
    • 1 ½ bbls
    • ¼ bbl
  1. When should a standing valve be considered?
    • If CP and TP equalize during the close cycle
    • Only if sand is in the well
    • Only when a continuous run plunger is used
  1. How do you know if a plunger lifted well is optimized?
    • No missed plunger arrivals
    • Plunger rise velocity is 750 fpm
    • Production is on the wells natural decline curve, as measured from IP to current