1. Plunger Lift Reference Guide
Base Mgmt
By Pass Non-Conventional
High Speed Non-Conventional
By Pass
Hollow center
By Pass with Pad
Ports
Pacemaker
Name: Ring Frictionless By Pass
Manufacturer: PCS
Name: Center By Pass
Manufacturer: PCS
Example Wells:
Fazekas 2-17
Circle F 2-25
Example Wells:
None
Name: Rapid Drop
Manufacturer: IPS
Name: Padded Sleeve By-Pass
Manufacturer: PCS
Example Wells:
None
Name: Stingray
Manufacturer: Well Master
Name: Pacemaker
Manufacturer: IPS
Operation
The two pieces of the plunger begin the cycle on the down hole assembly with plunger and ball traveling together as one unit as shown in Fig. 1. The differential pressure below the unit holds the two pieces together as the well begins to flow. Then as one unit, the plunger lifts accumulated fluid to the surface. In the lubricator at the surface, a shifting rod awaits the arrival of the plunger (Fig 2). The shifting rod separates the ball and sleeve, as in figure 3. The ball begins to fall back to the bottom-hole assembly, while the sleeve is held in place by the shifting rod. The auto-adjust controller determines when the motor valves close the well control valves to shut in the well and allow the plunger to fall through the wellhead. The well remains shut in for a short period for the plunger to pass through the wellhead and then resumes production while the plunger body falls back to the bottom.
Example Wells:
Dungeon 2-13
Fazekas 6-17
Yourman 6-15
Lubricator: Quick Drop
Fall Time: ft/m
Example Wells:
None
Example Wells:
None
Lubricator: Quick Drop
Fall Time: ft/m
Shifting Rod
Lubricator: Pacemaker
Fall Time: ft/m
Lubricator: Pacemaker
Fall Time: ft/m
Plunger
Flow Through Ports
Lubricator: Quick Drop
Fall Time: ft/m
Lubricator: Quick Drop
Fall Time: ft/m
Adjustments to control the by pass area
Ball
Ports
Operation
Drop Phase: The plunger has a sliding sleeve that while in the open position allows gas and liquid to flow through an inner mandrel and exit the flow port at the top of the mandrel.
Bottom Phase: The plunger falls to bottom and the sliding sleeve falls to the closed position preventing gas and liquid from flowing through the plunger.
Lifting Phase: After the sleeve closes and flow no longer travels through the plunger, the plunger will travel to the surface, lifting all liquids above it.
Top Phase: Once the fluid and plunger have arrived at the surface, the sleeve will be shifted to the open position to allow the plunger to fall for another cycle.
Ports
Well Velocity Below 15 Ft/s
Pads
Standing Valve and Spring Assembly
Well Velocity Below 10ft/s
Pads
Operation
Drop Phase: The plunger falls and allows fluid and gas to flow between the outer body and internal rod. Some of the exit ports can be closed to restrict the flow through the plunger to help achieve the most efficient cycle time.
Bottom Phase: The plunger falls to bottom and the rod shifts to the closed position preventing gas or liquid from flowing through the plunger.
Lifting Phase: After the plunger closes and flow no longer moves through it, the plunger will travel to the surface, lifting all fluid above it.
Top Phase: Once the fluid and plunger have arrived at the surface, the internal rod will shift to the open position to allow the plunger to fall for another cycle.
Operation
Drop Phase: The traveling dart is in the open position below the flow ports allowing high rates of gas and liquid to flow through the plunger.
Bottom Phase: The plunger falls to bottom and the traveling dart shifts to the closed position preventing flow through the plunger.
Lifting Phase: After the dart moves to the closed position and flow no longer goes through it, the plunger will travel to the surface, lifting all liquids above it.
Top Phase: Once the fluid and plunger have arrived at the surface, a rod in the lubricator will shift the dart off seat and allow the plunger to fall for another cycle.
Adjustment to Control By Pass Area
Ports
Ports
Shifting Rod
Pads
Shifting Rod
Shifting Rod
Shifting Rod/Dart
Operation
The By-Pass plungers with pads allow for the seal of a pad plunger for better fluid recovery, while offering flow through the plunger. The trip rods that open the plunger and allow flow can be located in the lubricator or on the plunger.
Conventional
Multi-Stage
Iron Soap
Viper
Testing
Liquid Unloading
Sand/Solids
Sand
Brush
Test
Name: Spiral Sand Plunger
Manufacturer: PCS
Name: Viper
Manufacturer: Well Master
Name: Smart Plunger
Manufacturer: PCS
Name: Brush
Manufacturer: PCS
Example Wells:
Smith 7-20
State c2-28
Dunagan 1-13
Hampton 2-18
Yourman 7-15
Foster 1
Small Orifices Where Gas Exits
Name: Liquid Aeration Plunger
Manufacturer: PCS
Traveling
Name: Multi Stage Tool
Manufacturer: PCS
Example Wells:
Varnum, Guy 4-25
Example Wells:
Sunflower 3
Anderson 3
Orr 7
Example Wells:
Myton 18
Foster 1-7
Martin C 7
Stationary 1
Lubricator: Conventional
Fall Time: ft/m
Drop Off 2
Gas Exit Jets
Example Wells:
Topping State 1-9
Example Wells:
Paschall 4-21
State c3-28
Hampton 2-18
Coblentz b3-1
Gas Exit Jets
Retrieval
Lubricator: Conventional
Fall Time: ft/m
Lubricator: Conventional
Fall Time: ft/m 3
Lubricator: Conventional
Fall Time: ft/m
Operation
The Viper plunger is a useful deliquification plunger in wells producing formation or frac sand. This conventional plunger is a solid plunger with a hollow core. The hollow core is connected to radial holes on the exterior that direct turbulent gas to the tubing wall pressure washing the wall on the upstroke. The radial grooves in the bottom create spinning action on the upstroke and down stroke.
Operation
The brush plunger is a solid mandrel wound with flexible brush fibers. Most of the time these plungers are constructed with undercuts ensuring descalling of the tubing.
Operation
The sand plunger operates similar to the Wellmaster Viper. The sand plunger from PCS offers grooves at the bottom of the plunger that creates a spinning turbulent seal. Also, the sand plunger allows gas to flow into the plunger and clean out grooves to prevent sand from sticking the plunger.
Lubricator: Conventional
Fall Time: ft/m 4
Operation
The plungers come with a stationary plunger, retrieval plunger, traveling plunger, and drop off plunger. The traveling device is able to collect data in a shut-in or flowing well and is cycled just as any other plunger and caught in the lubricator. The Drop Off plunger attaches to the fishneck of the stationary plunger and is dropped in the well. When the two plungers reach the bottom the thermocouple activates at a predetermined temperature and the plungers separate. The Drop off plunger is cycled to the surface. When the stationary plunger is ready to come out, the retrieval plunger is dropped in the well, and an overshot grabs the stationary plunger and the two are cycle to the surface.
Operation
The multi stage plunger creates bottom hole pressure by staging the well. The multi stage tool is usually landed between 40-70% of the way down the well. The bottom stage is a traditional plunger setup with a downhole spring, stop, and conventional plunger. When the well is open the bottom stage moves fluid up the hole and the gas bubble above it provides energy to the second stage. The top plunger lifts the column of fluid to the surface as the bottom plunger arrives at the multi stage assembly with a load for the next trip. When the well shuts, the top and bottom plungers fall simultaneously.
Gas Enters
Operation
The liquid aeration plunger removes the liquid load more efficiently and at higher velocities by jetting gas through orifices in the top of the plunger. The gas jetted through the plunger, as it travels upward, aerates the liquid above the plunger. 5
Ring
Paraffin
Low Pressure and/or Marginal Well
Deviated Wells
Snake
Solid
Pad
Name: Triple Pad
Manufacturer: PCS
Name: Shuttle Plunger
Manufacturer: Go Tek
Name: Single Pad
Manufacturer: IPS
Name: Two-Pad
Manufacturer: PCS
Name: Wobble Washer
Manufacturer: PCS
Name: Snake
Manufacturer: PCS
Name: Standard Solid Plunger
Manufacturer: PCS
Example Wells:
Orr 2
Lubricator: Conventional
Fall Time: ft/m
Example Wells:
None
Example Wells:
James 4-24
Mcalester 6-22
State c1-28
Hampton 3-18
Kinnkin Pate 1-3
Example Wells:
Nan 1-15
Simon 3-27
Example Wells:
Austin 5-13
Heitner 4-13
Picaro 2-36
Example Wells:
Quinton 3-20
Example Wells:
None
Lubricator: Conventional
Fall Time: ft/m
1 Ball and Seat (Flow Cage) – maintains the one way flow of liquids up the tubing and keeps liquids from the bottom stage until the top plunger can retrieve it.
2 Seal Element (Pack Off) – Seals as fluids are delivered keeping fluid above the flow cage.
3 Resettable locking mechanism – Holds the tool in open position for an easy installation and then sets to the closed position when depth is reached.
4 Collar stop
5 Bumper Spring – absorbs the impact of the arriving plunger.
Lubricator: Conventional
Fall Time: ft/m
Lubricator: Conventional
Fall Time: ft/m
Lubricator: Conventional
Fall Time: ft/m
Operation
The Ring plunger is similar to the triple pad plungers. Shifting rings keep continuous contact against the tubing walls producing a highly effective seal as well as wiping the tubing before the paraffin can harden. The seal is affected due to the movement of gas by the specially shaped washer held against the tubing wall with eccentric springs.
Lubricator: Conventional
Fall Time: ft/m
Lubricator: Conventional
Fall Time: ft/m
Operation
The snake plunger operates as a normal conventional plunger. It offers a flexible core that allows for bending and movement through tubing irregularities.
Operation
The solid plungers are heavy and able to cut through paraffin with faster fall velocities. The plunger has no moving parts and is durable.
Operation
The Shuttle Plunger contains a temperature gauge, pressure gauge, and collar locator. Unlike the Smart plunger which is available in many different styles, the shuttle plunger is a traveling plunger and only available in a solid plunger style. The Shuttle plunger can be downloaded via usb to a laptop in the field for evaluation.
Operation
The Pad plunger works as a typical conventional plunger and is available in 1, 2, and 3 pad models. The spring loaded pads press against the tubing wall in order to create a highly efficient seal bringing more fluid to the surface and avoiding liquid flowback.
Cody Hopkins | Summer Intern 2010 | Arkoma Asset | Base Mgmt

2. Plunger Lift Reference Guide
Base Mgmt
Life Cycle of the Well
Stage 1:
Well is flowing above critical rate with all flow in mist flow, no liquid gradient at anytime.
No deliquification Required
Stage 2:
Well begins to bubble and slug when rates fall below critical.
If velocity > 15ft/s the well is a candidate for a high speed non-conventional plunger such (i.e. pacemaker).
The wells normally still have high Gas to Liquid Ratios, meaning that they do not require and shut in time. The high GLR also allows for flow of gas to sales after the arrival of the plunger at the lubricator (after-flow).
The after-flow allows the two pieces of the plunger to distance themselves, creating a large by-pass area and reducing shut-in time. The reduced shut-in time, means more trips per-day and more water brought to surface.
Stage 3:
Well begins to have difficulty maintaining seal due to velocity getting below 15ft/s but greater than 10ft/s.
Candidate for by-pass style, non-convention al plunger
These wells may still require a lot of trips to remain unloaded, but need little or no flow time after each trip. Pacemaker wells running with significant off time or wells that have just begun “slug – flow” conditions are indicators of this life cycle stage.
These non-conventional plungers can reach the bottom almost as quick as the pacemaker, but do not require any after- flow since it is one piece.
Stage 4:
Well has velocity < 10ft/s
Candidate for conventional style plunger (i.e. iron soap, pad, viper, etc).
This stage of the life cycle occurs when GLR decrease and pressure build up is required to trip the plunger.
The conventional plunger comes in many different styles in order to adapt to well conditions such as: sand, fluid load, tubing irregularities, or scale.
Stage 5:
Well has such low bottom-hole pressure that a conventional plunger doesn’t work.
Candidate for multi stage plunger
This is the final stage in a wells life, when the GLR drops so low that a conventional plunger won’t cycle.
The Multi-Stage plunger stages the well into parts and creates bottom hole pressure by reducing the distance any single plunger has to travel.
Common Plunger Lift Setup
In this range for actual production, the recommendation would be to install a high speed non-conventional plunger (i.e. pacemaker).
In this range, the recommendation would be to run a bypass style non-conventional plunger
At lower flow rates (below 10ft/s), a conventional style of plunger would be recommended
Lubricators
Surface Equipment
Fazekas #5
Lubricator
Controller / Motor Valve
Flow Line to Sales
Master Valve
Cody Hopkins | Summer Intern 2010 | Arkoma Asset | Base Mgmt
Bumper Spring Assembly
The lubricator is installed on top of the tree or master valve to cushions the plunger upon arrival into the wellhead to prevent damage. The spring inside absorbs the impact of the plunger. The catcher holds the plunger in place and allows for safe removal of the plunger or inspection. All lubricators are available with on or two outlets.
PCS Bumper Spring Features:
Standard Fishing Neck
Tapered body
Spring
-Helps prevent down hole damage due to plunger fall
Mandrel
Standing Valve Cage
- ball and seat are used to hold liquid in the tubing
“No-Go”
-prevent fall through seating nipple
Cups
-sits in the seating nipple
8. Locking Mechanism
Orifice
- allows flow through the bumper spring assembly
PCS Conventional Lubricator
IPS Pace Maker Lubricator
Pace Maker Setup
Conventional Setup
Top View
Cap
Bumper plate
Pace Maker text is right side up, indicating it is for use with the pace maker
Bumper plate
Cap
Spring
Spring
Spring
Pace Maker text is upside down
Threaded to Remove Plunger
Threaded to Remove Plunger
Shifting Rod
Outlet
Outlet
Catcher
Ledges to hold the spring or shifting rod in the lubricator.
Outlet
Catcher (once plunger is at the surface, it can be caught by shifting the handle)
Catcher
In this set-up the shifting rod is inserted into the spring. During the operation the spring and rod will be assembled as shown inside the lubricator.
To change from the Pace Maker setup to this conventional setup, the upper portion must be unscrewed and flipped around. The shifting rod also must be pulled out and a second bumper spring ( not pictured) must be placed inside the existing spring.
Standing valves