Sucker Rod Pump Basics. Presentation Contents: Sucker Rod Pumps The Five Basic Components of a...

Sucker Rod Pump Basics

Presentation Contents:

Sucker Rod PumpsThe Five Basic Components of a PumpOperation of a Sucker Rod PumpTypes of Sucker Rod PumpsMaterial Selection of Pump Components

Observations at the Bleeder Valve

Handling a Sucker Rod Pump

The Five Basic Componentsof a Sucker Rod Pump:

Barrel Tube Plunger Traveling Valve Standing Valve Seating Assembly

BasicComponents of the Sucker Rod Pump

PLUNGER

TRAVELING VALVE

BARREL TUBE

STANDING VALVE

HOLD DOWN


Barrel Tubes

Thin WallRW & RS

Barrel

Heavy WallRH Barrel

Tubing Pump TH Barrel

Tubing Pump TP Barrel


Plungers

Pin EndSpraymetal

Plunger

Box EndSpraymetal

Plunger

Box EndSpraymetal

GroovedPlunger

Monel PinSpraymetal

Plunger

PressureActuatedPlunger


Rings for Soft-Packed Plungers

Composition Ring Split Composition Ring Pressure Actuated Ring

Flexite Ring Valve Cup


Traveling Valves

Closed-Type Cage forPin-End Plunger

Closed-Type Cage forBox-EndPlunger

Closed-TypeCage for

Pin-End Plunger

Insert Style

Open-TypeCage for

Travel Barrel

Pump


Standing Valves

Closed-TypeCage

Insert Style

Closed-Type Cage

Open CageTraveling

Barrel Type

Open CageTubing Pump

Closed CageTubing Pump


Valves for Traveling & Standing

Ball & SeatRib Type

Ball & SeatFlat Type


Seating Assemblies

3 Cup APIBottom

Hold Down

3 Cup APITop

Hold Down

3 Cup Type OBottom

Hold Down

MechanicalBottom Lock

API Type

MechanicalTop LockAPI Type


Seat / Unseat Requirements

TYPE HOLD DOWN

SEAT UNSEAT SEAT UNSEAT SEAT UNSEAT SEAT UNSEAT SEAT UNSEAT

Cup, Type "O"585 380 800 425 850 500 975 650 1100 740

Cup, Type "HR"585 380 800 425 850 500 975 650 1100 740

Mechanical Bottom Lock API Type

455 530 1200 1600 2250 2700

Mechanical Top Lock API Type

825 1900 1750 3850

LBS of Force Required to

TUBING SIZE


1.250" 1.500" 2.375" 2.875" 3.500"




The Basic Operation of a Sucker Rod Pump

A sucker rod pump is no more than a cylinder, or tube, consisting of two sections or chambers. One section is stationary or secured to the tubing. The other section travels with the sucker rod string. There are usually two valves working with these sections taking turns opening and closing. The valves transfer fluid from the bottom chamber to the top chamber and ultimately into the tubing and up to the wellhead.

ArrowsShowFluidTravelon theUpstroke

SUCKER ROD

TUBING

TRAVELING UNIT

STANDING UNIT

ArrowsShowFluid Travelon theDownstroke

SUCKER ROD

TUBING

TRAVELING UNIT

STANDING UNIT

Pressures in the WellboreP1 = Formation Pressure P2 = Inernal Pump Pressure P3 = Hydrostatic Pressure

Tubing

Well Head

Casing 0 0 0

Annulus Check Valve

Rod String

Pull Rod

Plunger

P3 P3

Travel Valve

Barrel

P3

P2 P2 P2

Standing Valve

Strainer Nipple

P1 P1 P1

P2 < P1Standing Valve

Opens

P2 > P3Travel Valve

Opens

P2 < P1Standing Valve

Opens

Upstroke

Fluid Level

Perforations

UPSTROKE Downstroke

API Bottomhole Pump Designation

Heavy Wall Thin Wall Heavy Wall Thin WallBarrel Barrel Barrel Barrel

Rod Pumps: Stationary Barrel, Top Anchor RHA RWA RSA Stationary Barrel, Bottom Anchor RWA RWB RSB Traveling Barrel, Bottom Anchor RHT RWT RSTTubing Pumps TH TP

Tubing Size: 15 - 1.900" OD Extension Length - Bottom - in Feet20 - 2-3/8" OD25 - 2-7/8" OD Extension Length - Top - in Feet30 - 3-1/2" OD40 - 4-1/2" OD Plunger Length in Feet50 - 5-1/2" OD

Barrel Length in FeetPump Bore: 125 - 1-1/4"

150 - 1-1/2" Seating Assembly Type: C - friction cup175 - 1-3/4" M - mechanical178 - 1-25/32"200 - 2" Location of Seating Assembly: A - top225 - 2-1/4" B - bottom250 - 2-1/2" T - bottom, travel barrel275 - 2-3/4"325 - 3-1/4" Barrel Type: H - heavy wall f/metal plunger375 - 3-3/4" W - thin wall f/metal plunger475- 4-3/4" P - heavy wall f/soft pack plunger550 - 5-1/2" S - thin wall f/soft pack plunger575 - 5-3/4"775 - 7-3/4" Pump Type: R - rod

T - tubing

X X - X X X - X X X X - X - X - X - X

Metal Plunger Pumps

Type of Pump

Soft-Packed PlungerPumps

Types of Sucker Rod Pumps

Insert Type Pumps

Installed on the end of a sucker rod string as a complete unit.

Can be ran deeper than Tubing Pump. Special service applications are

available for most types. Less service cost than a tubing pump.


Types of Insert Type Pumps

Bottom Hold Down: RWTC RWBC RHBC

Top Hold Down: RWAC RHAC

RWTC – API Insert Pump

Barrel Travels with Rod String.

Bottom Holddown.

Thin Wall Barrel.

RWTC – API Insert Pump

Advantages of RWTC Pumps:

Recommended for sandy wells.

Recommended for intermittent pumping wells.

Disadvantages of RWTC Pumps:

Not recommended for gassy wells.

Not recommended for wells with low fluid levels.

Not recommended for deep wells.

RWAC – API Insert Pump

Plunger Travels with Rod String.

Top Holddown.

Thin Wall Barrel.

Barrel Extends Below Seating Nipple.

RWAC – API Insert Pump

Advantages of RWAC Pumps: Recommended for sandy wells.

Recommended for low fluid level, gassy, or foamy wells.

Recommended for wells requiring long pumps.

Disadvantages of RWAC Pumps:


Valve rod is the weak link.

Not recommended for intermittent pumping.

Tubing erosion opposite top guide.

RWBC – API Insert Pump


Bottom Holddown.

Thin Wall Barrel.

RWBC – API Insert Pump

Advantages of RWBC Pumps:

Recommended for deep wells.

Recommended for low fluid levels.

Disadvantages of RWBC Pumps:

Not recommended for sandy wells.




Barrel subject to corrosive attack.

RHBC – API Insert Pump


Bottom Holddown.

Heavywall Barrel.

RHBC – API Insert Pump

Advantages of RHBC Pumps:



Recommended for stroke through design to combat scale and/or gyp.




Not recommended for intermittent pumping in sandy wells.



RHAC – API Insert Pump


Top Holddown.

Heavy Wall Barrel

Barrel Extends Below Seating Nipple.

RHAC – API Insert Pump

Advantages of RHAC Pumps: Recommended for sandy wells.

Recommended for low fluid levels, gassy, or foamy wells.

Recommended for stroke through design to combat scale and/or gyp.







Hollow Tube


Bottom Hold Down.

Available in Thin & Heavy Wall.

Available in Bottom & Top Hold Down.

Valve Rod is Replaced with Pull Tube.

Valve can be added on top of tube.

Hollow Tube

Advantages of Hollow Tube Pumps:


Pump discharge is spread across pump stroke (helps reduce tubing erosion).

Two Stage effect with valve on top of tube.

Pull Tube is more rigid than typical valve rod.

Disadvantages of Hollow Tube Pumps:



Sand Pump

Can be built as Stationary or Travel Barrel type pump.

Bottom Hold Down.

Heavy Wall Barrel construction.

Valve Rod is Replaced with Plunger.

Check Valve on top of pump.

Sand Pump

Advantages of San’ Pumps:

Recommended for wells producing sand.


Plunger replaces pull rod.

Fluid discharged length of pump stroke.

Disadvantages of San’ Pumps:

Stationary barrel design can sand in with extensive run times.

Not recommended for pumping gassy wells.

Barrel subject to corrosive attack unless upgraded material is used.

Volumax

Multiple volume type pump.

Obtains higher production than tubing pumps.

Increases loads on sucker rod strings

Volumax

Advantages of Volumax Pumps:

Produces large volumes of fluid.

Produces same volume as tubing pump with reduced cycle rate.

Insert type pump, can be pulled with rod string.

Disadvantages of Volumax Pumps:

Initial cost of pump is higher than regular pump

Not recommended for pumping sandy wells.

High unseating force on pump requires special hold down.

Three TubeOuter and Inner Barrel Tubes travel with rod string.

Standing Barrel (Middle Barrel Tube) is stationary.

No plunger incorporated in pump.

Check valve on top of pump.

Requires faster Strokes per Minute than conventional pumps due to

Three Tube

Disadvantages of Triax Pumps:

Not recommended for gassy applications.

Not recommended for low fluid level wells.

Has depth limitations.

Advantages of Triax Pumps:


Traveling barrel usually keeps sand off hold down assembly.

Top valve acts as check valve to keep sand out of pump.

Insert type pump, can be pulled with rod string.

Circle-A-Pump

Non API pump design.Designed for maximum flowDesigned for minimum turbulence.Designed for maximum efficiency.Can be built up to and including

3.50” bore size.

Circle-A-Pump

Advantages of Circle-A-Pumps:


Recommended for low fluid level, gassy, or foamy wells.


Recommended for deep well applications.

Disadvantages of Circle-A-Pumps:

Valve rod is the weak link in the rod string.

Initial cost is higher than conventional pump.

Material selection is limited.

Tension Pump

Keeps the rod string in tension on the downstroke.

Raises the minimum load of the sucker rod string.

Can be configured as either a rod pump or a tubing pump.

Increase in bottomhole stroke. Good application for both steel and

fiberglass sucker rod strings.

Tension Pump

Advantages of Tension Pumps:

Increase in Minimum Sucker Rod Loads.

Increase in Maximum Allowable Sucker Rod Stress.

Reduction/Elimination of Compressive Loads.

Increase in Net Plunger Travel.

Decrease in Polish Rod Horsepower.

Disadvantages of Tension Pumps:

May not be good in gassy applications.

Reduced Pump Efficiency. Unsure a POC will

determine a pumped off condition.

Lack of existing software to monitor loading.

Higher pump cost than standard pump.

The “Gas Bailer” Pump


Tubing Pumps

Typically produces more fluid than a rod pump.

More costly to service than a rod pump. Application is in shallow to medium

depth wells due to loading on rod string and pumping unit.

Not a good choice in gassy wells.

THBC – API Tubing Pump


Barrel Ran on Bottom of Tubing String.

Plunger Ran on Bottom of Rod String.

Bottom Holddown.

Heavy Wall Barrel.

Accessories Available for Subsurface Pumps

Top

Check

Valve

Bottom

Discharge

Valve

Top

Seal

Assembly

Tubing

Drain

Selecting a Subsurface Pump

What Information is Required?

Casing & Tubing Size

Equipment Available (Unit, Rods, etc.)

Depth

Fluid Production Required Viscosity Abrasion Corrosion

How do These Conditions Affect the Selection Process?

Tubing / Casing Size: Pump Bore Size.

Equipment Available: Pumping Unit & Rod Design Dictate Pump Size (Bore & Length).

Depth: Type of Barrel That Can be Run. Holddown Position.

Fluid: Size Pump Required to Reach Production Target. Pump Fit Required. Material Selection. Hold Down Position. Type of Accessories Available.

Determining Pump Length

Example: 3,000’ Well, Steel Sucker Rods, 120” Surface Stroke

120"

36"

12"

12"

180"Total Length=

Surface Stroke =

Plunger Length=

Pump Fittings=

Spacing=

Steel Barrel Yield Strength = 60,000 PSI

Brass Barrel Yield Strength = 60,000 PSI

RW Barrel SelectionMAXIMUM SETTING DEPTH CHART

RW (Thin Wall)

0

5000

10000

15000

20000

25000

30000

35000

0 30 50 70 90 110 130 150

Material Yield Strength (Thousand PSI)

Dep

th in

Feet

MAXIMUM SETTING DEPTH CHART

Recommended Safety Factors: For Bottom Hold Down Pumps -- Divide Max. Set. Depth By 2

For Top Hold Down Pumps -- Divide Max. Set. Depth By 3

EXAMPLE: 1-1/2" RW Pump, Bot. Hldn., Carbon Steel Max. Set. Depth -- 14,000 Rec. Safety Set. Depth --7,000'

Steel Barrel Yield Strength = 60,000 PSI

Brass Barrel Yield Strength = 60,000 PSI

RH & TH Barrel Selection


RH (Heavy WallTH (Heavy Wall)

0

5000

10000

15000

20000

25000

30000

35000

0 30 50 70 90 110 130 150

Material Yield Strength (Thousand PSI)

Dep

th in

Feet


Recommended Safety Factors: For Bottom Hold Down Pumps -- Divide Max. Set. Depth By 2

For Top Hold Down Pumps -- Divide Max. Set. Depth By 3

EXAMPLE: 1-3/4" RH Pump, Bot. Hldn., Carbon Steel Max. Set. Depth -- 18,000 Rec. Safety Set. Depth --9,000'

Barrel Tube Selection

Regular

Regular C

P

Carburiz

ed

501 SS C

P

Bra

ss

Bra

ss CP

Steel N

CC

Brass N

CC

ROCKWELL HARDNESS 15 70 62 70 80B 70 *71 *71

None A A A A A A A ANone + Abrasion X A A A X A B BSevere H2S X X X C A A A BSevere H2S + Abrasion X X X X X A B BMild H2S C C X C B A A AMild H2S + Abrasion X X X C X A B BSevere CO2 C C X B B B A BSevere CO2 + Abrasion X C X X X B C BMild CO2 B B X B B B A AMild CO2 + Abrasion X B X X X B C BSevere H2S + CO2 X X X C B C C BSevere H2S + CO2 + Abrasion X X X X X C C BMild H2S + CO2 X X X C B B C BMild H2S + CO2 + Abrasion X X X X X B C BSevere Brine B C B B A A A ASevere Brine + Abrasion X C B X X A B BMild Brine B B A A A A A AMild Brine + Abrasion X B A X X A B BOxygen B B C B A A A A

"A" Material suitable under most conditions."B" Corrosion or erosion expected, but material may be suitable under some conditions."C" Corrosion or erosion usually too severe for successful use."X" Material not suitable for use.

*Nickel Carbide Coated barrels have a composite hardness of 71HRC due to the silicon carbide particles in the nickel matrix..

Plunger Selection

Chr

ome

Plate

d

Chr

ome

Plate

Mol

ySpr

aym

etal

Spray

met

al N

icke

l Pin

Spray

met

al M

onel

Pin

ROCKWELL HARDNESS 70 70 62 62 62

None A A A A ANone + Abrasion A A A A ASevere H2S X X C A ASevere H2S + Abrasion X X C A AMild H2S X X A A AMild H2S + Abrasion X X A A ASevere CO2 X X C A ASevere CO2 + Abrasion X X C A AMild CO2 B B A A AMild CO2 + Abrasion B B A A ASevere H2S + CO2 X X X A ASevere H2S + CO2 + Abrasion X X X A AMild H2S + CO2 X X B A AMild H2S + CO2 + Abrasion X X B A ASevere Brine X X B A ASevere Brine + Abrasion C C B A AMild Brine C C A A AMild Brine + Abrasion C C A A AOxygen C C B A A


Plunger Fit & Length SelectionThe following recommendations are based upon years of experience in manufacturing and installation of subsurface

pumps. They are to be used as a guide in design of subsurface pumps.

Size Fit Plunger Length Size Fit Plunger Length1.06" & 1.25" -0.001" 2 ft. 2.25 & 2.50" -0.004" 2 ft.1.50" -0.002" 2 ft. 2.75" & 3.75" -0.005" 2 ft.1.75" & 2.00" -0.003" 2 ft. 4.75" & 5.75" -0.007" 2 ft.

Example: 2.25" x 3 ft. = -0.004" plus -0.01" = -0.005" fit

2.25" x 4 ft. = -0.004" plus -0.002" = -0.006 fit

2,000' 3,000' 4,000' 5,000' 6,000' 7,000' 8,000'1.06" 2' 2' 3' 3' 4' 4' 5'1.25" 2' 2' 3' 3' 4' 4' 5'1.50" 2' 2' 3' 3' 4' 4' 5'1.75" 2' 2' 3' 3' 4' 4' 4'2.00" 2' 2' 3' 3' 3' 4' 4'2.25" 2' 2' 2' 3' 3' 4' 4'2.50" 2' 2' 2' 3' 3' 3' -----2.75" 2' 2' 2' 3' 3' ----- -----3.75" 2' 2' 2' 2' ----- ----- -----4.75" 2' 2' 2' ----- ----- ----- -----5.75" 2' ----- ----- ----- ----- ----- -----

SizeWell Producing Depth

Maximum Plunger Length

Reduce fit (increase clearance) by -0.001" for each additional foot of length up to 4 ft.

or

Maximum Plunger Fit

Individual well conditions such as API gravity, Sand content, etc. must be considered in final plunger fit.

Ball & Seat Selection

440C

SS B

all

440C

SS S

eat

Rexall

oy 35 B

all

Rexall

oy 44 S

eat

Tung C

arbid

e Ball

Tung C

arbid

e Sea

t

Titaniu

m C

arb B

all

Silicon N

itrid

e

Ceram

ic

ROCKWALL HARDNESS 61 54 63 46 A89 A88 85 94 84None A A A A A A A A ANone + Abrasion A A A A A A A A ASevere H2S B B A A A A A A ASevere H2S + Abrasion C C B B A A A A AMild H2S A A A A A A A A AMild H2S + Abrasion B B A A A A A A ASevere CO2 A A A A A A A A ASevere CO2 + Abrasion B B B B A A A A AMild CO2 A A A A A A A A AMild CO2 + Abrasion A A A A A A A A ASevere H2S + CO2 B B A A A A A A ASevere H2S + CO2 + Abrasion C C B B A A A A AMild H2S + CO2 A A A A A A A A AMild H2S + CO2 + Abrasion B B A A A A A A ASevere Brine A A A A A A A A AMild Brine + Abrasion B B A A A A A A AOxygen A A A A A A A A A


Fitting Selection

1045

CARBON S

TEEL

8620

ALLOY S

TEEL

3000

SERIE

S STAIN

LESS

17-4

DOUBLE H

EAT TREATED S

S

NAVAL BRASS 7

0-30

R MONEL 4

05

None A A A A A ANone + Abrasion X A A A A ASevere H2S X C C X B ASevere H2S + Abrasion X C C X B AMild H2S B B B C B AMild H2S + Abrasion X B B C B ASevere CO2 X X A A C ASevere CO2 + Abrasion X X A A C AMild CO2 C C A A A AMild CO2 + Abrasion C C A A A ASevere H2S + CO2 X X B X C ASevere H2S + CO2 + Abrasion X X B X C AMild H2S + CO2 C C B C A AMild H2S + CO2 + Abrasion C C B C A ASevere Brine X B B X B AMild Brine + Abrasion C B B B A AOxygen X C A A C A


Spacing a Pump at the Wellsite

2.0 x Footage of Steel Rods (ft)

2.0 x Seating Nipple Depth (ft)

Add { 1 } + { 2 } to get pump spacing off bottom in inches. Rule of thumb.

= { 2 }1,000

Steel Sucker Rod String

1,000= { 1 }

9.0 X Footage of Steel Rods (ft)

2.0 x Seating Nipple Depth (ft)

Add { 1 } + { 2 } to get pump spacing off

= { 2 }1,000

Fiberglass Sucker Rod String

1,000= { 1 }

6,0001,000

6,0001,000

Steel Sucker Rod String

2.0 x 3,000

1,000=

=1,000

2.0 X 3,000{ 6 }

{ 6 }

=

=

6" + 6" = 12" spaced off bottom

How Important is Spacing ?

@ 16" = 300#

@ 8" = 600#

@ 4" = 1200#

2400#=

Pressure

PumpIntake Pressure

Hydrostatic

@ 2"

2400#

2400#

Efficiencies of Sucker Rod Pumps

Theoretical Production:Pump Constant x SPM x Surface Stroke Length

Actual Production:Pump Constant x SPM x Net Plunger Stroke

Factors Causing Efficiency LossesRod Design: Stretch & OvertravelTubing: Anchored or Unanchored

Fluid Slippage: Viscosity, Pump Clearances, Pump WearGas Interference: GOR & GLR

Pump Production Formula

Net Plunger Travel x SPM x Pump Constant

0.1316 = 1-1/16" 0.7285 = 2-1/2"0.1821 = 1-1/4" 0.8814 = 2-3/4"0.2622 = 1-1/2" 1.2310 = 3-1/4"0.3569 = 1-3/4" 1.6390 = 3-3/4"0.3695 = 1-25/32" 2.6297 = 4-3/4"0.4662 = 2" 3.5258 = 5-1/2"0.5901 = 2-1/4" 7.0006 = 7-3/4"

Pump Constants:

1 Change the figure in the red box to the desired pump bore size. 1.5

2 Change the figure in theblue box to the desired surface stroke in inches. 100

3 Press enter.4 Chart will automatically calculate fluid production

EFF. SPM> 3 4 5 6 7 8 9 10 11 12

100% m3/day 12.5 16.7 20.9 25.0 29.2 33.4 37.5 41.7 45.9 50.0

(bbl/day) 78.3 104.3 130.4 156.5 182.6 208.7 234.8 260.8 286.9 313.0

90% m3/day 11.3 15.0 18.8 22.5 26.3 30.0 33.8 37.5 41.3 45.0

(bbl/day) 70.4 93.9 117.4 140.9 164.3 187.8 211.3 234.8 258.2 281.7

80% m3/day 10.0 13.3 16.7 20.0 23.4 26.7 30.0 33.4 36.7 40.0

(bbl/day) 62.6 83.5 104.3 125.2 146.1 166.9 187.8 208.7 229.5 250.4

70% m3/day 8.8 11.7 14.6 17.5 20.4 23.4 26.3 29.2 32.1 35.0

(bbl/day) 54.8 73.0 91.3 109.6 127.8 146.1 164.3 182.6 200.8 219.1

60% m3/day 7.5 10.0 12.5 15.0 17.5 20.0 22.5 25.0 27.5 30.0

(bbl/day) 47.0 62.6 78.3 93.9 109.6 125.2 140.9 156.5 172.2 187.8

50% m3/day 6.3 8.3 10.4 12.5 14.6 16.7 18.8 20.9 22.9 25.0

(bbl/day) 39.1 52.2 65.2 78.3 91.3 104.3 117.4 130.4 143.5 156.5

40% m3/day 5.0 6.7 8.3 10.0 11.7 13.3 15.0 16.7 18.3 20.0

(bbl/day) 31.3 41.7 52.2 62.6 73.0 83.5 93.9 104.3 114.8 125.2

30% m3/day 3.8 5.0 6.3 7.5 8.8 10.0 11.3 12.5 13.8 15.0

(bbl/day) 23.5 31.3 39.1 47.0 54.8 62.6 70.4 78.3 86.1 93.9

20% m3/day 2.5 3.3 4.2 5.0 5.8 6.7 7.5 8.3 9.2 10.0

(bbl/day) 15.7 20.9 26.1 31.3 36.5 41.7 47.0 52.2 57.4 62.6

10% m3/day 1.3 1.7 2.1 2.5 2.9 3.3 3.8 4.2 4.6 5.0

(bbl/day) 7.8 10.4 13.0 15.7 18.3 20.9 23.5 26.1 28.7 31.3

FLUID PRODUCTION TABLEPump Bore (in)

Surface Stroke (in)

Observations at the Bleeder for Sucker Rod Pumps

Observations at the Bleeder

Suction on the Upstroke

Traveling Valve Assembly Leaking

If the traveling assembly is leaking, there will be a suction on the upstroke. This is caused by fluid above the plunger rushing downward to fill the area in the pump chamber that is vacated by the plunger as it moves upward.

Traveling Valve is not holding.

•Ball & Seat Leak

•Ball bad

•Seat Bad

•Cage Bad


Suction on the Upstroke

Rod Part (Tubing Partially Full of Fluid)

On the upstroke, the polish rod will move up and out of the tubing which can create a suction.


Blow on the Upstroke &Suction on the Downstroke

Standing Valve Leaking

If the standing valve is leaking the rod pump will not displace fluid. It will take fluid into the pump chamber on the upstroke, then release it back into the well bore on the downstroke. The fluid above the traveling valve will ride up and down with each stroke of the unit.

Standing Valve is not holding.•Ball & Seat Leak

•Ball bad

•Seat Bad

•Cage Bad



Gas Interference or “Gas Lock”

When gas interferes, the fluid and gas in the pump chamber can not be compressed to open the traveling valve on the downstroke. At the same time the gas/fluid mixture maintains enough pressure to keep the standing valve closed which prevents more fluid from entering the pump. The fluid above the traveling valve will ride up and down with each stroke of the unit.



Well is “Pumped Off”

Pumped off is very similar to “Gas Locked” at the bleeder. Fluid above the traveling valve rides up and down with the unit. It is possible to encounter a “fluid pound” situation. The pump will appear to be tagging even if it is properly spaced. This can occur when the lower chamber of the pump is only partially filled with fluid. The traveling valve is held closed with the hydrostatic load, and on the downstroke it will slam into the fluid above the standing valve.

Incomplete Fillage in the Pump Chamber


Suction on the Upstroke and Downstroke

Tubing Leaking

If the pump is operating properly, on the upstroke the plunger will lift a column of fluid toward the surface. With a tubing leak, the fluid will dump into the annulus creating a suction at the bleeder.

Tubing Leak


Blow on the Upstroke and Downstroke

Flowing Well

This is a characteristic of a well that flows the tubing dry from pressure from the formation. When the formation pressure is great enough to overcome the hydrostatic load on the traveling valve, it will keep both the traveling and standing valves in the open position.

Formation Pressure


Suction on the Upstroke and Blow on the Downstroke

Rods Parted (Tubing is Full Of Fluid)

The suction is created when the polish rod moves up and out of the tubing. The blow occurs as the polish rod moves down and into the fluid held in the tubing.

Summary ofObservations at the Bleeder

Suction on the Upstroke: Traveling Valve is Leaking. Rods Parted (Tubing partially full of Fluid).

Blow on the Upstroke & Suction on the Downstroke: Standing Valve is Leaking. Gas Interference or “Gas Lock”. Well is Pumped Off.

Suction on the Upstroke & Downstroke: Tubing is Leaking.

Blow on the Upstroke and Downstroke: Well is trying to Flow.

Suction on the Upstroke & Blow on the Downstroke: Sucker rods are parted (Tubing is Full of Fluid).

Care & Handling of Subsurface Pumps


Subsurface pumps are built with precision components. The barrel and plunger are measured in thousandths of an inch. The OD and ID of the pump can have plating or coatings that can be damaged with improper handling practices. A pumps efficiency and run life can be effected by the way a pump is handled. Is everyone that handles your pump aware what a subsurface pump can cost?


Pump Storage at the Pump Shop

The pump should have waterproof wrapping on both ends and an identification tag secured .

Pumps should be stored in a single layer on horizontal racks.

Supports should be spaced no more than six feet apart.


Transportation by the Pump Shop

Pumps with a barrel tube of 24’ or shorter may be transported on the side of a vehicle.

Pumps with a barrel tube longer than 24’ will be transported on a trailer.

There will be a minimum of three supports on the vehicle, and each will be used to secure the pump.


Storage of the Pump on Location

Pumps should have the waterproof wrapping on both ends and stored on some type of horizontal support.

The supports should be similar in spacing to pumps stored in the pump shop.

Remember to never stack other equipment such as sinker bars, polish rod and liner, and sucker rods on top of the pump.


Running the Pump

If the pump barrel is 20’ or longer, it is suggested that a pick up clamp be used by the crew.

Do not drag the bottom of the pump when it is being lifted by the elevators.

Longer pumps should be supported by the sand line being attached in the middle of the pump.

Gas anchors should be made up while the pump is in the vertical position using a clamp on the gas anchor for safety.

Adjustable wrenches are preferred over pipe wrenches in making up the top and bottom connections of the pump.

Sucker Rod Pump Basics. Presentation Contents: Sucker Rod Pumps The Five Basic Components of a...

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