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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
The Five Basic Componentsof a Sucker Rod Pump:
Barrel Tubes
Thin WallRW & RS
Barrel
Heavy WallRH Barrel
Tubing Pump TH Barrel
Tubing Pump TP Barrel
The Five Basic Componentsof a Sucker Rod Pump:
Plungers
Pin EndSpraymetal
Plunger
Box EndSpraymetal
Plunger
Box EndSpraymetal
GroovedPlunger
Monel PinSpraymetal
Plunger
PressureActuatedPlunger
The Five Basic Componentsof a Sucker Rod Pump:
Rings for Soft-Packed Plungers
Composition Ring Split Composition Ring Pressure Actuated Ring
Flexite Ring Valve Cup
The Five Basic Componentsof a Sucker Rod Pump:
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
The Five Basic Componentsof a Sucker Rod Pump:
Standing Valves
Closed-TypeCage
Insert Style
Closed-Type Cage
Open CageTraveling
Barrel Type
Open CageTubing Pump
Closed CageTubing Pump
The Five Basic Componentsof a Sucker Rod Pump:
Valves for Traveling & Standing
Ball & SeatRib Type
Ball & SeatFlat Type
The Five Basic Componentsof a Sucker Rod Pump:
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
The Five Basic Componentsof a Sucker Rod Pump:
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
LBS of Force Required to
1.250" 1.500" 2.375" 2.875" 3.500"
LBS of Force Required to
LBS of Force Required to
LBS of Force Required to
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 Sucker Rod Pumps
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:
Not recommended for deep wells.
Valve rod is the weak link.
Not recommended for intermittent pumping.
Tubing erosion opposite top guide.
RWBC – API Insert Pump
Plunger Travels with Rod String.
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.
Valve rod is the weak link.
Not recommended for intermittent pumping.
Tubing erosion opposite top guide.
Barrel subject to corrosive attack.
RHBC – API Insert Pump
Plunger Travels with Rod String.
Bottom Holddown.
Heavywall Barrel.
RHBC – API Insert Pump
Advantages of RHBC Pumps:
Recommended for deep wells.
Recommended for low fluid levels.
Recommended for stroke through design to combat scale and/or gyp.
Disadvantages of RWBC Pumps:
Not recommended for sandy wells.
Valve rod is the weak link.
Not recommended for intermittent pumping in sandy wells.
Tubing erosion opposite top guide.
Barrel subject to corrosive attack.
RHAC – API Insert Pump
Plunger Travels with Rod String.
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.
Recommended for wells requiring long pumps.
Disadvantages of RWBC Pumps:
Not recommended for deep wells.
Valve rod is the weak link.
Not recommended for intermittent pumping.
Tubing erosion opposite top guide.
Hollow Tube
Plunger Travels with Rod String.
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:
Recommended for deep wells.
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:
Not recommended for sandy wells.
Barrel subject to corrosive attack.
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.
Recommended for low fluid levels.
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:
Recommended for sandy wells.
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 sandy wells.
Recommended for low fluid level, gassy, or foamy wells.
Recommended for wells requiring long pumps.
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
Types of Sucker Rod Pumps
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
Plunger Travels with Rod String.
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
MAXIMUM SETTING DEPTH CHART
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
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: 1-3/4" 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
"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.
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
"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.
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
"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.
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
Observations at the Bleeder
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.
Observations at the Bleeder
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
Observations at the Bleeder
Blow on the Upstroke &Suction on the Downstroke
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.
Observations at the Bleeder
Blow on the Upstroke &Suction on the Downstroke
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
Observations at the Bleeder
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
Observations at the Bleeder
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
Observations at the Bleeder
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
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?
Care & Handling of Subsurface Pumps
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.
Care & Handling of Subsurface Pumps
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.
Care & Handling of Subsurface Pumps
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.
Care & Handling of Subsurface Pumps
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.