Sucker Rod Pumps 2001 CD

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ARTIFICIAL LIFT SYSTEMS

®

Introduction

Components

Applications &

Considerations

Troubleshooting





®

IntroductionIntroduction





®

General

Well Design





®

Complete

ConventionalSucker Rod

Pump

System





®

APIClassification


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®

API Method of Pump

Assembly Description

Heavy-Wall

Barrel

Thin-Wall

Barrel

Heavy-Wall

Barrel

Thin-Wall

Barrel

Stationary Barrel,

Top Anchor RHA RWA - RSA

Stationary Barrel,

Bottom Anchor RHB RWB RXB RSB

Traveling Barrel,Bottom Anchor RHT RWT - RST

Tubing Pumps TH - TP -

ROD PUMP TYPE

SOFT-PACKED PLUNGER

PUMPSMETAL PLUNGER PUMPS

Letter Designations

Heavy-Wall

Barrel

Thin-Wall

Barrel

Heavy-Wall

Barrel

Thin-Wall

Barrel

Stationary Barrel,

Top Anchor RHA RWA - RSA

Stationary Barrel,

Bottom Anchor RHB RWB RXB RSB

Traveling Barrel,Bottom Anchor RHT RWT - RST

Tubing Pumps TH - TP -

ROD PUMP TYPE

SOFT-PACKED PLUNGER

PUMPSMETAL PLUNGER PUMPS

Letter Designations




®

Tubing Pumps vs. Insert Pump

Barrel Assembly of this type pump is screwed onto,

and becomes part of the tubing.

Larger bore than a rod pump, thus it produces a

greater volume of fluid in any give diameter of tubing

The complete pump is attached to, and inserted into

the well tubing with the sucker rod string.

As a complete unit, this pump may be pulled out of

the well without pulling the tubing.

Tubing Pump

Insert Pump




®

Basic Rod PumpConfigurations

RWTC

Rod-Type,

Thin Wall,

Traveling Barrel,

Bottom

Holddown (Cup)

RWAM

Rod-Type,

Thin Wall,

Top Holddown

(Mechanical)

RHBC

Rod-Type,Heavy Wall,

Bottom Holddown

(Cup)

THM

Tubing-Type,Heavy Wall,

Mechanical

Holddown




®

Rod PumpOperation - Concept

Visualization of Rod Pump Working

(A) (B) (C)

Pump grabs a “bite” of fluid

on each downstroke of the

pump, as the “mouth” of the

traveling valve opens on the

downstroke, and grabs a

bite of whatever is within the

compression chamber.

(A)




®


Upstroke closes thetraveling valve, traps the

fluids in the chamber and

physically lifts them up thewell a few feet. This bite is

simply stacked below the

previous bite until enough

bites start running out at

the surface of the well.

(B)


(A) (B) (C)




®


Standing Valve opens at the

start of upstroke to admit

fluids into the compression

chamber from the reservoir,and closes on downstroke

of pump to prevent these

fluids from returning to theformation.

(C)


(A) (B) (C)




®

Types of Insert Pumps

Rod Pump - Top Anchor

Rod Pump - Bottom Anchor

Rod Pump - Travel Barrel Bottom Anchor




®

Rod PumpBarrel ApplicationTop Anchor

BottomHold-Down

Pump

TopHold-DownPump





®

Rod PumpTop Anchor

Valve Rod

Plunger

Barrel

Ball Stop

Standing

Valve

Seat

Traveling

Valve

Valve Rod

Plunger

Barrel

Ball Stop

Standing

Valve

Seat

Traveling

Valve

PumpPump

MovementMovement





®

Rod PumpTop Anchor

Good for sandy wells

Pump Barrel acts as Gas Anchor

Excellent for low fluid wells

Advantages

Disadvantages

Valve rod is weak leak of sucker rod

Not recommend for deep wells

Barrel Tube subject to sedimentation on

part-time pumping





®

Rod PumpBarrel Application

Bottom Anchor

BottomHold-Down

Pump

TopHold-DownPump





®

Rod PumpBottom Anchor

Valve Rod

Plunger

Barrel

Ball Stop

Standing

Valve

Seat

Traveling

Valve

Valve Rod

Plunger

Barrel

Ball Stop

Standing

Valve

Seat

Traveling

Valve

PumpPump

MovementMovement





®

Rod PumpBottom Anchor

Run in deep wells

Good valve location

Better design where long pumps necessary

Advantages

V-rod weak link in S-rod chain

Barrel Tube subject to sedimentation

Barrel Tube subject to corrosion

Disadvantages





®

Rod PumpTraveling BarrelBottom Anchor





®

Rod PumpTraveling Barrel

Valve Rod

Plunger

Barrel

Ball Stop

Standing Valve

Seat

Traveling

Valve

Valve Rod

Plunger

Barrel

Ball Stop

Standing Valve

Seat

TravelingValve

PumpPump

MovementMovement





®

Rod Pump- Traveling BarrelBottom Anchor

Agitation keep sand from settling Good discharge distribution

Both cages are open type

Advantages

Not recommend for gas wells

Not recommend for pumps in deep wells

Poor valve placement

Disadvantages





®

Types of Tubing Pumps

Tubing Pump- Bottom Anchor

Large Bore Tubing Pump





®

API Pump

Assembliesfor Tubing Pump

Bottom Anchor

THC

Pump

THM

Pump

TPC

Pump





®

Tubing Pumps

Valve Rod

Plunger

Barrel

Ball Stop

Standing Valve

Seat

TravelingValve

Valve Rod

Plunger

Barrel

Ball Stop

Standing Valve

Seat

TravelingValve

PumpPump

MovementMovement





®

Tubing Pump-Bottom Anchor

Higher volume Simple Rugged for severe service

Used to stroke in & out of barrel

Pulling cost factor

Prone to gas locking

Stuck SV leads to pulling wet string

Advantages

Disadvantages





®

High VolumeFluid Pumps





®

High Volume Fluid Pumps

Casing Pump - attached to the Packer

Advantages - Highest volume available;

insert style, therefore retrievable Disadvantages - Wear by the rods on the

casing; sanding in of the packer

‘Bottled-Up’ Pump Advantages - Greater Production Volumes

Disadvantages - Plunger larger than the tubing

Oversized Tubing Pump

ID threads on barrel allow larger plunger

than normal





®

ComponentsComponents





®

Rod PumpHolddowns

MechanicalBottom Lock

Holddown

MechanicalTop Lock

Holddown

Cup-TypeHolddown





®

Rod PumpBarrels & Plungers

Barrels materials available -

Regular steel

Hardened steel Regular steel w/ chromed I.D.

Brass

Brass w/chromed I.D.

Stainless w/chromed I.D. Steel Nickel Carbide

Brass Nickel Carbide

Plungers available inall standard API

sizes and types





®

Rod PumpBarrels





® Rod

Pump

Barrels

TubingPump

Barrels

Thin Wall Heavy Wall

Heavy WallCommon Working

Barrel

SEAL

SEAL

RW, RS RH

TP TH

THREADED

SEAL

Difference

BetweenRod PumpandTubing PumpBarrels





®

Thin Wall Barrel &Heavy Wall Barrel





®

Metallurgy

Nobility Chart

Galvanic

Series of Metals





®

M i l d

M o d e r a

t e

S e v e r e

M i l d

M o d e r a

t e

S e v e r e

Precision - 1026 Steel

90 HRB - 23

HRC X X

Precision - 443 Brass 85 HRB (Min) X X

Nitrided - Alloy Steel 58 - 63 HRC X X

Carburized - Carbon

Steel

58 - 63 HRC X X

Barrel MetallurgySurface

Hardness

AbrasionCorrosion

Service

Barrel Metallurgy Applications(Steel Barrel)





®

M i l d

M o d e r

a t e

S e v e r e

M i l d

M o d e r

a t e

S e v e r e

Chrome Plated ID -

1026 Steel69 - 72 HRC X X

Chrome Plated ID - 443

Brass69 - 72 HRC X X

Chrome Plated ID -

Nickel Copper Alloy

69 - 73 HRC X X

Nickel Carbide Coated -

1026 Steel72 - 75 HRC X X

Nickel Carbide Coated -

443 Brass72 - 75 HRC X X

MetallurgySurface

Hardness

Service

Corrosion Abrasion

Barrel Metallurgy Applications

(Steel CID Barrel)





®

Barrel Comparison for 2.75"

0

0.5

1

1.5

2

2.5

Steel ChromePlated ID Steel Nickel

Carbide Coated

Brass ChromePlated ID Brass Nickel

Carbide Coated

V a l u e

o f B a r r e l

Barrel Performance





®

Chrome Plated Barrel(Loosing Chrome)





®

Rod PumpPlungers

Plungers available in all

standard API sizes and

types





®

WeatherfordManufactured Plungers

Pin End

Plunger Box End

Plunger

Grooved

Plunger

Monel Pin

End

Plunger

Pressure

Actuated

Plunger





®

Plunger

MaterialMild Moderate Severe Mild Moderate Severe Mild Moderate Severe

Spray Metal

58 RC min. X X X

Chrome Plated

67 - 71 RCX X X

Spray Metal

Monel Pin 58

RC min

X X X

Pressure

Actuated with

Steel Pins

58 RC min

X X X

Pressure

Actuated with

Monel Pins 58

RC min

X X X

CO2Abrasion H2S

Plunger MaterialSelection





®

Pressure ActuatedPlunger





®

Rod PumpFluid Slippage

Depending upon well fluids and

conditions, 2-3% slippage of

produced fluid is expected to keep

barrel/plunger contact sufficiently

lubricated.





®

High-Pressure Fluid Effectson Rod Pump Barrels

Fig. #1 Fig. #2 Fig. #3

A. Traveling Valve

B. Pump Barrel

C. Pump SuctionD. Pressure created by fluid

column in tubing

E. Plunger

F. Tubing

G. Bottom Holddown

H. Sucker or Pony Rod

I. Top Holddown

J. Fluid level in the well





®

Shows the effect of

pressure caused by

the fluid column hydrostaticpressure against the part

of the barrel not supported

internally by the plunger.

As the plunger moves, it

contacts the convex wall

of the barrel causing it to

wear into a ‘cigar’ shape.

Fig. 3 - Bottom Holddown Rod Pump


Figures 1 & 3

Fig. 1 -Traveling Barrel Rod Pump

Fig. 2Fig. 1 Fig. 3





®


Fig. 2Fig. 1 Fig. 3

Figure 2

Shows the effect of thepressure of the

fluid column hydrostatic

pressure on a stationary

barrel pump (top or bottomholddown)





®

Standing Valves

Closed-Type

Cage

Open Cage,

Traveling BarrelOpen Cage,

Tubing

Open Cage, Tubing,

Drain-Type Closed Cage,Tubing, Permanent

Closed Type

Cage,

Insert Style





®

Standing Valves





®

Double Valve





®

Four Ball Guides





®

Double Traveling Valve &Standing Valves

Extra set of valves offer backup seal in

the event of trash or valve wear.

Extra set of valves reduces the unswept

area in the pump, which reduces the

compression ratio, thus limiting the

pumps ability to handle gas.

More parts = more expensive pump

Advantages

Disadvantages





®

Traveling Valves

Closed-Type

Cage for Pin-

End Plunger

Closed-Type

Cage for Box-

End Plunger

Open-Type Cage for

Traveling Barrel

Pump Barrel

Closed-Type

Cage,

Insert Style





®

Piston Steel Chrome Molly Stainless Steel N50Spray Metal

Coating

C1045 Carbon A4140 431 N50Nickel Base

Alloy

Chemical Analysis

Carbon C 0.41 - 0.49 0.38 - 0.43 0.20 max 0.06 max 0.50 - 1.00

Manganese Mn 0.60 - 0.87 0.75 - 1.00 1.00 max 4.00 - 6.00

Phosphorus P 0.04 max 0.035 max 0.04 max 0.00 - 0.02

Sulfur S 0.05 max 0.04 max 0.03 max 0.00 - 0.02

Chromium Cr 0.80 - 1.10 15.00 - 17.00 20.50 - 23.50 12.00 - 18.00Silicon Si 0.15 - 0.35 1.00 max 1.00 max 3.50 - 5.50

Iron Fe Balance Balance 3.00 - 5.50

Boron B 2.50 - 4.50

Cobalt Co 0.00 - 0.10

Nickel Ni 1.25 - 2.50 11.5 - 13.50 66.00 - 79.00

Copper Cu

Nitrogen N 0.20 - 0.40

Molybdenum Mo 0.15 - 0.25 1.50 - 3.00

Properties

Tensile 90K - 120K 120K - 150K 120K min 135K min N/A

Yield 85K - 110K 90K - 120K 100K min 105K min N/AElongation 9% - 12% 10% - 20% 20% 20% N/A

Hardness Rc 19 - 28 Rc 25 - 33 Rc 24 - 55 Rc 35 max Rc 55 - 62

Raw Material

General Terminology for

Polished RodPiston Steel Chrome Molly Stainless Steel N50

Spray Metal

Coating

C1045 Carbon A4140 431 N50Nickel Base

Alloy

Chemical Analysis

Carbon C 0.41 - 0.49 0.38 - 0.43 0.20 max 0.06 max 0.50 - 1.00

Manganese Mn 0.60 - 0.87 0.75 - 1.00 1.00 max 4.00 - 6.00

Phosphorus P 0.04 max 0.035 max 0.04 max 0.00 - 0.02

Sulfur S 0.05 max 0.04 max 0.03 max 0.00 - 0.02

Chromium Cr 0.80 - 1.10 15.00 - 17.00 20.50 - 23.50 12.00 - 18.00Silicon Si 0.15 - 0.35 1.00 max 1.00 max 3.50 - 5.50

Iron Fe Balance Balance 3.00 - 5.50

Boron B 2.50 - 4.50

Cobalt Co 0.00 - 0.10

Nickel Ni 1.25 - 2.50 11.5 - 13.50 66.00 - 79.00

Copper CuNitrogen N 0.20 - 0.40

Molybdenum Mo 0.15 - 0.25 1.50 - 3.00

Properties

Tensile 90K - 120K 120K - 150K 120K min 135K min N/A

Yield 85K - 110K 90K - 120K 100K min 105K min N/A

Elongation 9% - 12% 10% - 20% 20% 20% N/A

Hardness Rc 19 - 28 Rc 25 - 33 Rc 24 - 55 Rc 35 max Rc 55 - 62

Raw Material

General Terminology for

Polished Rod

Polished Rod Specifications





®

Special Applications

& Considerations





®

Pump Failure Types

Operational

Well Condition

Mechanical





®

Operational Problems

Bottomhole Assembly design

Bad spacing of pump

Bad seating nipple

Deviated wells

Loose Tubing Anchor





®

Well Condition Problems

Fluid Pound

Gas Locking

Sand

Scale

Corrosion





®

Mechanical Problems

Seized Pumps

Parted V-Rods

Split Cages

Split Barrels

Scored Plungers





®

Solutions to“Well” Known Problems

Gas Locking

Sand Problems

Heavy Oil





®

What is Gas Locking?

Gas Lock Occurs when a barrel iscompletely filled with Gas.

Gas can not be compressed enough to

overcome the Hydrostatic head acting

on the traveling valve.

Consequently both valves remainclosed and the pump is gas locked.





®

Required Compression Ratiosas Reservoir Pressure Depletes





®

Gas Locking vs Gas Interferencevs a Pumped Off Condition

Gas Locking

No valves open during pumping cycle.

No fluid lifted to surface.

Gas Interference

Valves function properly, but reduced efficiencyas gas takes place of some fluid.

Pumped Off ConditionPumping rate exceeds ability of fluid to flow

into pump. Well does produce some fluid.

G L ki G I t f





®

Gas Locking, Gas Interference& a Pumped Off Condition

R d P





®

Rod PumpGas Locking

Not enough pressure generated in

compression chamber on down stroke

to open traveling valve.

Produced fluid in tubing rides up anddown with traveling valve, which is not

opening.

Causes

R d P





®

Rod PumpGas Lock

Effects

No fluid produced to the surface.Fluid level on backside continues

to rise as no fluids are removed

from well.

R d P





®

Rod Pump -Gas Locking

Increase compression ratio in pump

through better design/assembly.

Increase compression ratio in pump

through longer stroke or smaller plunger.

Install II stager valve to removehydrostatic pressure from traveling valve.

Reduce gas intake into pump through

better downhole separation.

Increase pump intake pressure by

allowing higher fluid level on backside.

Solutions

R d P





®

Rod PumpGas Interference

Poor gas separation, prior to fluidentering the pump, allows gas to

take the place of fluid in thecompression chamber.

Causes

R d P





®

Effects

Pump shows poor efficiency becauseonly fluid is being measured.

Pump is actually operating properly,

but fluid production is limited bygas in pump.


R d P





®

Solutions

Separate gas from fluid before it gets

to pump intake through better downhole separation.

Increase rate of well by lengtheningstroke, changing strokes per minute

or changing bore size.

This increases both gas and fluidwhich are produced through

the pump.






®

API RWB Pump

API RHB Pump





®

API RWB Pump

API RHB Pump

Pumps with

Extensions have

greater chancefor gas locking

then Pumps without Extensions

WHY?

More space

Decreases

compression ratios





® Gas Compression Ratios

Spacing vs. Fluid Over Pump

2438 meters - 2" pump - 100" Net Plunger Travel

0

1000

2000

3000

4000

5000

6000

7000

8000

.5" 2.5" 4.5" 6.5" 8.5" 10.5" 12.5" 14.5" 16.5" 18.5"

Spacing Off Bottom

M a x i m u m P r e s s u r e i n

C o m p r e s s i o

n C h a m b e r

0

50

100

150200

250

300

350

400

M e t e r s o f

F l u i d a b o v e

P u m p

Pressure in Barrel Pressure on Traveling Valve

Fluid Required Over Pump

API Subsurface Pump





®

0

10

20

30

40

50

60

70

54 64 74 86 100 120 144 168 192

Stroke Length

C o m p

r e s s i o n R a t i o

1-1/4" Plunger )Rod) 1-1/2" Plunger(Rod) 1-3/4" Plunger (Rod)

2" Plunger (Rod) 2-1/4" Plunger(Tubing)

API Subsurface PumpCompression Ratios





®

Combating Gas Locking

High Compression Valves

Gas Breakers

Gas Anchors

Combating





®

CombatingGas Locking

Gas Breakers

Two Stager

Gas Compression Valves

Gas Compression Plugs

Sliding Top Valve





®

COMPRESSION RATIOS

A B C D

Well Depth (mts.) 2,286.0 2,286.0 2,286.0 2,286.0

Plunger Travel 90" 90" 90" 90"

Pump Bore 1.25 1.25 1.25 1.25

Oil Cut 80% 80% 80% 80%

Seat Plug Type Standard Standard Hex Plug Hex Plug

Intake Pressure 80 PSI 80 PSI 80 PSI 80 PSIS.V. Cage Type Standard Standard Inverted Inverted

Unswept Barrel Area 1.287 5.582 5.037 0.74

Unswept S.V. Area 2.244 2.244 1.264 1.264

Total Unswept Area 3.531 7.826 6.301 2.004Distance Spaced Off Bottom 1/2" 4" 4" 1/2"

Load on Traveling Valve 3200 3200 3200 3200

Pressure in Barrel 2582 1209 1483 4488





®

Conventional

(Poor Boy)

Gas Anchor

Gas Separation





®

Gas Separation(Concept 1 of 4 )

Casing

Tubing

Rods

Pump

Spillover Tube

Crossover Packer

Pump IntakePerforations

Producing Zone

Packer-Type Anchor

Casing

Tubing

Rods

Producing Zone

Pump

Seating Nipple

Tubing Intake

Perforations

Natural-Gas Anchor

Gas Separation





®

Poor-Boy Gas Anchor

Tubing

Rods

Pump

Tubing IntakePerforations

Producing Zone

Casing

Seating Nipple

Suction Tube

Mud Anchor

Modified Poor-Boy

Gas Anchor

Tubing

Rods

Pump

Tubing IntakePerforations

Producing Zone

CasingSeating Nipple

Suction TubeMud Anchor


Gas Separation





®

1.9-in. Casing

Rods

2 7/8-in. O.D. Casing

Pump

Seating Nipple

1.316-in. OD Tubing

Producing Zone

TubingPerforations

Modified Natural-Gas Anchor

(For Small-Diameter Casing)

Rods

2 7/8-in. OD Casing

Pump

Seating Nipple

30 in. x 1.0-in.O.D. Tubing

Producing Zone

Packoff

Modified Packer-Type Gas Anchor



Gas Separation





®

Fluid Level

Liquid

Gas5 1/2-in. Casing

Decentralizer

DiametricallyOpposed to Lower Port (not to scale)

Casing

Perforations

2 7/8-in. Tubing

Seating Nipple

Upper Port

3 5/8-in.Thin WallPipe (1/8-in.)

Lower Port

Dip Tube

3 5/8-in. O.D. Thin-Wall Gas Separator



Rod Pump





®

Rod PumpHorizontal Wells

AdvantagesReduce reservoir pressure by lowering fluid level and recovering

more fluid. Better gas separation when pump is set below the

kickoff point.

Rod Pump





®


Limitations<15%/100’ (Some installations allow up to 25%).

Pump can be set at 90°.

Rod Pump





®


DisadvantagesIncrease tubing/rod wear decreases run times.

Friction results in increased loads on sucker rods, polish rod and

pumping unit. Typically shorter run life on rod pump.

Use of Rod Rotator advised to

increase life of rods and tubing.





®

What causes Sand Problems?

Sand can come from the reservoir or a sand-Frac.

If sand is present from a sand-Frac, it is usually a

temporary problem that will clear itself as the well is

pumped.

If the sand is from the reservoir the problem will be

ongoing and special attention must be given to the

design of the pump and its material selection.

How do you Minimize





®

How do you MinimizeSand Problems?

Pressure-Actuated Plunger

Combo Plunger Actuated Plunger

Chrome Plated Grooved Plunger

Sand Hogg

3-Tube Pump

Type of plungers





®

Type of plungersfor Sand Problems?

Pin End

Plunger

Box End

Plunger

Grooved

Plunger

Monel Pin

EndPlunger

Pressure

ActuatedPlunger





®

Best Particulate Producers

Traveling Barrel Pump , Top Holddown Pump,

& Tubing Pump

Stroke Through Pump

Short Barrel, Long Plunger

Special Pumps

3 Tube Pump

Others

Bottom Discharge Valve, Top Seal Assembly,

& Plunger Wipers

Designs to Handle Solids





®

Special 3-Tube Pump

Efficient operation in extremely abrasive or

dirty production

Utilizes produced fluid as packing medium for

effective seal surface

Telescoping tubes give longer seal surfaceallowing for looser fit

Turbulence of fluid miniumizes the danger

of sanding in

Sandy Fluid/





®

Sandy Fluid/Pampa Pump

Traveling barrel pump designed for use in wells

where abrasive or dirty fluids are produced.

Pump has a smooth plunger which extends througha relatively short hardened-liner section

Due to length of Plunger, the ends do not enter theliner section at either the top or bottom of the stroke

Plunger is wiped clean on each stroke, and foreign

material (sand, etc) is not carried into the liner.

When Pump is shut down, the Traveling valve on

top of the pump serves as check valve.

Rod Pump





®

od u pTop Seals

Clutched

Top Seal

Fin

Top Seal

Rod Pump





®

pBottom Discharge Valve

Coupling

Ball and Seat

Body

Cage

Plug





®

Viscosity Problems

Viscosity problems are caused by wells which

produce heavy API oil.

If steam injection is not practiced, lifting fluidsto the surface would be difficult for the surface

and subsurface equipment to function properly.

Viscosity problems are best handled:

Heavy Oil Pump

Insert Anchors

Barrel Stabilizers





®

Insert Anchor

A production tool which provides a

trouble free method of anchoring

and packing-off a pump in wells

where a pump seating nipple has not

been provided.





®

Barrel Stabilizer

Used on long 1-1/4” Bore Pumps that are

operating inside 2-7/8 Tubing

Pumps have a tendency to lean to one side

of the tubing leading to uneven wear of

plunger and barrel.





®

Ball and Seat





®

-

1.0

2.0

3.0

4.0

5.0

6.0

Stainless Steel Alloy (Dumore) Tungsten Carbide Nickel Carbide

V a l u

e

-

1.0

2.0

3.0

4.0

5.0

6.0

Stainless Steel Alloy (Dumore) Tungsten Carbide Nickel Carbide

V a l u

e

Seat Values Comparison





®

Ball Values Comparison

-

10.0

20.0

30.0

40.0

50.0

60.0

Stainless

Steel

Alloy Ceramic Gold

Z Ball

Titanium

Carbide

Tungsten

Carbide

Nickel

Carbide

Ceramic Silicon

Nitride

V a l u e

-

10.0

20.0

30.0

40.0

50.0

60.0

Stainless

Steel

Alloy Ceramic Gold

Z Ball

Titanium

Carbide

Tungsten

Carbide

Nickel

Carbide

Ceramic Silicon

Nitride

V a l u

e

Relative Costs for Various





®

SRP Components

ABC Oil Company

0

1000

2000

3000

4000

5000

6000

7000

8000

Barrel Plunger Valve Rod SV Cage TV Cage SV Ball TV Ball SV Seat TV Seat Hold-down TV Seat

Plug

$ S p e

n t o n P u m p

P a r t s - 1 9 9 7

ABC Oil Company

0

1000

2000

3000

4000

5000

6000

7000

8000

Barrel Plunger Valve Rod SV Cage TV Cage SV Ball TV Ball SV Seat TV Seat Hold-down TV Seat

Plug

$ S p e

n t o n P u m p P a r t s - 1 9 9

7





®

Stretch in the Rod String





®

Troubleshooting

& Failure Analysis

TYPES OF PUMP FAILURE





®

FOR XYZ COMPANY

Tubing Failure

12%

Rod Failure

19%

Work Over

5%

Pump Failure

42%

Foreign

Material

Green

Pumps





®

FAILED PARTS IN XYZ FIELD

Barrels

35%

Plungers

17%

Balls

13%

Seats

11%

Valve Rod

4%

Cage

13%

Hold-down7%

®

TYPES OF BARRELSFAILED IN XYZ FIELD





®

FAILED IN XYZ FIELD

Brass Tri-Carb

0%

Steel Chrome75%

Tri-Carb

19%

Brass Chrome

6%

®

R f B l F il





®

Reasons for Barrel Failure

Corrosion64%

Bent9%

Hole

18%

Plunger Stuck

9%

®

S lit C





®

Split Cage

®

Standing Valve Cage





®

with Severe Corrosion

®

Pl D





®

Plunger illustrates

severe grooves causedfrom passage of sand

or iron sulfide

Plunger Damage

®

P t d T li V l C





Parted Traveling Valve Cage

®

Parted Standing Valve Cage





THREAD

PART

Parted Standing Valve Cage

Standing valve cage

parted at the pin endthat screws to barrel

®





TOP CAGESHOWSCORROSIONATTACK

®

Pitted Silicon Nitride Ball





Pitted Silicon Nitride Ball

®

Severely Pitted Ball





Severely Pitted Ball

®

Pitted and Non Pitted Ball





Pitted and Non-Pitted Ball

®

C k d S t





Cracked Seat

®





No-Go on SV

Mandrel

severely pitted

®





V-Rod Guide

PoundedSeverely

®





V-Rod Guide worn.

Showing signs of side loading

®





V-rod guide worn ( bottom view).Showing signs of side-loading

®

Worn & Parted Valve Rod





Wear Part

Worn & Parted Valve Rod

®





Pounded

Pull Tube Guide

®





Pounded

V-Rod

Guide

®

Elements thatInfluence Corrosion





Influence Corrosion

Hydrogen Sulfide - Sour (H2S)

Carbon Dioxide - Sweet (CO2)

Oxygen

Chlorides

Water Content

pH

Abrasion

®






H2S Service

Sour conditions exist when H2S is equal to

or greater than 0.35 Kpa (0.05 psi)

OxygenSevere corrosion can be expected if

conditions include 50 ppb dissolved oxygen

ChloridesPitting corrosion will occur if total dissolved

solids exceed 10,000 mg/L and/or if totalchlorides exceed 6,000 mg/L.

Influence Corrosion

®






Water Content

If water content is greater than 20%, fluid is in

water phase with oil droplets.

If water content is less than 20%, fluid is in oil

phase with water droplets. Use of an inhibitor isrecommended if the water content is greater

han 20%.

Influence Corrosion

®






pH

pH content at bottom hole level is frequently

lower (more acidic) than that measuredat surface.

After acidizing, the pH should be monitored toensure the fluid does not attack any chromeplate

that may be used in pump.

Influence Corrosion

®






Abrasion

Conditions are considered abrasive if solids

are greater than 100 ppm.

Abrasion refers not only to solid content but

also to corrosive by-products, e.g., iron sulfide

Influence Corrosion

®

Corrosion Identification - H2S





Corrosion Identification H2S

Pitting is random & scattered

Pits are steep walled

Edges flare out at surface

Black iron sulfide on surface

Hydrogen embrittlement causes breakfaces to appear brittle.

®

Corrosion Types - CO2





Corrosion Types CO2

Pitting is round based

Pits are steep walled

Edges appear sharp

Pits are filled with iron carbonate

Pits are interconnected in lines

CO2 gas in water forms carbonic acid,

which lowers pH of water

®

Mild Metal Loss Corrosion





Mild Metal Loss Corrosion

Water

- Water cut less than 25%

H2S

- Less than 10ppm

CO2

- Less than 250ppm

®

Moderate Metal Loss Corrosion





Moderate Metal Loss Corrosion

Water

- Water cut 25% to 75%

and/or H2S

- between 10 and 100 ppm

and/or CO2

- between 250 and 1500 ppm

®

Severe Metal Loss Corrosion



Severe Metal Loss Corrosion

Water

- Water cut more than 75%

and/or H2S

- greater than 100 ppm

and/or CO2

- Greater than 1500 ppm

Sucker Rod Pumps 2001 CD

Documents

Transcript of Sucker Rod Pumps 2001 CD