Packer.pdf

Packers and Liner Hangers

• Basic Overview • Applications and Selections of Packers • Setting Criteria and procedures

What is a Packer?

• A packer is a tool used to form an annular seal between two concentric strings of pipe or between the pipe and the wall of the open hole.

• A packer is usually set just above the producing zone to isolate the producing interval from the casing annulus or from producing zones elsewhere in the wellbore.

• Separates fluid types (or ownership), protects against pressures and corrosion.

Why are packers used?

• Tubing and packer used to isolate zone of interest - can be removed for repair.

• Packers act as downhole valve for press control. • Packer can be a temporary plug to seal off the

zone while work is done up the hole. • Subsurface safety valves used with packers for

downhole shut-in. • Focus flow • Isolate between zones

Lock Ring and Mandrel

Slips

Cone

Seal

Inner Mandrel

Packer Cutaway Drawing

Ability to effectively set a packer depends on having a clean, non corroded set point and reaching the set point without fouling the slips or failing other components.

As the packer sets, the inner mandrel moves up, driving the cone underneath the slips, pushing them into the casing wall. The sealing element is compressed & extruded to the casing wall.

Packers and Liner Hangers Mechanical isolation methods

Two examples:

1. An external casing packer (ECP) set to seal the annulus between the surface or protection string and the inner, production string

2. A conventional packer set near the end of the tubing, that isolates the inner annulus from the tubing.

Packer Considerations

• Force on an area

Remember, it’s a force balance. Area down =

casing ID - tube OD

Area up =

tube x-section +

casing ID - tube OD

Packer Types & Selection

Hydraulic Set

Wireline Set

Retrievable Permanent

Production Packers

Sealbore

Hydraulic

Multiport

Mechanical

Hydraulic Set

Wireline Set

Differential Set

Hydrostatic Set

Double Grip

Single Grip

ESP

RMC

Dual

Single

Hyd. Slips

Mech. Slips

Schlumberger

Specific Packer Examples

• Packer Examples – Retrievables – Seal bores – Inflatables – Wash Tools

Retrievable Packers

• Expected to be retrieved • More prone to leaks • Need an equalizing port • Release mechanism must be possible with

well design

Retrievable Packers

• Compact • Simple J slot control for set and release • Shear ring secondary release • Right-hand safety joint emergency release • Rocker type slips • Can be set shallow

Tension Set - Economical packer used in production, injection, zone isolation applications

Weatherford

Retrievable Production Packers

• Rotation set and release • Can be set with tension or compression • Tubing can be landed in tension, compression or neutral • Models rated up to 10,000 psi • Pressure equalization needed prior to upper slip release • Secondary shear release required

Mechanical - Used in production, injection, fracturing, zone isolation and remedial applicatuions

Weatherford

Retrievable Production Packers

• Compression set • RH rotation required to set, (LH option usually

available) • Available with or without Hydraulic hold down

buttons for differential pressure from below • By-pass needed for equalization of pressure, and for

running and retrieval without surging/swabbing the well.

Mechanical Used in production, stimulation and testing

Weatherford

Retrievable Packers

• Can act as a bridge plug prior to production • Connect to tubing via On/Off Tool with blanking plug • Tubing can be landed in tension, compression or neutral • Slips above and below the elements • Triple element pack off system • Pressures to 10,000 psi • Fluid bypass needed for pressure equalization • Retrieved on tubing • Secondary shear release needed

Wireline set - Used in production, injection, fracturing, zone isolation and remedial applications

where wireline setting is preferred

Weatherford

Seal Bore Packers

• Allow tubing movement; however: – Too much contraction can pull seals out of PBR – Seals can “bond” to the seal bore over long

time at higher temperatures – Debris on top of packer can stick assembly

Unprotected seals below the packer may allow seal swelling by gas and fluids, causing seals to roll off if the stinger is pulled out.

Deep Completions

• Most typical is permanent packer with a PBR (arrangement depends on personal preferences, individual well configurations and intended operations).

• Seal assembly length dependent not only on normal operations, but also fracturing, kill and expected workovers.

Seal Bore Packers

• High pressure & temperature ratings available

• Multiple packing elements available

• Short units are desirable for use in tight doglegs (>5o) and high (>8o/100ft) departure angles

• Ability to set on wireline or with a hydraulic setting tool

• Rotationally locked units needed for mill-ability

• Share Seal Assemblies with permanent seal bore packers • Critical metallurgical and seals (O-rings, etc) should be isolated

from wellbore fluids by main elements.

Weatherford

Retrievable Seal Bore Packer

• Hydraulic set version retrievable seal bore packer available for one-trip installations

• Seal assembly is run in place for one trip installation

• Available with large upper seal bore to maximize ID

• Rotationally locked components

One-trip applications

Weatherford

Permanent Seal Bore Packers

• Seals run in place for one trip setting

• A metal back-up system can be specified to casing ID to prevent element extrusion

• Elastomer and materials available for hostile environments

Used in one trip production applications

Weatherford


• Select seals for full range of expected temperatures, pressures, and fluids.

• A back-up system is need around the main seal to prevent seal extrusion at high temps and pressure.

• Examine slip design to help avoid premature setting during movement through viscous fluids, doglegs and rough treatment

Seal Bore Packers

Molded Seals: • Recommended in medium pressure

applications where seal movement out of the seal bore is anticipated.

Nitrile Seal or Viton Seal

Steel spacer

Seal spacer

End spacer

Nitrile Seal or Viton Seal

Middle spacer

MOLDED SEAL SINGLE UNIT

CHEVRON SEAL SINGLE UNIT

Chevron Seals: Used for higher pressure and

temperature applications.

Weatherford

Seal Bore Packer Accessories

• Tubing Anchor and Locator Assemblies • Seal Units and Spacer Tubes • Seal Bore and Mill-Out Extensions • Packer Couplings and Bottoms • Pump-out, Screw-out, and Knock-out Bottoms

Weatherford

Inflatable Packers and Plugs

• Reasons to run and inflatable. – Need to set beneath a restriction. – Need to set in open hole. – In non-standard casing. – Setting in multiple sizes of pipe on same run. – Where larger run-in and retrieval clearances are

needed. – Large diameter applications.

Inflatable Setting Considerations The inflatable packer offers a way to set a seal in a larger area below a restriction.

The quality of the seal depends on how much the packer must expand over initial diameter, the length of the slide (placement run), the differential pressure it must hold, what fluid is used for inflation and the conditions in the area in which it is set.

Holding ability of the inflatable is always suspect since it does not have conventional slips.

When deflating an inflatable packer, allow time (1 hr?) for relaxation of the elements. The elements never shrink back to initial diameter – allow about 30% increase in diameter for retrieval.

Baker

Inflatables rely on expansion of an inner rubber bag that pushes steel cables or slats against the wall of the pipe or the open hole. The only gripping ability is generated by the friction of the steel against the pipe or open hole. This is critically dependent on the inflation pressure and the exterior slat or cable design. For a permanent seal, place several bailers of cement on top of the inflatable.

• Heavy Duty reinforced casing cups

• Spacing between cups adjustable from 12” to any length by addition of standard tubing pup joints

• Large internal bypass

• Cup wear from casing burrs can be significant and may reduce seal, especially in long zones.

• The number of successful resets depends on casing conditions, pressures, slide length (running), temperature and deviation. Successful resets run from about 5 to over 20.

Used for selective acidizing of perforated intervals

Perforation Wash Tool

Weatherford

Packer Seals Packer Slips

Lawrence Ramnath - Trinidad

A hydraulic set packer. Note the lower slips set by movement of the mandrel and upper slips set by piston action.

Slips – Liner hanger

J-Slot on a liner hanger.

HES Schlumberger (Camco)

Packer Type

Weatherford Completion Systems (Bold Items are Preferred Products)

Baker

Halliburton Guiberson Solid head, Tension Set, Mechanical, Single Grip

PAD-1, PADL-1 AD-1 AL

RB R-4

Uni-Packer I SA-3 T Series

Compression Set, Mechanical, Single Grip

PR-3 Single Grip R-3 Single Grip Model G

R-4

Uni-Packer IV Uni-Packer II G-4

SR-2 U-3 CA-3, C Series

Compression Set, Double Grip Packer

PR-3 R-3 Double Grip MHS MH-2

Uni-Packer V SR-1

Neutral Set, Double Grip Packer QDG, QDH, Arrowset I-X (&10K), Ultra-Lok, Double Grip

Lockset, Max J-Lok, MS

WPL Perma-Lach

Uni-Packer VI G-6, G-16

SOT-1 KH

Hydraulic Set Retrievable

HRP, Hydrow-I, PFH FH, FHL, FHS Hydra-Pak HS, HS-S

RH PHL AHR

Uni-Packer VII G-77 RHS

Hydro-5 HRP

Dual Hydraulic Set Retrievable Hydrow IIA A-5 T-2 GT

RDH BHD

Uni-XXVII RHD

Hydro-10 HSD

Wireline Set Permanent

Arrowdrill B Model D F-1

AWB BWB AWS

G, GT H, HT

Model S

Wireline Set Permanent Double Bore

Arrowdrill DB DA, DAB FA, FAB

AWR G-1, GT-1 H-1, HT-1

Hydraulic Set Permanent

Arrowdrill BH SB-3 MHR PG PH

Model HS

Hydraulic Set Permanent Double Bore

Arrowdrill DBH SAB-3 MHR PG-1 PH-1

Model HSB

Retrievable Seal Bore Arrow-Pak

Retrieva-D, DB WS, WSB SC-1, SC-2

VTL (Versa-Trieve) G-10 M Omegatrieve Quantum

Hydraulic Set Retrievable Seal Bore

Hydrow-Pak SC-2PAH VHR (Versa-Trieve) RSB

HPHT Hydraulic Set Retrievable Hydrow-Pak HP-1AH, SC-2PAH HP/HT

HPHT (Versa-Trieve Retrievable)

Compression Set Service Packer CST, C5, H/D, MSG EA Retrievamatic RTTS Champ III, IV

HDCH-V Omegamatic

Compression Set Storm Packer CSTH, DLT Tension Set Service Packer

32A, Fullbore Tension C Fullbore BV Tension Packer R-104

Tubing Set Retrievable Bridge Plug

QDH w/ EQV, TSU G Lock-Set 3L RBP-VI P-1

Wireline Set Retrievable Bridge Plugs

WRP, CE, CE2

Permanent Bridge Plugs/Cement Retainer

PCR, Plugwell, PBP

Mercury N, K-1 EZSV, EZ Drill EZ Drill SVB Fas-Drill, HCS

Type A Quik-Drill

Packer Comparisons - from Weatherford

Packer specifics from Baker

Monobore: mixed grades, same weight

Mixed grades and weights

Mixed weights, same grade

Casing Design Options – think about running and setting packers.

Small diameters at the top of the well may prevent entry by some packers.

Production Packers

• Purposes – Casing protection from fluids or pressures – Separation of zones – Subsurface pressure and fluid control – Artificial lift support equipment


• Seal stability – pressure, temperature, fluid reaction

• Force balance and direction – slip direction

• resists upward motion, downward or both ways) • tension, compression, mechanical or hydraulic set

Allowing Tubular Movement

• Usually incorporate a PBR - polished bore receptacle, for a “stinger” or seal assembly to slide through.

• Shoulder out on the PBR - if it can move, it will eventually leak.

• Seals must match operating extremes as well as general conditions.

Seal Bore Packer to Tubing Connections

Seal Bore Extensions (SBE)

Polished Bore Receptacle (PBR)

Tubing Sealbore Receptacle (TSR)

Seal Assembly Locator Types

Locator Anchor Latch

Snap Latch

A “stinger” or seal assembly that is run on the end of tubing and “stings” into the polished bore receptacle (PBR) of the packer.

Stinger Seal Materials

• Single or mixture of elastomers • seal design variance • seals usually protect the slips from

corrosive fluids.

Tubing Seal Stability Seal Material oil brine H2S CO2 Butyl Rubber 4 1 1 2 Flurocarbon 1 1 4 2 Nitrile 1 1 4 1 Fluro-silicone 2 1 3 2 1=good, 2=fair, 3=doubtful, 4= unsatisfactory Much larger data base available online.

A-Satisfactory B - Little or no effect C - Swells D - Attacks NR - Not recommended NT - Not tested

NOTE: (1) This information provides general guidelines for the selection of seal materials and is provided for informational purposes only. Seal Specialists with Halliburton Energy Services should be consulted for the actual selection of seals for use in specific applications. Halliburton Energy Services will not be liable for any damage resulting from the use of this information without consultation with Halliburton Seal Specialists.

(2) Contact Technical Services at Halliburton Energy Services - Dallas for service temperature and pressure. (3) Back-Up Rings must be used. (4) There could be a slight variation in both temperature and pressure rating depending on specific equipment and seal designs.

Halliburton Energy Services General Guidelines For Seals (1)

PEEK (2), (4) Ryton Fluorel (3) Aflas (3) Chemraz (3) Viton (3) Neoprene (3) Nitrile (3) Kalrez (3) Teflon (3)

Filled Unfilled Unfilled Filled Unfilled Filled Filled Filled Filled Unfilled

350 350 450 350 325 300 275 450 400 325 (177) (177) (232) (177) (163) (149) (135) (232) (204) (163)

Above Below 15,000 10,000 15,000 5000 5000 5000 3000 15,000 15,000 5000 (103) (68.9) (103) (34.4) (34.4) (34.4) (20.7) (103) (103) (34.4)

A A A A A B B NR NR A A A

A A B B A B B C A A A A

A A A A A A A B B A A A

A A A A A A A B C A A A A

A A A C A A A NR NR A A A

A A C B A C C B A A A A

A A A A A A A NR NR A A A

A A NR A A NR NR NR B A A A

A A A A A A A C A B A A

A A NR A A NR NR NR NR NR B B

Diesel A A A NR A A A B B A A A

(2), (4) Compound

Service °F (°C)

Pressure psi (MPa )

Environments H 2 S

CO 2

CH 4 (Methane)

Hydrocarbons (Sweet Crude)

Xylene

Alcohols

Zinc Bromide

Inhibitors

Salt Water

Steam

(2), (4)

Halliburton Energy Services General Guidelines For V-Packing (1)

Packer Element Selection Chart

NITRILE ELEMENTS W/BONDED GARTER SPRINGS

NITRILE ELEMENTS W/TEFLON AND METAL BACKUPS

AFLAS ELEMENTS W/STANDARD METAL BACKUPS

AFLAS ELEMENTS W/TEFLON AND GRAFOIL WIREMESH AND METAL BACKUPS

CHECK WITH YOUR HALLIBURTON REPRESENTIVE FOR SPECIAL APPLICATIONS

TEMP GREATER THAN 450°F

FLUOREL ELEMENTS W/BONDED GARTER SPRINGS

AFLAS ELEMENTS W/BONDED GARTER SPRINGS


EPDM ELEMENTS WITH BACKUPS


Y

Y

Y

Y

Y

Y

Y

Y

N

N

N

N

N

N

N

N

START STEAM/THERMAL

APPLICATION W/NO HYDROCARBON FLUIDS

NITRILE ELEMENTS W/STANDARD METAL BACKUPS

Y

Y

Y Y

Y

N

N N N

N

Y

PERMANENT PACKER DESIGN

PACKER IN OIL BASE MUD OVER 24 HOURS BEFORE

SET?

PACKER IN BROMIDE

COMPLETION FLUIDS MORE THAN 36 HOURS BEFORE

SET?

TEMP 40°F TO 325°F


TEMP 100°F TO

400°F

TEMP 100°F TO

450°F

RETRIEVABLE PACKER DESIGN


TEMP 100°F TO

400°F


TEMP LESS THAN 550°F


PACKER ELEMENTS

EXPOSED TO AMINE CORROSION INHIBITORS?

PACKER EXPOSED TO BROMIDES?

TEMP 40°F TO

400°F

N

N

(1)

NOTE: (1) This information provides general guidelines for the selection of seal materials and is provided for informational purposes only. Seal Specialists with Halliburton Energy Services should be consulted for the actual selection of seals for use in specific applications. Halliburton Energy Services will not be liable for any damage resulting from the use of this information without consultation with Halliburton Seal Specialists.

Forces and Length Changes

• Temperature:

• Piston Effect:

• Ballooning

• Buckling: A tubing movement calculator is the best method, but the difficulty is in knowing accurate temperature changes and pressure changes.

Is it Force or Length Change?

• No packer - tube suspended and not touching well bottom - length change

• Tube landed on packer - incr. force with increasing temp, shortening possible with cooling after downward force absorbed.

• Latched tubing - no movement, only forces • Tube stung through - length changes unless

locator is shouldered • If tube set in tension or compression, effects of

temp depends on initial force and DT

Temperature, length change

DL = CLDT Where: DL = length change C = expansion coeff. for steel = 6.9x10-6/oF L = length of tubing DT = average temp change, oF

Temperature, Force change

• F = 207 DTa As

• Where: F = temperature induced force DTa = change in average temp of tubing, oF

As = cross sectional area of tubing

What Temperature is Average?

• If no circulation - assume all tubing is same as injected fluid temperature. (worst case)

• If circulation is allowed, all but top few joints will be unaffected by injected fluid temp. - no temp change. (v. slight effect)

• Injected fluid temp? - source dependent! • In dual packer - treat each packer as a

separate calculation. Bottom string first.

Temperatures in the Well? Circulating or High Rate Injection?

0

2000

4000

6000

8000

10000

12000

14000

16000

18000

30 40 50 60 70 80 90 100 110 120 130

Tubing

Tbg Fluid

Casing 1

Undisturbed

Circulation pump rate = 8-BPM

BHST= 122*F

BHCT= 98*F

0

2000

4000

6000

8000

10000

12000

14000

16000

18000

30 40 50 60 70 80 90 100 110 120 130

Undisturbed

Tbg Fluid

Tubing

Casing 1

Frac job pump rate = 35-BPM

BHST= 125*F

BHTT= 86*F

Problem

• Temperature Effect Only – Is a 6 ft seal assembly (effective seal length)

enough to keep the tubing from unseating when the average temperature falls from 210oF to 100oF during a Frac job? L = 8000 ft.

– Assume locator is shouldered but no downward force is applied.

Problem

• Temperature Effect Only DL = 6.9 x 10-6 x 8000 x 110 DL = 6.1 ft unseats!

What if 15,000 lb downward force were applied to the tubing before the temperature change?

How much temperature increase is spent lifting the 15,000 lb?

• F = 207 x DT2 x 2.59 in2

DT2 = 15000 / (207 x 2.59) = 28oF Then: 110 - 28 = 82oF DL = 6.9 x 10-6 x 8000 x 82 = 4.52 ft

What about those other factors?

• Buckling, Piston, Ballooning - Use a computer program - better yet, use a couple of them (different assumptions).

Temperature Extremes

• The extremes of temperature change (higher than normal) are usually seen in operations involving cyclic thermal processes.

• Lower than normal temperatures may be seen in permafrost, sea floor penetrating and CO2 operations.

Setting the Packer

• Chances of setting packers go up sharply when a casing scraper is run. (Remember the burrs on the perforations?)

• The quantity of debris turned loose from the casing wall is often severe! (Tens of pounds worth!) Watch the formation damage.

Packer Set Point Requirements • Avoid setting packer in the

same joint where previous packers have been set.

• Avoid doglegs, fault locations or high earth stress zones

• Adequate cement and bond required behind pipe at packer set point

• Caliper casing above and through the packer set point

• Clearance between packer and casing at set point is within rated range of packer

• Avoid zones of high corrosion, either internal or external.

• Remove burrs from pipe above packer set point

• Remove debris (dope, mill scale, mud, cement, etc.) on casing wall (fills slip teeth)

• Well pressures are within range of packer at set point

• Pipe alloy compatible with setting slips (hardness of casing relative to packer slips)

• Slip design & contact area acceptable for slip holding

• Weight applied to packer can be transferred to formation

Information Required Before Setting Packer or Plug

• Wellbore drawing with all diameters • Last TD tag – rerun? • Doglegs and deviations • Viscosity of fluid in wellbore

– Calculate running speed vs. surge/swab. • Copy of reference logs • Where have other packers been set (avoid that joint) • Set point requirements • How can it be equalized if it has to be pulled?

Job Checks

• Measurements from CCL to a packer reference point.

• Run in hole at about 100 fpm, slowing at ID restrictions.

• Using CCL/GR, log up and correlate depths • Set packer – look for line weight reduction • Disconnect and log up a few collars (may

be slightly off depth after disconnecting).

Job Checks

• Drop back and gently tag packer with setting tool to confirm depth.

• Log back up a few collars.

Packer Setting Guidelines

• Drift • Scraping • Casing Support

Drift the Casing

• Casing ID requirements above the set point • Casing ID requirements below the set point • Check the drift to deepest point with drift of

diameter and length of packer.

Clean/Scrape The Casing?

• Removal of perforation burrs minimizes elastomer seal damage

• Removal of cement, mud, pipe dope and mill scale minimize debris that can fill the slips.

• Scraping casing can increase packer setting success

• Scraping casing can also produce some severe formation damage if perforations are not protected.

Casing Scraper – Designed to knock off perforation burrs, lips in tubing pins, cement and mud sheaths, scale, etc.

It cleans the pipe before setting a packer or plug.

The debris it turns loose from the pipe may damage the formation unless the pay is protected by a LCM or plug.

Effect of Scraping or Milling Adjacent to Open Perforations

-60-50-40-30-20-10

01020

1 2

% C

hang

e in

PI

Short Term PI ChangeLong Term PI Change

Perfs not protected by LCM prior to scraping

Perfs protected by LCM

SPE 26042

One very detrimental action was running a scraper prior to packer setting. The scraping and surging drives debris into unprotected perfs.

Typical Completions

• Single and Dual Zone Completion Types

Single Zone Completion (Mechanical Packer)

Retrievable Packer

On-Off Sealing Connector

Packer isolates casing from production • Provides means of well control • Protects casing above packer from corrosion • Anchors tubing string

• Tension Set • Compression set • Wireline Set • Large Variety of

accessories available

Weatherford

Single Zone Completion (Hydraulic Set Packer)

• Permits Packer setting without tubing manipulation

–Common in offshore applications where SCSSV control lines prevent tubing rotation

• Allows one-trip installation • With sliding sleeve, allows packer fluid change-

out after wellhead is flanged (sliding sleeve not recommended in every case).

• Requires tubing plugging device to set packer –Wireline plug - preferred –Drop Ball Seat – debris problem?

Flow Coupling

Sliding Sleeve

Flow Coupling

Hydrostatic Retrievable Packer

Flow Coupling

Seating Nipple

Spacer Tube

Ball Activated Pressure SubPerforated Spacer TubeNo-Go Seating Nipple

Wireline Re-Entry Guide

Weatherford

Single Zone Completion (Seal Bore Packers)

• Dependable • Low failure frequency • Generally permit larger flow ID’s • Available as Permanent or Retrievable • Production string may be anchored or floating,

depending on tubing movement requirements (anchored or shouldered is highly recommended)

• Packer may be plugged, can be used as temporary or permanent bridge plug

• Permanent packers removed by milling operations • Retrievable Seal Bore Packers are removed in

separate trip with retrieval tool – provided seals will release.

Annulus Activated, Block and Kill Valve

Sliding Sleeve

Seal Bore Packer

Mill-Out Extension

Crossover Sub

Flow Coupling

Seating NippleSpacer TubeFlow Coupling

No-Go Seating NipplePerforated Spacer TubeCrossover SubSeating NippleWireline Re-Entry Guide

Weatherford

Single Zone Completion (Seal Bore Packers w/Locator Seal Assy.)

• Locator unit atop Seal Bore Extension allows tubing movement from press and temp changes: – Frac or Acid Stimulation – Production extremes and shut-in

• Seals available to match environment: – Temperature Range – Pressure Conditions – Fluid Environment

• Works well with tubing conveyed perforating (TCP)

Sliding Sleeve

Flow CouplingLocator Seal Assembly

Seal Bore Packer

Seal Spacer Tube

Seal Bore Extension

Tubing Seal Nipples

Production Tube

Spacer Tube

Flow Coupling

Seating Nipple

Perforated Spacer Tube

No-Go Seating Nipple

Weatherford

Single Zone Completion (Polished Bore Receptacle (PBR))

• Seal Bore Packer with large upper bore permits maximum flow area.

• PBR above packer accommodates tubing trip/movement – Shear release locator allows one-trip

installation with Hydraulic set packer – Large ID suitable for Thru-Tubing

perforating

Locator Seal Assembly

Retrievable Packer Bore Receptacle

Anchor Tubing Seal Nipple

Hydraulic Set Seal Bore Packer

Mill-Out ExtensionCrossover Sub

Shear-Out Ball Seat Sub

Weatherford

Single Zone Completion (Stacked Selective Completion)

• Permanent packers are stacked for multiple zone completion – Zones are selective flowed or shut-in by

sliding sleeves or ported profiles and plugs

– Tubing may be anchored or floating

– Blast joints are placed across production interval to reduce flow-cutting of production lines

• This type of completion design often has severe problems with leaking sleeves and corroded/eroded tubing in the straddled zone.

Flow Coupling

Sliding Sleeve

Seal Bore Packer

Seal Bore Extension

Tubing Seal Nipples

Flow CouplingSeating Nipple

Blast JointPolished Nipple

Flow CouplingSliding Sleeve

Seal Bore Packer

Seal Bore ExtensionSeal Spacer Tube

Tubing Seal Nipples

Spacer Tube

No-Go Seating NippleProduction Tube

Weatherford

Single Zone Completion (Standard Dual Completion)

• Permits independent production of each zone

• Flanged-up completion for safety

• Fully retrievable completion (both packers) for remedial access

• Or, the bottom packer may be a permanent packer which serves as a locator for spacing out the completion

Flow CouplingsSeating NipplesFlow Couplings

Flow Coupling

Flow Coupling

Sliding Sleeve

Short String Seal NippleDual Hydraulic Retrievable Packer

Seating NippleFlow CouplingBall Activated Pressure Sub

Ball Activated Pressure Sub





Pinned Collar

Seating NippleBlast JointPolished Nipple

Sliding Sleeve

Hydraulic Retrievable Packer

Seating Nipple

Wireline Re-Entry Guide

Weatherford

Packer.pdf

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