DLT PACKER V-III UNLOADEV-III UNLOADERR STORM...

Weatherford Completion Systems 2000United Kingdom Address: Weatherford House • Lawson Road • Dyce • Aberdeen • Scotland • AB21 0GL • Phone: +44 (0)1224 770123 • Fax: +44 (0)1224 771309

DLT PACKERDLT PACKER

V-III UNLOADERV-III UNLOADER

STORM VALVESTORM VALVE

PRODUCTINFORMATION

SERVICE TOOLS

DLT RETRIEVABLE PACKERThe DLT Retrievable Packer is a compression set packer with hydraulic hold down that isdesigned to provide an extra measure of dependability for rugged service. The hydraulicactuated upper slips provide more than the usual surface area to assure the packer will notmove up the hole, The DLT is ideally suited for high pressure, high temperature service work.

Features:• Positive rotational locks on all internal connections which allow for extreme values of

torque (left or right hand) to be transmitted through the packer.• Back-up rings on all the o-rings which provide more reliable sealing at high temperature

and pressure.• Extra long top and bottom subs which allow for hydraulic tong make up and break-out.• Range of elastomers and rubber goods to suit a wide variety of well conditions.• 10,000 psi differential *

SETTING PROCEDURERun the DLT to setting depth in conjunction with a Type ‘V-III’ Unloader. The Unloader shouldremain open while running in. Pick up the tubing and rotate it 1/4 turn to the right at the packer.Slack off weight on the packer to set the slips and compress the packing elements. Release thetorque after slacking off 6” to allow the unloader to close and lock. The set down weight mustremain on the packer throughout well operation.

RELEASING PROCEDURERotate the tubing 1/4 turn to the right and pick up on the tubing to open the unloader. Allow timefor the tubing and casing pressures to equalise. Continued upward movement of the tubingrelaxes the packing elements, unsets the slips, and automatically re-jays the packer. The toolmay now be moved and reset or pulled from the well.

DLT SPECIFICATION GUIDECASING PACKER

O.D.in/

WEIGHT(#/ft)

PRODUCT NUMBER

11.6 – 13.5 688-46-0004 1/2”

15.1 – 16.9 688-45-00011.5 – 15.0 688-50-000

515.0 – 18.0 688-51-000

5 1/2 688-55B-00017.0 – 23.0

688-73A-00126.0 – 32.0 688-73B-00132.0 – 38.0 688-73C-001

7

38.0 – 46.4 688-73D-00132.3 – 43.5 688-96-00043.5 – 53.5 688-95-0009 5/858.4 – 59.4 688-94-00051.0 – 55.5 688-10A-00060.7 – 65.7 688-10B-00010 3/471.1 – 73.2 688-10C-000

11 3/4 60.0 – 71.0 688-11B-00013 3/8 48.0 – 77.0 688-13-000

ADDITIONAL SIZES AVAILABLE UPON REQUEST

* 13 3/8” DLT – 8000 psi differential

DLT

Weatherford Completion Systems 2000

ELEMENT SYSTEM O-RINGS TEMP. RANGE H2S CO2 CHEMICALS

80-60-80(Nitrile) Nitrile 60-200 deg F Poor (1-5%) Good (25%) -

90-70-90(Nitrile) Nitrile 100-275 deg F Poor (1-5%) Good (25%) -

90-80-90(Nitrile) Viton 250-325 deg F Poor (1-5%) Good (25%) -

95-90-95(HSN) Aflas Max 365 deg F Good Good -

95(HSN)-90(Fluorel)-95(HSN) Aflas Max 400 deg F Fair - Good Fair - Good -

90-70-90(Fluorel) Aflas Max 350 deg F Good (5-15%) Fair (15%) Zinc BromideCalcium Bromide

90(Fluorel)-80(Aflas)-90(Fluorel) Aflas Max 350 deg F Good - Excellent Good - Excellent Zinc BromideCalcium Bromide

90-80-90(Aflas) Aflas Max 400 deg F Excellent Excellent Zinc BromideCalcium BromideCesium Formate

Problems: Nitrile / HSN : Organic SolventsSome Oils

Fluorel : FormulationSome Gases

Aflas : Low Temperatures (

DLT RETRIEVABLE PACKERMINIMUM SETTING WEIGHTS FOR DLT PACKERS

MINIMUM SETTING WEIGHTS FOR DLT PACKERS

SIZE(in)

MIN. WEIGHTREQUIRED AT

PACKER(lbs)

HANG-OFFWEIGHT

(lbs)

MAX. TORQUE TRANSMITTEDTHROUGH TOOL

(lbs)

MAX. WORKINGDIFFERENTIAL PRESSURE

(psi)

5 10,000 90,000 10,000 10,000

5 1/2 15,000 122,000 10,000 10,000

7 14,000 195,000 20,000 10,000

9 5/8 25,000 375,000 20,000 10,000

10 3/4 35,000 460,000 20,000 10,000

11 3/4 35,000 460,000 20,000 10,000

13 3/8 35,000 460,000 20,000 8,000

Note: The above pressure ratings should be cross checked against the packer operating envelopes which show the maximum allowablepressure when the packer is subjected to axial loading. The lower of the two figures should be used for job design.

For example, the performance envelopes show that a 10 3/4” DLT packer with a hang off weight of 460,000 lbs. can withstand 7500 psidifferential collapse pressure and 18,472 psi differential burst pressure. However, the above table shows a maximum working differentialof 10,000 psi. Therefore the maximum differential burst pressure is 10,000 psi and the maximum differential collapse pressure is 7,500psi.


SERVICE TOOLS

The V-III Unloader is designed as a high pressure accessory for the C/5, DC-5 and DLT packers. The unloader is run above the packer inthe open position. After the packer is run to setting depth, the procedures required to set the packer will automatically close the V-IIIUnloader. The standard V-III slot locks in both the open and closed positions. With the packer set and the unloader closed, well operationmay now proceed. When run above a DLT or other compression set packer, the V-III Unloader is opened by rotating the tubing 1/4 turn andthen picking up, (standard slot is right hand close, right hand open) After opening the unloader, allow differential pressure to equalise beforereleasing the packer below.

NOTE: The J-slot in the V-III Unloader is available in various configurations and should be compatible with the packer it is run with.

When running the V-III Unloader, always match nominal tubing size of unloader to the size of tubing run above the V-III Unloader andPacker.

V-III UNLOADER SPECIFICATION GUIDE

Nominal TubingSize

MAX. O.D. OFTOOL

MIN. I.D. OFTOOL

(in/mm) (in/mm) (in/mm)

TUBINGTHREAD

BASEPRODUCTNUMBER

1.75044,45

2 3/8 I.F. 527-202 3/8

3.50088,90 2.000

50,802 3/8 EU 8RD 529-20

2 7/8 I.F. 527-252 7/8

3.75095,25

2.50063,50

2 7/8 EU 8RD 529-25

3 1/24.500114,30

2.50063,50

3 1/2 I.F. 527-35

4 1/25.500139,70

2.68868,28

4 1/2 I.F. 527-45

ADDITIONAL SIZES AVAILABLE ON REQUEST

SERVICE TOOL SPECIFICATIONS FOR V-III UNLOADER

TOOL TYPEMAXIMUM

TENSILE LOAD(lbs)

MAXIMUM J-PIN WORKINGLOAD(lbs)

MAXIMUM WORKINGDIFFERENTIAL PRESSURE

(psi)

3 1/2” V-III UNLOADER 246,800 110,000 10,000

4 1/2” V-III UNLOADER 300,000 150,000 10,000

V-III COMPRESSION UNLOADER


SERVICE TOOLS

The Storm Valve is normally run above a compression set packer similar to a C/5, DC-5 and DLT packers. The Storm Valve providesmeans of disconnecting the drillpipe or tubing close to the surface without tripping the entire string. It is useful in situations where the rigmust be abandoned quickly. The Storm Valve remains closed, providing a secure seal until the drillpipe or tubing is re-connected

OPERATIONNormal well conditions will allow ample drill pipe to be run below the storm packer for proper weight and for proper well circulation. If thedrill pipe weight is less than 20,000 #, drill collars should be run below the tool for weight.

MAKE-UP (Recommended)After the Storm Packer has been set in the slips on its pick-up joint, tong up the lower half of the on/off tool making sure all breaks are tongtight and lock screws are secure. Hand make-up the top back-off sub on the drill pipe. Pick up on joint or stand and stab into the matingparts. Hand rotate twenty (20) rounds to the right. Tighten drill pipe connection holding back-ups on the top connector. Remove tongs andcontinue hand make-up of the back-off sub and tighten as you would any safety joint. Check the left hand break out several times, assuringproper torque.

CAUTION: DO NOT LIFT DRILL STRING UNTIL BACK-OUT THREADS ARE FULLY ENGAGED

SET AND BACK-OUT PROCEDUREAfter reaching setting depth, rotate and set storm packer lowering all weight on tool. Maintain a zero (0) weight and rotate the back-out sub fifteen (15)rounds to the left. At this point the valve is closed and threads are still engaged. Pressure may now be applied to assure valve is operational. Test only to1/2 the pressure required to shear pump out plug. Bleed to zero (0). An additional twelve (12) rounds will totally release from tool.

RE-CONNECTLower the drill pipe slowly and tag the top of the valve with a maximum of 1,000#. During re-connect, be prepared to handle pressure from the drill pipe andcasing side. With 1,000# ê or less set on the valve, rotate two (2) rounds to the right and pull 2,000# é to assure threads are engaged. Slack down tozero (0) and rotate an additional eight (8) rounds. At this point the valve the closed and in a position to pump out the pre-loaded plug. This procedure isrecommended if extended circulation periods at rates of 10 BPM or greater are needed. If pump out plug is not to be sheared, a total of twenty-seven (27)rounds to the right should be applied. This will open valve fully for pumping. A maximum rate of nine (9) barrels per minute is recommended with plug inplace.

STORM VALVE SPECIFICATION GUIDE

SIZEMAX. O.D. OF

TOOL

(in) (in)

THREAD CONNECTIONBOX UP / PIN DOWN

BASEPRODUCTNUMBER

4 3/4 5.469 3 1/2 I.F. 682-10

6 1/8 7.900 4 1/2 I.F. 682-20

SERVICE TOOL SPECIFICATIONS FOR V-III UNLOADER & STORM VALVE

TOOL TYPEMAXIMUM

TENSILE LOAD(lbs)

MAXIMUM J-PIN WORKINGLOAD(lbs)

MAXIMUM WORKINGDIFFERENTIAL PRESSURE

(psi)

4 3/4” STORM VALVE 315,000 N/A 6,000*

6 1/8” STORM VALVE 363,750 N/A 6,000*

* Dependant on shear pin values

STORM VALVE


SPECIFICATION GUIDE

4 3/4” STORM VALVE SPECIFICATION GUIDE

SIZE(in/)

MAX. O.D. OFTOOL

(in/)


BASE PRODUCT NUMBER

4 3/4 5.469 3 1/2 I.F. 682-10

4 3/4” STORM VALVE OPTIONSPART NUMBER O.D. (in)

682-65D-830 4.950OPTIONAL GAUGE RING

682-73D-830 5.469

6 1/8” STORM VALVE SPECIFICATION GUIDE

SIZE(in)

MAX. O.D. OFTOOL

(in)


BASE PRODUCT NUMBER

6 1/8 7.900 4 1/2 I.F. 682-20

6 1/8” STORM VALVE OPTIONSPART NUMBER O.D. (in)

682-95-830 7.900OPTIONAL GAUGE RING

682-13-830 11.000

PART NUMBER SHEAR (psi)

682-20-910 1500OPTIONAL SHEAR PINS

682-20-901 6000

STORM VALVE


The performance envelopes produced by Weatherford Completion Services are intended to serve as a guideline forsafe, reliable performance. Operation of Weatherford equipment in environments that are within the defined envelopeis considered to be recommended service. Operation of the equipment outside the defined envelope is notrecommended without first seeking expert advice from Weatherford personnel.

The envelopes are produced by first analysing the product and identifying the weakest metallic component. Thismaterial cross section of the weakest component is then entered into the envelope program. The results of theprogram are printed in a chart form that is easy to use. The effect of combined loading, for example, tension andcollapse pressure, is taken into account by the slope of the border of the envelope.

The equations used for calculation are taken from API Bulletin 5C3. The results from these calculations represent aconservative estimation of the strengths of the components. This conservative view is intentionally devised to keepthe operator out of trouble. If a specific job requires operation of the equipment outside the envelope, Weatherfordtechnical personnel will evaluate the situation and make necessary recommendations.

It is important to note that these performance envelopes are representative of individual metallic strengths whensubjected to loads. These components are listed in the information above the chart. The envelopes do notnecessarily represent the entire product performance. In many of our products, the elastomers, however, are notconsidered in these performance envelopes.

With proper understanding, these envelopes can be a very useful tool in predicting safe product operation. It isalways recommended, however, that the operator asks questions any time situations arise when there is not a clearunderstanding of the product performance capabilities.

The information contained herein shall be considered the property of WeatherfordCompletion Systems, and the recipient agrees not to disclose the said information without

written consent.

DLT, V-III UNLOADER & STORM VALVESERVICE TOOLS

PERFORMANCE ENVELOPES UNDER BI-AXIAL LOADING


20000

10000

15000

-10000

-15000

5000

-5000

0

50000 100000 1500000 200000-50000-100000-150000-200000

-20000

Internal Yield13,568

Tension141,166

Collapse12,800

Compression141,166

Identification:Project: 5” DLT Packer Part No.: 688-50-210Critical component: MandrelDescription: Mandrel Strength – tubing open

Dimensional data:Minimum O.D.: 2.497 in. Area: 1.283 in.Maximum I.D.: 2.145 in. Minimum Wall: 0.176 in.Material Yield: 110,000 psi D/t: 14.188

Performance Envelope:Internal Yield (Py): 13,568 psi If tubing plugged:Collapse (Pc): 12,800 psi (Py) = 10,641Tensile pipe body (Ty): 141,166 lbs (Pc) = 7,479

-250000 250000

DLT RETRIEVABLE PACKER


20000

10000

15000

-10000

-15000

5000

-5000

0

100000 200000 300000 400000-100000-200000-300000-400000

-20000


Tension295,907

Collapse11,056

Compression295,907

Identification:Project: 7” DLT Packer Part No.: 688-73D-210Critical component: MandrelDescription: Mandrel Strength – tubing open


Performance Envelope:Internal Yield (Py): 12,610 psi If tubing plugged:Collapse (Pc): 11,056 psi Same Pressure asTensile pipe body (Ty): 295,907 lbs Open Tubing

-500000 500000



10000

-10000

-15000

5000

-5000

0

100000 200000 300000 400000-100000-200000-300000-400000

-20000


Tension451,868

Compression451,868

Identification:Project: 9 5/8” DLT Packer Part No.: 688-95-210Critical component: MandrelDescription: Mandrel Strength – tubing open


Performance Envelope:Internal Yield (Py): 13,185 psi If tubing plugged:Collapse (Pc): 9,913 psi (Py) = 10,278 psiTensile pipe body (Ty): 451,868 lbs (Pc) = 6,820 psi

-500000 500000

Collapse9,913


20000

15000


20000

10000

15000

-10000

-15000

5000

-5000

0

500000 1000000 1500000 2000000-500000-1000000-1500000-2000000

-20000


Tension1,624,444

Collapse14,272

Compression1,624,444

Identification:Project: 13 3/8” DLT Packer Part No.: 688-13-210Critical component: MandrelDescription: Mandrel Strength – tubing open


Performance Envelope:Internal Yield (Py): 14,379 psi If tubing plugged:Collapse (Pc): 14,272 psi (Py) = 10,844Tensile pipe body (Ty): 1,624,444 lbs (Pc) = 7,849

-2500000 2500000



40000

20000

30000

-20000

-30000

10000

-10000

0

50000 100000 1500000 200000-50000-100000-150000-200000

-40000


Tension164,353

Collapse20,853

Compression164,353

Identification:Project: 2 3/8” V-III Unloader Part No.: 527-20-210Critical component: MandrelDescription: Mandrel Strength


Performance Envelope:Internal Yield (Py): 20,410 psi J-Pin Working Load is 75,000 lbs.Collapse (Pc): 20,853 psi Tailpipe limit 125,000 lbs.Tensile pipe body (Ty): 164,353 lbs

-250000 250000



40000

20000

30000

-20000

-30000

10000

-10000

0

100000 200000 3000000 400000-100000-200000-300000-400000

-40000


Tension402,463

Collapse21,414

Compression402,463




-500000 500000



20000

10000

15000

-10000

-15000

5000

-5000

0

200000 400000 600000 800000-200000-400000-600000-800000

-20000


Tension616,208

Collapse17,460

Compression616,208

Identification:Project: 4 3/4” Storm Valve Part No.: 682-10-635Critical component: BodyDescription: Body Strength


Performance Envelope:Internal Yield (Py): 16,732 psi The plug is pumpedCollapse (Pc): 17,460 psi out in this conditionTensile pipe body (Ty): 616,208 lbs

-1000000 1000000

STORM VALVE


40000

20000

30000

-20000

-30000

10000

-10000

0

200000 400000 600000 800000-200000-400000-600000-800000

-40000


Tension616,208

Collapse22,897

Compression616,208

Identification:Project: 6 1/8” Storm Valve Part No.: 682-20-610Critical component: Seal MandrelDescription: Mandrel Strength


Performance Envelope:Internal Yield (Py): 22,715 psi The plug is pumpedCollapse (Pc): 22,897 psi out in this conditionTensile pipe body (Ty): 873,438 lbs

-1000000 1000000

STORM VALVE



INDEX

SECTION A : Running for well suspension

SECTION B : Running for casing test

SECTION C : Inflow test liner lap with un-perforated liner

SECTION D : Inflow test with open perforations

APPENDIX 1 : DLT Packer calculations. Buoyancy / deviation chart

APPENDIX 2 : 1. Pre-job meeting data2. Packer function test

APPENDIX 3 : 1. Tool joint torque requirements2. Trouble shooting

SERVICE TOOLS

DLT RETRIEVABLE PACKERPROCEDURES

SECTION A: DLT Packer: Running for well suspension

1. Perform Pre-job checks, etc:

1.1 See Appendix 2.1

1.2 Was a casing scraper run? if not then recommend one. Also, if possible the hole should be circulatedclean prior to running the tools and/or spot a hi-vis pill over the packer especially if it is to be left in thehole for a long period of time.

1.3 Make a fishing diagram of all tools to run down hole.

1.4 Perform all necessary calculation prior to job.

2. RIH and set DLT Packer:

2.1 Make up and RIH with drill collars/pipe to give suitable buoyancy compensated weight below the toolto keep the packer set.

This drill pipe/collar string will be run below the DLT Packer. The total weight/length of drillpipe/collars run will depend upon the setting weight required - see section 5, for minimum weights seton each tool.

2.2 Pick up DLT Packer with 6-1/8” Storm Valve and run in hole. Ensure correct torque is applied and theStorm Valve back-off sub is only hand right prior to running in hole. (Note: When running 7” tools andsmaller a 4-3/4” Storm Valve will be run).

- Pick up Storm Valve and place in mouse hole, use a safety clamp.

- Make up a single or double onto the Storm Valve.

- Pick up DLT Packer and place in mouse hole, use a safety clamp to hold packer as low aspossible in mouse hole.

- Make up Storm Valve on the DLT Packer, use racking arms and tugger lines to keep toolsvertical in the mouse hole. Keep tugger lines as close to the tongs as possible.

- Torque up all tool joints to the required torques in the mouse hole taking maximum care.

- Pick assembly out of the mouse hole and make up to drill pipe in the rotary table and torqueup.

- Prior to running in the hole check DLT Packer setting mechanism. See Appendix 2.2

- Set slips on top sub of packer and check the back-off sub is still chain-tong tight, by breakingjoint remaking.

2.3 RIH with tool assembly.

- Run DLT Packer and Storm Valve through BOP’s slowly.

- Do not use any force to pass through BOP’s.

- If running from a floater make sure the compensator is operational and used when passingthrough the BOP’s.

- Avoid making a connection with the packer in the BOP’s it on a floater.

Once past the wellhead, do not exceed a running speed of 1 min/stand to prevent surging (no bypassor unloader on DLT Packer).

2.4 Test DLT Packer as soon as possible below wellhead: Set packer by picking up 5 ft, rotating toolstring 1/4 turn to right and set down weight. Pressure test annulus to 1000-psi.

2.5 Run DLT Packer 10 - 20 ft below setting depth, note 'down weight' on Martin Decker.

2.6 Pick back up 10 - 20 ft to place packing elements of packer at required setting depth: record string 'upweight'. (This depth may be adjusted for ease of setting operations on the drill floor or to compensateto ensure the packer is to be set around mid casing joint (away from casing collar).

2.7 Set DLT Packer. Apply 1/4 turn to the right at the tool or one turn to the right per 3000 ft of packersetting depth and hold torque. Lower drill string to see if packer takes weight.

When setting the packer, right hand torque should be keep to a minimum. If torque values over 4000lbs are required to turn the string the setting procedure should be altered. When picking up to settingdepth the right hand torque should be applied, as the string is moving this lower the force required toturn the drill string. The torque should be held as setting depth reached and then lower string withtorque still applied.

2.8 When the packer begins to take weight, release the right hand torque and slack off the weight of theB.H.A below the packer. This should be a minimum of 25,000 lbs off the 'down weight' of the string.

2.9 Close annular preventer(s) and pressure test annulus to the required pressure.

3. Back-off Storm Valve to suspend well:

Note: Maximum setting depth for Storm Valve is 2000 ft for deeper application a bridge plug shouldbe used.

3.1 Pick up string weight (above packer) + 2/3000 lbs tension.

3.2 Rotate the back-out sub of the Storm Valve 12 turns to the left. At this point the valve is closed andthe threads and seals of the back-out sub are still engaged.

3.3 Pressure test down the drill pipe to 1000 psi to confirm the Storm Valve is closed and holding. Bleedoff all pressure when complete.

3.4 Rotate the string an additional 10 turns to the left (20 - 21 total) to release the back-out threads fromthe Storm Valve slowly.

- Keep an eye on the weight indicator to see when the valve disengages.

- Pick up string weight slowly and check the up-weight of the string is reduced.

- Note up and down weight of string once backed off from tool.

- Note free torque of string once backed off of tool.

3.5 POOH and inspect Storm Valve stinger sub at surface for damage or missing O-rings.

4. Retrieving DLT Packer and Storm Valve:

4.1 If debris is suspected to be in Storm Valve, remove O-rings on stinger sub.

4.2 RIH with drill pipe and stinger sub of Storm Valve.

- Prior to tagging the top of the packer install a surface valve and pressure gauge; pressuremay be trapped below Storm Valve and may need to be controlled/bled off when valve isengaged/opened.

- Circulate as the tool string is being lowered.

4.3 Slowly tag the top of the Storm Valve body with mud pump not pumping.

4.4 Pull back to string 'up weight', then 1-2 ft and circulate 10 bbls at 5 BPM’s.

4.5 Stop pumping, run back down slowly and tag Storm Valve tool with the minimum weight possible,ideally 1-2000 lbs.

4.6 If O-rings were removed from stinger, circulate hole volume, trip out replace O-rings.

4.7 Rotate 10 turns to the right at the tools and then pick-up 5000 lbs above the landing string 'upweight' to check that the stinger sub is engaged.

4.8 Slack off +/- 2000 lbs off of landing string 'down weight' and make a further 12 - 13 turns to the right(20 - 21 turns total) to fully engage the packer and open the Storm Valve. As soon as an increase intorque is noticed then stop rotation. After about 12 turns (valve starting to open) watch carefully for anindication of pressure trapped below the packer.

- Keep torque to a minimum. Set torque limiter to +/- 4000-ft lbs.

- If gas/pressure is present under the packer the torque will increase as the Storm Valve isopened and pressure moved into the drill string above the valve, do not proceed withunseating the packer until the OIM / DSV is informed. Well kill procedures should then befollowed.

- The packer cannot be un-set with positive pressure in the drill string as this will cause theupper packer slips to engage the casing. The annulus above the Packer should bepressurised to give a positive differential pressure (about 500 psi) from the annulus to drillpipe across the packer elements.

- Observe for any pressure trapped below the tools and bleed off accordingly.

4.9 Once all pressures balanced or zero, pick-up to string 'up weight' then another 5 ft to de-energisepacking elements of the DLT Packer. Circulate about 5 bbls to clear solids around elements. Wait 5 -10 minutes prior to POOH to allow elements to relax.

- Some over-pull may be noted when un-setting the packer due to solids settling out above.

- Depending on hole conditions, a decision to circulate bottoms up or kill the well should bemade at this time. Circulation rates will not be a problem so long as no losses occur.

4.10 Confirm DLT Packer is in safety position - Pick up 10 ft and then run back down 10 ft.

4.11 POOH with Storm Valve and DLT Packer. Control POOH rate to avoid swabbing well in. Watch forslips hanging up while pulling through BOP’s.

4.12 Once DLT Packer and Storm Valve are back at surface do the following: -

- Break out tools in exactly the same way as they were made up in the mouse hole.

- Once broken out wash the tools with fresh water if available.

- Make sure all tool threads have protectors fitted.

- Red tag tools and note any damage before back loading for redressing.

Note: The Storm Valve is as its name implies a Storm Valve. It is not intended to be a Bridge Plugconversion for the DLT Packer. When a tool is needed to plug the well at depths in excess of 2000 ftthe proper size Bridge plug should be used.

DLT Packer: Deviated well supplement.

1. Additions to well suspension procedure.

1.1 When suspending a well with a DLT Packer in a highly deviated well, some additional proceduresshould be implemented.

- The weight of pipe to be hung off below the Packer will have to be calculated to take intoaccount the pipe lying on the side of the casing and the drag this creates. These effects willall reduce the weight hanging on the Packer.

- The weight of the pipe below the tool has to be calculated to give an accurate free point at theStorm Valve when backing off.

- When setting the packer torque may have to be worked into the string. This is done byputting a couple of turns to the right into the string at a time and working them in by loweringthe string to 20,000 lbs from the down weight, then pulling back up to 20,000 lbs from the upweight. Do this several times and then pull back up to the up weight and put another coupleof turns into the string until the full turns have been worked into the string. Now the string maybe lowered to see if the packer will take weight.

SECTION B : DLT Packer: Running for casing test

1. Perform Pre-job checks, etc:

1.1 See Appendix 2.1

1.2 Was a casing scraper run ? if not then recommend one. Also, if possible the hole should be circulatedclean prior to running the tool.

1.3 Before running tools hydraulics calculations must be performed to decide what pipe has to be run andwhat the string will do when pressured up.

1.4 Make a fishing diagram of all tools to be run downhole.

1.5 Perform all necessary calculations prior to job.

1.6 One stand of pipe should be run below tools to avoid them being run into any solids build-up at thebottom of the hole.


2.1 Make up and RIH with drill collars/pipe if weight is to be run below tools.

Normally for a casing test, the packer will be run deep. This means there will be enough weightabove the packer to set down for the pressure test. If this is the case just run a joint or stand of pipebelow the tools to guide them through the wellhead/BOP’s.

2.2 Pick up DLT Packer with 4-1/2” VIII Unloader and RIH.

Note: When running 7” tools and smaller, smaller sizes of VIII Unloaders are used.

- Pick up Unloader and place in mouse hole, use safety clamp.

- Make up a single or a double onto VIII Unloader.

- Pick up DLT Packer and place in mouse hole, use safety clamp to hold packer, as low aspossible in mouse hole.

- Make up VIII Unloader on to the DLT Packer, use racking arms and tugger lines to keep toolsvertical in the mouse hole. Keep tugger lines as close to tongs as possible.

- Torque up all tool joints to the required torques in the mouse hole taking maximum care.

- Pick assembly out of mouse hole and make up onto drill pipe in rotary table.

- Prior to running in hole, check DLT Packer setting mechanism.

- Gauge Packer O.D. for the correct size of casing.

- Check VIII Unloader is open and in safety position. If not reset with chain tong.


- Run DLT Packer and VIII Unloader through BOP’s slowly.

- Do not use any force to pass through BOP’s

- If running from a floater make sure the compensator is operational and used when passingthrough the BOP’s.

- Avoid making a connection with the packer in the BOP’s if on a floater.

Once past the BOP’s watch for losses. If losses occur slow down running speed to suit.

2.4 Test DLT Packer as soon as possible below wellhead: Set packer by picking up 5 ft rotating string 1/4turn to the right and set down weight. Pressure test annulus to 1000 psi.

2.5 To unset DLT Packer and open VIII Unloader, hold 1/2 turn to the right in string and pick up 5 ft. ThePacker should now be unset and the VIII Unloader open. Before running to test depth wait for 5 to 10minutes to ensure elements have contracted fully.

2.6 Setting packer at testing depth.

- Run Packer 15 ft below setting depth. Note 'down weight' of string.

- Pick up to 'up weight' of string and note it, then another 15 ft to place elements at test depth.

- Rotate string 1 turn per 3000 ft depth to the right and hold the torque.

- Lower string until 'down weight' starts to decrease. When packer starts to set then releasethe torque and continue to slack off required weight onto tool for pressure test to compensatehydraulics.

- Close annular preventor and perform casing pressure test.

3. Unset DLT Packer and POOH:

3.1 Pick up to strings full up weight slowly. If packer is free pick up another 5 ft quickly.

- Make sure all pressure is bled off before unsetting Packer.

- Hold right hand torque in the string while unsetting packer to opent the VIII Unloader, if theright hand torque used to set the packer was let out then 1 turn per 3000 ft depth to the rightwill be required to open the VIII Unloader.

- Once Packer has been unset lower string 10 ft to ensure it is in safety.

- Before POOH, wait 5 to 10 mins to ensure element have contracted fully.

- POOH and break out tools in the same way as they were made up.

Caution: When pulling out if casing is open to the formation, do not exceed 1 minute per standand watch the wall does not swab in.

SECTION C : DLT Packer: Inflow testing liner lap with unperforated liner.

Outline: This procedure has been designed for running a 9-5/8” DLT Packer and 4-1/2” VIII Unloaderto inflow test the liner lap of a liner which has pressure integrity.

1. Perform Pre-job check, etc:

1.1 See Appendix 2.1.

1.2 Was a scraper run ? if not then recommend one. Also, if possible the hole should be circulated cleanprior to running the tool.

1.3 Check on rig well control procedures.

1.4 Make a fishing diagram of all tools to be run downhole.



2.1 Pick up DLT Packer with 4-1/2” VIII Unloader and run in hole. Ensure correct torques are applied andthat the unloader is in the open position.

- Pick up DLT Packer and place in mouse hole, use a safety clamp.

- Pick up VIII Unloader and make up onto DLT Packer.

- Put one stand of drill pipe onto top of VIII Unloader in the mouse hole, only if the blocks willtake the extra height of the tools, If they will not then run a single or a double above the tool.

- Torque up all tool joints as they are run, but do not set slips on packer body.See Appendix 3.1 for torque values.

Note: Never rack tools back in derrick under stands of pipe as damage will occur.


- Run DLT Packer slowly through BOP’s.

- Do not use excessive force to pass through BOP’s.

- If running from a floater, make sure the compensator is operational and used when passingthrough the BOP’s.

- Avoid making a connection with the Packer in the BOP’s if on a floater.

- Plan space out to setting depth for closing annular or pipe rams.

3. Setting, Pressure Testing and Inflow Testing:

3.1 Run DLT Packer 10 ft below setting depth. Note 'down weight'.

3.2 Pick up until 'up weight' is reached and note it, then pick up another 10 ft to place the elements as therequired testing depth, in this case will be a close to the PBR as possible.

3.3 Set DLT Packer: Apply 1/4 turn to the right at the tool or 1 turn to the right per 3000 ft of depth andhold in the torque. Lower drill string to see if packer takes weight.

3.4 When packer takes weight, release torque and slack off the required amount of weight for thepressure test off the 'down weight'.

3.5 Close annular preventor or pipe rams and pressure test packer to the required pressure.

3.6 Circulating drill pipe to light fluid.

- Make sure all pressure is bled off.

- Pick up drill string to 'up weight', then another 5 ft. The packer is now unset.

- Displace the drill pipe only to seawater from volume previously calculated.

- Maximum rate of 3 bpm if you are unsure that the unloader is open.

- DLT Packer should now be set again. If hole is deviated, enough torque should still be lockedin the string to allow the packer to be set by just lowering the drill string again, until weightdrops off the 'down weight'. If this does not reset the packer then the full setting procedurewill have to be repeated.

- Once packer is set, bleed down surface pressure in the drill string to perform inflow test onliner lap.

During this operation watch the level of fluid outside the drill string. If this level drops as the inside ofthe drill sting is bled off, then the unloader may still be open. Pressure up the drill pipe to stabilise thewell and unset, then reset the packer. Follow inflow steps again.

4. Reverse circulating out light fluid and POOH:

4.1 Reverse circulating out seawater

- Pressure up drill string to equalise BHP at packer

- Pick up string 'up weight' then another 5ft to unset packer.

- Close in annular preventor

- Reverse circulate out light fluid.

4.2 Surface pressures should now be ZERO. Open annular preventor and perform flow check for 5 to 10minutes.

4.3 POOH and break out tools at surface in same manner as made up.

SECTION D : DLT Packer: Inflow testing liner lap with open perforation, etc.

Outline: This procedure has been designed for running a 7" DLT Packer with a 3 1/2" VIII Unloaderinto and old liner which is perforated, has a leaking shoe etc., to pressure test and inflow testthe liner lap.

1. Perform Pre-job check, etc:

1.1 See Appendix 2.1.

1.2 Was a casing scraper run? if not then recommend one. Also, if possible the hole should be circulatedclean prior to running the tools and/or spot a hi-vis pill over the packer especially if it is to be left in thehole for a long period of time.

1.3 Check on rig well control procedures

1.4 Make a fishing diagram of all tools to be run downhole

1.5 To perform an inflow test, care must be taken to space out tool joints correctly to enable the packeroperations to be performed without obstruction.

- When inflow testing on a floater, space-out is not a problem, whether equipped with a topdrive or a kelly (BOP's on sea bed). Space-out should be planned to place the middle of ajoint of drill pipe across the annular preventor, when the packer is set. This will allow thepacker to be unset with the annular preventor closed while circulating to seawater undercontrolled conditions and set again to perform the inflow test.

- When inflow testing on a platform: space out is also not a problem when the rig is equippedwith a top drive and same procedure as above applies.

- The space-out is much more important where there is no top drive. On most platforms therewill be a +/- 20ft between the rotary table and the top of the BOP's. When the kelly bushingsare engaged there will be +/- 6ft from the rotary table to the bottom of the first tool joint. Withthis short space available, the setting procedure must be altered. To set the packer the kellybushings must be engaged, the lower the drill string another 10ft and note the 'down weight'.Now pick up the string as high as possible without dis-engaging the kelly bushing, note the'up weight'. At this point the required amount of right hand turns should be put into the stringto set it, then start to lower the string until the packer starts to take weight. Putting the turnsinto the string with as much of the kelly out of the hole as possible will leave +/- 14ft to lowerthe string to set the packer while leaving the middle of the DP across the BOP's.


2.0 RIH and set DLT packer:

2.1 Pick up DLT Packer with 3 1/2" Unloader and run in hole. Ensure correct torques are applied and thatunloader is in the open position.

- Pick up DLT Packer and place in mouse hole, use a safety clamp.

- Pick up VIII Unloader and make up onto DLT Packer.

- Put one stand of drill pip in rotary table and tie off slips.

- Make up one stand of drill pip onto top of V-III Unloader in mouse hole, only if the blocks willtravel high enough to take the extra height of the tools. If they will not, then make up a singleor a double onto the top of the tools in mouse hole.

- Torque up all tool joint as they run, but do not set slips on packerSee Appendix 3.1 for torque values

Note: Never rack tools back in derrick under stands of pipe as damage will occur

2.2 RIH with tool assembly

- Run DLT Packer slowly through BOP's

- Do not use excessive force to pass through the BOP's

- If running from a floater, make sure the compensator is operational and used when passingthrough the BOP's

- Avoid making a connection with the packer in the BOP's of on a floater

- When entering the top of a liner/PBR, etc. Do not excessive force as you may pop one of theelements. If necessary pick up quickly before entering PBR to ensure the packer is in safely.

- Plan space out to setting depth for closing annular pipe rams

3. Setting, Pressure Testing and Inflow Testing:

3.1 Run DLT Packer 10ft below setting depth. Note 'down weight'

3.2 Pick up until weight of string is reached and note it, then pick up another 10ft to place the elements atthe required depth.

3.3 Set DLT packer. Apply 1/4 turn to the right at the tool or 1 turn to the right per 3000ft of depth and holdtorque in the string. Lower drill string to see if tit takes weight.

3.4 When packer starts to take weight release torque and slack off required amount from own weight tocompensate for hydraulic forces at V-III Unloader for pressure test.

3.5 Close in annular op pipe rams and pressure test packer to the required pressure.

3.6 Circulating hole to seawater for inflow testing.

- Make sure all pressure is bled off

- Leave annular closed

- 1/4 RH torque at tool to open unloader

- Pick drill string up until 'up weight' is reached then another 5ft. (pick up as much as kelly willallow without dis-engaging the bushings)

- Wait 5 to 10 minutes, to let elements contract fully.

- Start circulating mud slowly, to check packer is unset.

- Circulate wait to seawater under controlled conditions. (if hole is open to formation keepcirculating pressure below fracture pressure).

- Put required amount of right hand turns into string for setting packer.

- Lower drill string until packer starts to reduce strings 'down weight'. Set minimum weight ontopacker to compress elements.

4. Circulating back to Mud / Brine and POOH:

4.1 Circulating hole back to mud / brine.

- Close in choke

- Pressure up annulus to same surface pressure as drill pipe

- Still holding right hand torque in the string, pick up to the 'up weight' of the string, then another5ft or as much as the kelly will allow. If more height is required, torque may now be releasedfrom the string before dis-engaging the kelly bushings.

- Circulate the hole back to mud / brine, under controlled conditions.

4.2 Open annular preventor and perform a flow check for 5 to 10 minutes.

4.3 POOH and break out tools at surface in same manor as made up.


SERVICE TOOLS

DLT RETRIEVABLE PACKERAPPENDIX : 1

Buoyancy Factor

Buoyancy Factor BF = 1 – (0.0153 x Mud weight (PPG)

Actual buoyancy compensated pipe weight:

Actual Pipe weight = Dry pipe weight (lbs) x Buoyancy Factor

Kill string hang off weight/drag prediction:

Neutral weight = Dry pipe weight x Buoyancy Factor x Cos. Well inclination

Drag prediction = Dry pipe weight x Buoyancy Factor x Sin. Well inclination

Hang off string 'down weight' = Neutral weight – Drag

Hang off string 'up weight' = Neutral weight + Drag

Ballooning/Reverse Ballooning:

Tubing internal value = Change in av. tubing pressure (psi) x ID area of tubing (in2)

Tubing external value = Change in av. tubing pressure (psi) x OD area of tubing (in2)

Higher internal tubing value will result in Ballooning force, which takes weight off the packer.

Higher external tubing value will result in Reverse Ballooning force, which applies extra weight down.

FORCE = 0.6 (Tubing internal value – tubing external value)

Temperature effect:

Force created by temperature change, will force down on packer if a +change in temperature

Force created by temperature change, will take weight off of packer if a -change in temperature

FORCE – 207 x Cross Sectional Area of tubing x Average change in temperature

Note: Well may have to be broken into sections to accurately predict neutral weight and drag. Break it down into sections to give several average inclinations.

2.75


SERVICE TOOLS


BUOYANCY / DEVIATION FACTOR

8 10 12 14 16 18 20

0.9

0.8

0.7

0.6

0.5

0.4

0.3

0.2

0.1

0

Straight Hole

20 Deg dev

30 Deg dev

40 Deg dev

50 Deg dev

60 Deg dev

70 Deg dev

80 Deg dev

This chart has been made up to give a buoyancy factor which compensates for hole deviation which will reduce the neutral weight ofpipe. To use this chart the mud weight in the hole deviation must be known.

MUD WEIGHT (PPG)

BU

OYA

NC

Y FA

CTO

R


SERVICE TOOLS


1. Pre-job meeting data

MD (ft) TVD (ft) Incl. (deg) BHST (degF)Packer SettingDepth(s)

MD (ft) TVD (ft) Weight (lb./ft) Min ID (in.) Grade

Previous Casing

Casing

Liner

MD (ft) O.D. (in) Weight (lb./ft) Min ID (in) Conn / Thread

Drill pipe / Tubing

Mud Wt (ppg) Well Head depth: Hang-off weight:

2. Packer function test

Just before tool is run below the rotary table, put a sling around the J-slot housing of the packer and turn it 1/4 turn to the right outof safety as it is picked up with a tugger to check the slips are functional


SERVICE TOOLS


1. Required tool joint torque values

TOOL JOINT SIZE TORQUE VALUE4 1/2" I.F. 22-24,000 ft lbs.3 1/2" I.F. 12-13,000 ft lbs.

2. Troubleshooting

PROBLEM POSSIBLE SOLUTIONTools will not pass through wellhead Pull tools back to surface and inspect for defects.

Check minimum I.D. of wellhead / wear bushing etc.Packer will not pressure test When testing above packer check for returns up drill pipe.

This will show if packer is leaking or unloader is open / leaking.Unset packer and go through setting procedure again.

Unloader will not close Unset packer and repeat setting procedure.Unloader will not open Reset packer, hold torque in string and unset packer again. This should open the

unloader.Packer will not set Repeat setting procedure.

If setting in deep deviated hole, work torque into string.Try slacking off weight onto tool quicker.

Storm valve will not pressure test afterscrewing out.

Check for surface leaksScrew back into valve, then screw out again. If this does not solve the problem,retrieve packer and pull back to surface. Strip tool.

Storm valve cannot be screwed into at all. Repeat well suspension procedures 3.3 onwardsFull 21 turns cannot be put into Storm valve Screw out of valve and repeat well suspension procedures 3.3 onwards

Depending on how many turns have been put into the valve, it may be possible to pullback to surface without getting the full 21 turns. 10 turns should be the minimum, butless may be adequate in extreme circumstances, depending on the weight of pipebelow and drag.CAUTION! Always remember there may be pressure trapped below the packer whichwill not be seen until the Storm valve is open. The valve does not start to open until12 turns have been made.

Packer causes excessive drag after being setfor a long time.

Work string several times between ‘up-weight’ and neutral weight at packer. Thisshould let the elements contract which may be extruded over the bottom gauge ring ofthe packer.

DLT packer will not unset. If pressure has been applied below the packer, the upper slips will have been set.These should retract when pressure is bled off. Double check by putting 500 psiabove the packer.

INDEX NO.: 400UNIT NO.: 688-45PN: 688-45 & 46PAGE: 1 OF 2

© 1999 WEATHERFORD All Rights Reserved. NORTH AMERICAN NUMBERS: HUNTSVILLE, TX PH:800/331-4042 USA 409/295-0080 FAX:409/295-9132 • POWELL, WY PH:307/754-7234 800/458-9202 USA FAX:307/754-5875 REV. 00/DTD: 11-08-99

4-1/2” X 2-3/8” DLT RETRIEVABLE PACKER

The Weatherford DLT Packer is a compression set packer with hydraulic hold down that is designedto provide an extra measure of dependability for rugged service. The hydraulic actuated upper holddown provides more than the usual surface area to assure the packer will not move up the hole. TheDLT includes the same reliable features as our C-5 Packers. It is ideally suited for high pressure,high temperature service work. Some unique features of the DLT include positive rotational locks onall internal connections, which allow for extreme values of torque (left or right hand) to be transmittedthrough the packer. Back-up rings on all the o-rings provide for more reliable sealing at hightemperature and pressure. The DLT also comes with extra long top and bottom subs, which allow forhydraulic tong make-up and break out.

SPECIFICATION GUIDE

4-1/2 11.6 - 13.5 3.920 4.000 3.781 1.750 2-3/8" IF 688-454-1/2 15.1 - 17.7 3.696 3.826 3.593 1.750 2-3/8" IF 688-46

CASING

O.D. (IN.)

WEIGHT (LBS./FT.)

RECOMMENDED CASING RANGEMIN. (IN.)

MAX. (IN.)

MAX. O.D. OF

TOOL

MIN. I.D. OF

TOOL

THREAD CONNECTION

BOX UP PIN DOWN

PRODUCT NUMBER

NOTE: Coordination of unloader and packer jay slots is imperative. The setting and releasing procedures below represent use of a right hand open and right hand close unloader jay slot with a right hand set, automatic release packer jay slot.

SETTING PROCEDURES

Run the DLT packer to setting depth in conjunction with a Type V-III Unloader. The unloader shouldremain open while running in. Pick up the tubing and rotate it ¼ turn to the right at the packer. Slackoff weight on the packer to set the slips and compress the packing elements (see setting forcesguide). Release the torque after slacking off 6” to allow the unloader to close and lock. The set downweight must remain on the packer throughout well operation.

RELEASING PROCEDURES

Rotate the tubing ¼ turn to the right and pick up on the tubing to open the V-III Unloader. Allow timefor the tubing and casing pressures to equalize. Continued upward movement of the tubing relaxesthe packing elements, un-sets the slips, and automatically re-jays the packer. The tool may now bemoved and reset or pulled from the well.

SETTING FORCES GUIDE

4-1/2 10,000

SIZE (IN.)

MINIMUM WEIGHT REQUIRED AT THE

PACKER (LBS.)

DISASSEMBLY

1.) Place top sub (1) in vise.2.) Remove J-body torque screws (31) and remove J-body (30) from control body (23) [LEFT HAND

THREAD]. Turn J-body (30) to expose torque screws (32) in bottom sub (35).3.) Remove torque screws (32) from bottom sub (35) and remove bottom sub (35) from mandrel

(15). Remove o-ring (33) and back-up ring (34) from bottom sub (35).4.) Compress and hold drag blocks (27). Remove drag block retainer (29) from control body (23).

Remove drag blocks (27) and drag block springs (28) from control body (23).5.) Remove control body (23) from inner mandrel (15). Remove slips (24) from control body (23)

and remove set screws (25) and slip springs (26) from slips (24).6.) Remove lower cone (22) from rubber retainer (21) and remove from inner mandrel (15).7.) Slide volume tube (4) out of inner mandrel (15).8.) Remove hold down cap (9) from hold down body (8). Remove torque screws (7 & 16) from top

and bottom of hold down body (8).9.) Remove inner mandrel (15) from hold down body (8). Remove packing elements (18 & 20) and

rubber spacers (19) from inner mandrel (15). Remove rubber retainer (21) from inner mandrel(15).

10.) Remove upper retainer cap (17) from hold down body (8). Remove screws (14) from hold downstraps (10) and remove straps (10) and button springs (12) from control body (8).

11.) Remove hold down buttons (13) from hold down body (8).12.) Remove T seals (11) from hold down buttons (13).13.) Remove hold down body (8) from top sub (1).14.) Remove o-rings (5) and back-up rings (6) from top and bottom of hold down body (8).15.) Remove o-ring (2) and back-up rings (3) from top sub (1).16.) Clean and inspect all parts. Replace any worn or damaged parts. Re-assemble in reverse order

of disassembly.

CAUTION: If the DLT Packer is run with a retrievable bridge plug, make sure that the J-slots on the bridge plug, retrieving tool, unloader and packer are compatible. Whichever direction the plug is set, the retrieving tool should release and the Packer should set in the opposite direction.

EXAMPLE: Right hand set / right hand releasing bridge plug, is used with a left hand release retrieving tool, left hand set packer and a left hand close / right hand open unloader.

NOTES: 1.) Hang off weight for the DLT packer: 4-1/2” are 90,000 lbs.2.) Maximum torque transmitted through tool: 4-1/2” 10,000 ft-lbs.3.) Pressure rating: 4-1/2” - 10,000 PSI.

PACKING ELEMENT GUIDE

END MIDDLE ENDLOW TEMPERATURE 60 - 125 80 60 80STANDARD TOOL 125 - 225 90 70 90MODERATE TEMP. 225 -275 90 80 90HIGH TEMPERATURE 275 - UP

CLASSIFICATION TEMP. RANGE

ELEMENT DURO

CONTACT TECH. SALES

© 1999 WEATHERFORD All Rights Reserved. NORTH AMERICAN NUMBERS: HUNTSVILLE, TX PH:800/331-4042 USA 409/295-0080 FAX:409/295-9132 • POWELL, WY PH:307/754-7234 800/458-9202 USA FAX:307/754-5875

INDEX NO.: 400UNIT NO.: 688-45PN: 688-45 & 46PAGE: 2 OF 2

REV. 00/DTD: 11-08-99

PARTS LIST

4-1/2" 4-1/2"11.6 - 13.5 15.1 - 17.7

688-45 688-461 TOP SUB** 688-45-610 688-45-6102 O-RING* 050-90-226 050-90-2263 BACK-UP RING* 045-01-226 (2) 045-01-226 (2)4 VOLUME TUBE 688-50-280 688-50-2805 O-RING* 050-90-231 (2) 050-90-231 (2)6 BACK-UP RING* 045-00-231 (4) 045-00-231 (4)7 TORQUE SCREW* 021-C8-007 (4) 021-C8-007 (4)8 HOLD DOWN BODY** 688-45-311 688-46-3109 HOLD DOWN CAP 688-45-370 688-46-37010 HOLD DOWN STRAP 688-45-360 688-45-36011 T-SEAL 053-01-129 (6) 053-01-129 (6)12 SLIP SPRING* 688-45-975 (12) 688-45-975 (12)13 CARBIDE BUTTON* 688-45-980 (6) 688-46-980 (6)14 SET SCREW* 005-03-006 (3) 005-03-006 (3)15 MANDREL** 688-45-210 688-45-21016 TORQUE SCREW* 021-C8-007 (4) 021-C8-007 (4)17 UPPER RETAINER CAP 688-45-830 688-46-83018 PACKING ELEMENT* 688-45-514 (2) 688-46-514 (2)

ITEM N0.

DESCRIPTION

DIMENSIONAL DATA

4-1/2 688-45 96.277 18.292 4.467 2.000 12.5144-1/2 688-46 96.277 18.292 4.467 2.000 12.514

CASING SIZE (IN.)

PRODUCT NUMBER A B

DIMENSIONS (IN.)

C D E

PARTS LIST

4-1/2" 4-1/2"11.6 - 13.5 15.1 - 17.7

688-45 688-4619 RUBBER SPACER 688-45-840 (2) 688-46-840 (2)20 PACKIING ELEMENT* 688-45-511 688-46-51121 RUBBER RETAINER 688-45-850 688-46-85022 LOWER CONE 688-45-410 688-45-41023 CONTROL BODY** 688-45-330 688-45-33024 CARBIDE SLIP* 688-45-110 (4) 688-46-110 (4)25 SET SCREW* 004-03-004 (4) 004-03-004 (4)26 SLIP SPRING* 350-35-900 (8) 350-35-900 (8)27 DRAG BLOCK* 090-55-90P (4) 090-55-90P (4)28 DRAG BLOCK SPRING* 091-00-900 (16) 091-00-900 (16)29 DRAG BLOCK RETAINER 688-45-910 688-45-91030 J-BODY 688-45-355 688-45-35531 TORQUE SCREW* 021-C8-007 (4) 021-C8-007 (4)32 TORQUE SCREW* 021-C8-007 (4) 021-C8-007 (4)33 O-RING* 050-90-226 050-90-22634 BACK-UP RING* 045-01-226 (2) 045-01-226 (2)35 BOTTOM SUB** 688-45-620 688-45-620

ITEM N0.

DESCRIPTION

*Common repair parts. **These parts are mated parts and cannot be replaced separately without field adaptation.

DIMENSIONAL DATA (cont.)

4-1/2 688-45 3.380 1.750 3.594 3.781 21.3754-1/2 688-46 3.380 1.750 3.594 3.593 21.375

CASING SIZE (IN.)

PRODUCT NUMBER F G

DIMENSIONS (IN.)

H J K

INDEX NO.: 400UNIT NO.: 688-50PN: 688-50 & 51

688-55 & 55BPAGE: 1 OF 3


5” & 5-1/2” X 2-3/8” DLT RETRIEVABLE PACKER

The Weatherford DLT Packer is a compression set packer with hydraulic hold down that is designedto provide an extra measure of dependability for rugged service. The hydraulic actuated upper holddown provides more than the usual surface area to assure the packer will not move up the hole. TheDLT includes the same reliable features as our C-5 Packers. It is ideally suited for high pressure,high temperature service work. Some unique features of the DLT include positive rotational locks onall internal connections, which allow for extreme values of torque (left or right hand) to be transmittedthrough the packer. Back-up rings on all the o-rings provide for more reliable sealing at hightemperature and pressure. The DLT also comes with extra long top and bottom subs, which allow forhydraulic tong make-up and break out.

SPECIFICATION GUIDE

5 11.5 - 15.0 4.408 4.560 4.250 1.750 2-3/8" IF 688-505 15.0 - 18.0 4.276 4.408 4.125 1.750 2-3/8" IF 688-51

5-1/2 13.0 - 17.0 4.892 5.044 4.641 1.750 2-3/8" IF 688-555-1/2 17.0 - 23.0 4.670 4.892 4.500 1.750 2-3/8" IF 688-55B

CASING

O.D. (IN.)

WEIGHT (LBS./FT.)

RECOMMENDED CASING RANGEMIN. (IN.)

MAX. (IN.)

MAX. O.D. OF

TOOL

MIN. I.D. OF

TOOL

THREAD CONNECTION

BOX UP PIN DOWN

PRODUCT NUMBER


SETTING PROCEDURES





5 10,0005-1/2 15,000

SIZE (IN.)


PACKER (LBS.)

DISASSEMBLY

1.) Place top sub (1) in vise.2.) Remove J-body torque screws (32) and remove J-body (31) from control body (24) [LEFT HAND

THREAD]. Turn J-body (31) to expose torque screws (33) in bottom sub (36).3.) Remove torque screws (36) from bottom sub (36) and remove bottom sub (36) from mandrel

(22). Remove o-ring (34) and back-up rings (35) from bottom sub (36).4.) Compress and hold drag blocks (28). Remove drag block retainer (30) from control body (24).

Remove drag blocks (28) and drag block springs (29) from control body (24).5.) Remove control body (24) from inner mandrel (22). Remove slips (25) from control body (24)

and remove set screws (26) and slip springs (27) from slips (25).6.) Remove lower cone (23) from lower retainer cap (21) and remove from inner mandrel (22).7.) Slide volume tube (17) out of inner mandrel (22).8.) Remove hold down cap (2) from hold down body (3). Remove torque screws (4) from top and

bottom of hold down body (3).9.) Remove inner mandrel (22) from hold down body (3). Remove packing elements (18 & 20) and

rubber spacers (19) from inner mandrel (22). Remove lower retainer cap (21) from innermandrel (22).

10.) Remove upper retainer cap (16) from hold down body (3). Remove screws (12) from hold downstraps (13) and remove straps (13) and button springs (11) from control body (3).

11.) Remove hold down buttons (10) (Hold down button disassembly tool P/N: 613-55-PP1) from holddown body (3).

12.) Remove T seals (9) from hold down buttons (10).13.) Remove hold down body (3) from top sub (1).14.) Remove o-rings (5 & 14) and back-up rings (6 & 15) from hold down body (3).15.) Remove o-ring (7) and back-up rings (8) from top sub (1).16.) Clean and inspect all parts. Replace any worn or damaged parts. Re-assemble in reverse order

of disassembly.

CAUTION: If the DLT Packer is run with a retrievable bridge plug, make sure that the J-slots on the bridge plug, retrieving tool, unloader and packer are compatible. Whichever direction the plug is set, the retrieving tool should release and the Packer should set in the opposite direction.

EXAMPLE: Right hand set / right hand releasing bridge plug, is used with a left hand release retrieving tool, left hand set packer and a left hand close / right hand open unloader.

NOTES: 1.) Hang off weights for the DLT packer: 5” are 90,000 lbs. / 5-1/2” are 122,000 lbs.2.) Maximum torque transmitted through tool: 5” 10,000 ft-lbs. / 5-1/2” 10,000 ft-lbs.3.) Pressure rating: 5” - 10,000 PSI. / 5-1/2” - 10,000 PSI.


END MIDDLE ENDLOW TEMPERATURE 60 - 125 80 60 80STANDARD TOOL 125 - 225 90 70 90MODERATE TEMP. 225 -275 90 80 90HIGH TEMPERATURE 275 - UP


ELEMENT DURO

CONTACT TECH. SALES


INDEX NO.: 400UNIT NO.: 688-50PN: 688- 50 &51

688-55 & 55BPAGE: 2 OF 3

REV. 00/DTD: 11-11-99

PARTS LIST

5" 5"11.5 - 15.0 15.0 - 18.0

688-50 688-511 TOP SUB** 688-50-610 688-50-6102 HOLD DOWN CAP 688-50-370 688-50-3703 HOLD DOWN BODY** 688-50-310 688-50-3104 TORQUE SCREW* 021-C10-008 (8) 021-C10-008 (8)5 O-RING* 050-90-337 050-90-3376 BACK-UP RING* 045-01-337 (2) 045-01-337 (2)7 O-RING* 050-90-329 050-90-3298 BACK-UP RING* 045-01-329 (2) 045-01-329 (2)9 BUTTON T-SEAL* 053-01-133 (6) 053-01-133 (6)10 HOLD DOWN BUTTON* 688-50-980 (6) 688-50-980 (6)11 BUTTON SPRING* 680-50-975 (12) 680-50-975 (12)12 SET SCREW* 005-03-008 (3) 005-03-008 (3)13 HOLD DOWN STRAP 688-50-360 (3) 688-50-360 (3)14 O-RING* 050-90-333 050-90-333

ITEM N0.

DESCRIPTION

DIMENSIONAL DATA

5 688-50 99.340 43.000 19.000 1.750 3.375 4.125 4.2505 688-51 99.340 43.000 19.000 1.750 3.375 4.125 4.125

CASING SIZE (IN.)

BASE PRODUCT NUMBER

A B

DIMENSIONS (IN.)

GC D E F

PARTS LIST

5" 5"11.5 - 15.0 15.0 - 18.0

688-50 688-5115 BACK-UP RING* 045-01-333 (2) 045-01-333 (2)16 UPPER RETAINER CAP 688-50-830 688-51-83017 VOLUME TUBE 688-50-280 688-50-28018 PACKING ELEMENT* 650-50-514 (2) 602-50-513 (2)19 RUBBER SPACER 650-50-840 (2) 601-50-840 (2)20 PACKING ELEMENT* 650-50-511 602-50-51121 LOWER RETAINER CAP 688-50-850 688-51-85022 INNER MANDREL** 688-50-210 688-50-21023 LOWER CONE 688-50-410 688-50-41024 CONTROL BODY** 688-50-330 688-50-33025 CARBIDE SLIP* 680-50-110 (4) 680-50-110 (4)26 SET SCREW* 004-03-006 (4) 004-03-006 (4)27 SLIP SPRING* 450-55-900 (8) 450-55-900 (8)28 DRAG BLOCK* 090-56-90P (4) 090-56-90P (4)29 DRAG BLOCK SPRING* 091-00-900 (16) 091-00-900 (16)30 DRAG BLOCK RETAINER 688-50-910 688-50-91031 J-BODY** 688-50-355 688-50-35532 TORQUE SCREW* 021-C10-008 (4) 021-C10-008 (4)33 TORQUE SCREW* 021-C10-008 (4) 021-C10-008 (4)34 O-RING* 050-90-329 050-90-32935 BACK-UP RING* 045-01-329 (2) 045-01-329 (2)36 BOTTOM SUB** 688-50-620 688-50-620

ITEM N0.

DESCRIPTION


INDEX NO.: 400UNIT NO.: 688-50PN: 688-50 & 51

688-55 & 55BPAGE: 3 OF 3


PARTS LIST

5-1/2" 5-1/2"13.0 - 17.0 17.0 - 23.0

688-55 688-55B1 TOP SUB** 688-55B-610 688-55B-6102 HOLD DOWN CAP 688-55-370 688-55B-3703 HOLD DOWN BODY** 688-55B-310 688-55B-3104 TORQUE SCREW* 021-C10-010 (8) 021-C10-010 (8)5 O-RING* 050-90-337 050-90-3376 BACK-UP RING* 045-01-337 (2) 045-01-337 (2)7 O-RING* 050-90-329 050-90-3298 BACK-UP RING* 045-01-329 (2) 045-01-329 (2)9 BUTTON T-SEAL* 053-01-226 (6) 053-01-226 (6)10 HOLD DOWN BUTTON* 688-55-980 (6) 688-55-980 (6)11 BUTTON SPRING* 688-55-975 (18) 688-55-975 (18)12 SET SCREW* 005-C5-006 (3) 005-C5-006 (3)13 HOLD DOWN STRAP 680-55-360 (3) 680-55-360 (3)14 O-RING* 050-90-333 050-90-333

ITEM N0.

DESCRIPTION

DIMENSIONAL DATA

5-1/2 688-55 99.218 44.406 22.531 1.750 3.380 4.493 4.6415-1/2 688-55B 99.218 44.406 22.531 1.750 3.380 4.493 4.500

CASING SIZE (IN.)

PRODUCT NUMBER A B

DIMENSIONS (IN.)

GC D E F

PARTS LIST

5-1/2" 5-1/2"13.0 - 17.0 17.0 - 23.0

688-55 688-55B15 BACK-UP RING* 045-01-333 (2) 045-01-333 (2)16 UPPER RETAINER CAP 688-55-830 688-55B-83017 VOLUME TUBE 688-50-280 688-50-28018 PACKING ELEMENT* 680-55-514 (2) 680-56-514 (2)19 RUBBER SPACER 680-55-840 (2) 680-56-840 (2)20 PACKING ELEMENT* 680-55-511 680-56-51121 LOWER RETAINER CAP 688-55-850 688-55B-85022 INNER MANDREL** 688-55B-210 688-55B-21023 LOWER CONE 688-55B-410 688-55B-41024 CONTROL BODY** 688-55B-330 688-55B-33025 CARBIDE SLIP* 680-55-110 (4) 680-55-110 (4)26 SET SCREW* 004-03-004 (4) 004-03-004 (4)27 SLIP SPRING* 350-55-956 (4) 350-55-956 (4)28 DRAG BLOCK* 090-55-90P (4) 090-55-90P (4)29 DRAG BLOCK SPRING* 091-00-900 (20) 091-00-900 (20)30 DRAG BLOCK RETAINER 688-55-910 688-55B-91031 J-BODY** 688-55B-355 688-55B-35532 TORQUE SCREW* 021-C10-010 (4) 021-C10-010 (4)33 TORQUE SCREW* 021-C10-010 (3) 021-C10-010 (3)34 O-RING* 050-90-329 050-90-32935 BACK-UP RING* 045-01-329 (2) 045-01-329 (2)36 BOTTOM SUB** 688-55B-620 688-55B-620

ITEM N0.

DESCRIPTION


INDEX NO.: 400UNIT NO.: 688-73APN: 688-73A-000

688-73B THRU 73D-001688-75A & 75B

PAGE: 1 OF 4


7” & 7-5/8” DLT RETRIEVABLE PACKER

The Weatherford DLT Packer is a compression set packer with hydraulic hold down that is designedto provide an extra measure of dependability for rugged service. The hydraulic actuated upper holddown provides more than the usual surface area to assure the packer will not move up the hole. TheDLT includes the same reliable features as our C-5 packers. It is ideally suited for high pressure,high temperature service work. Some unique features of the DLT include positive rotational locks onall internal connections, which allow for extreme values of torque (left or right hand) to be transmittedthrough the packer. Back-up rings on all the o-rings provide for more reliable sealing at hightemperature and pressure. The DLT also comes with extra long top and bottom subs, which allow forhydraulic tong make-up and break out.

SPECIFICATION GUIDE

7 17.0 -23.0 6.366 6.538 6.188 3.750 3-1/2" IF 688-73A-0007 26.0 - 32.0 6.094 6.276 5.954 3.750 3-1/2" IF 688-73B-0017 32.0 - 38.0 5.920 6.094 5.781 3.750 3-1/2" IF 688-73C-0017 38.0 - 46.4 5.626 5.920 5.525 3.750 3-1/2" IF 688-73D-001

7-5/8 24.0 - 29.7 6.875 7.025 6.670 3.750 3-1/2" IF 688-75A-0007-5/8 33.7 - 39.0 6.625 6.765 6.453 3.750 3-1/2" IF 688-75B-000

PRODUCT NUMBER

CASING

O.D. (IN.)

WEIGHT (LBS./FT.)

RECOMMENDED CASING RANGE

THREAD CONNECTION

BOX UP PIN DOWN

MIN. I.D. OF

TOOL

MAX. O.D. OF

TOOLMAX. (IN.)

MIN. (IN.)


SETTING PROCEDURES





7" & 7-5/8" 14,000

SIZE (IN.)


PACKER (LBS.)

DISASSEMBLY

1.) Place top sub (1) in vise.2.) Remove J-body set screws (33) and remove J-body (34) from control body (29). (LEFT HAND

THREAD)3.) Remove bottom sub set screws (35) from bottom sub (38). Remove bottom sub (38) from

mandrel (20). Remove o-ring (36) and back-ups (37) from bottom sub (38).4.) Compress and hold drag blocks (30). Remove drag block retainer (32) and remove drag blocks

(30) and drag block springs (31) from control body (29).5.) Remove control body (29) from mandrel (20). Remove slips (26) from control body (29).6.) Remove slip spring screws (27) and slip springs (28) from slips (26).7.) Remove cone (25) from rubber retainer (24).8.) Remove cone (25) from lower end of mandrel (20).9.) Remove set screws (18) from hold down body (8).10.) Remove mandrel (20) from hold down body (8). Remove packing elements (21 & 23), rubber

spacers (22), and rubber retainer (24) from rubber mandrel (20).11.) Remove hold down cap (9) and lower cap (19) from hold down body (8). Remove set screws

(15) from hold down body (8) and remove hold down strap (10) and button springs (12) fromhold down body (8).

12.) Remove carbide buttons (11) (HOLD DOWN BUTTON DISASSEMBLY TOOL P/N: 613-95-PP1)from hold down body (8) and remove o-rings (13) and back-ups (14) from carbide buttons (11).

13.) Remove set screws (7) from top sub (1).14.) Remove hold down body (8) from top sub (1). Remove volume tube (4) from hold down body

(8). Remove o-rings (2 & 16) and back-ups (3 & 17) from hold down body (8).15.) Remove o-ring (5) and back-ups (6) from top sub (1).16.) Clean and inspect all parts. Replace all worn or damaged parts. Re-assemble in reverse order

of disassembly.

CAUTION: If the DLT Packer is run with a retrievable bridge plug, make sure that the J-slots on the bridge plug, retrieving tool, unloader and packer are compatible. Whichever direction the plug is set, the retrieving tool should release and the packer should set in the opposite direction.

EXAMPLE: Right hand set / right hand releasing plug, is used with a left hand release retrieving tool, left hand set packer and a left hand close / right hand open unloader.

NOTES: 1. Hang off weights for the 7” & 7-5/8” DLT Packers are: 195,000 lbs.2. Maximum torque transmitted through tool: 20,000 ft. / lbs.3. Pressure rating: 10,000 PSI.


END MIDDLE ENDLOW TEMPERATURE 60 -125 80 60 80STANDARD TOOL 125 - 225 90 70 90MODERATE TEMP. 225 - 275 90 80 90HIGH TEMPERATURE 275 - UP


ELEMENT DURO

CONTACT TECH. SALES



688-73B THRU 73D-001688-75A & 75B

PAGE: 2 OF 4

REV. 00/DTD: 11-11-99

PARTS LIST

7" 7" 7"17.0 - 23.0 26.0 - 32.0 32.0 - 38.0

688-73A-000 688-73B-001 688-73C-0011 TOP SUB** 688-73D-610 688-73D-610 688-73D-6102 O-RING* 050-90-236 050-90-236 050-90-2363 BACK-UP RING* 045-00-236 (2) 045-00-236 (2) 045-00-236 (2)4 VOLUME TUBE 688-73D-220 688-73D-220 688-73D-2205 O-RING* 050-90-348 050-90-348 050-90-3486 BACK-UP RING* 045-00-348 (2) 045-00-348 (2) 045-00-348 (2)7 TORQUE SCREW*5/8-11 X 3/4" 021-C10-010 (3) 021-C10-010 (3) 021-C10-010 (3)8 HOLD DOWN BODY** 688-73D-310 688-73D-310 688-73D-3109 UPPER CAP 688-73A-865 688-73C-865 688-73C-86510 HOLD DOWN STRAP 681-70-360 (3) 681-70-360 (3) 681-70-360 (3)11 CARBIDE BUTTON* 688-73A-980 (6) 688-73B-980 (6) 688-73B-980 (6)12 BUTTON SPRING* 613-55-975 (12) 613-55-975 (12) 613-55-975 (12)13 O-RING* 050-90-141 (6) 050-90-141 (6) 050-90-141 (6)14 BACK-UP RING* 045-00-141 (12) 045-00-141 (12) 045-00-141 (12)15 FLAT HEAD SCREW* 005-C5-006 (3) 005-C5-006 (3) 005-C5-006 (3)16 O-RING* 050-90-240 050-90-240 050-90-24017 BACK-UP RING* 045-00-240 (2) 045-00-240 (2) 045-00-240 (2)18 TORQUE SCREW*5/8-11 X 3/4" 021-C10-010 (3) 021-C10-010 (3) 021-C10-010 (3)19 LOWER CAP 688-73A-820 688-73B-820 688-73C-82020 MANDREL** 688-73D-210 688-73D-210 688-73D-210

ITEM NO.

DESCRIPTION

DIMENSIONAL DATA

7 688-73A-000 103.438 18.000 4.875 1.000 12.7507 688-73B-001 103.438 18.000 4.875 1.000 12.7507 688-73C-001 103.438 18.000 4.875 1.000 12.7507 688-73D-001 103.438 18.000 4.875 1.000 12.750

7-5/8 688-75A-000 103.438 18.000 4.875 1.000 12.7507-5/8 688-75B-000 103.438 18.000 4.875 1.000 12.750

CASING SIZE (IN.)

PRODUCT NUMBER A B

DIMENSIONS (IN.)

C D E

PARTS LIST

7" 7" 7"17.0 - 23.0 26.0 - 32.0 32.0 - 38.0

688-73A-000 688-73B-001 688-73C-00121 PACKING ELEMENT* 602-72-514 (2) 602-70-514 (2) 602-67-514 (2)22 RUBBER SPACER 611-72-840 (2) 611-70-840 (2) 688-73C-840 (2)23 PACKING ELEMENT* 602-72-513 602-70-513 602-67-51324 RUBBER RETAINER 688-73A-850 688-73B-850 688-73C-85025 CONE 680-73D-410 680-73D-410 680-73D-41026 CARBIDE SLIP* 688-73A-115 (4) 688-73B-115 (4) 688-73B-115 (4)27 SLIP SCREW*10-24 X 3/8"NP 004-03-006 (4) 004-03-006 (4) 004-03-006 (4)28 SLIP SPRING* 688-73D-956 (8) 688-73D-956 (8) 688-73D-956 (8)29 CONTROL BODY** 688-73C-335 688-73C-335 688-73C-33530 DRAG BLOCK* 090-90-90P (6) 090-90-90P (6) 090-90-90P (6)31 DRAG BLOCK SPRING* 091-01-900 (36) 091-01-900 (36) 091-01-900 (36)32 DRAG BLOCK RETAINER 680-73A-910 680-73A-910 680-73A-91033 TORQUE SCREW*5/8-11 X 1/2" 021-C8-008 (4) 021-C8-008 (4) 021-C8-008 (4)34 J-BODY** 688-73D-351 688-73D-351 688-73D-35135 TORQUE SCREW*5/8-11 X 3/4" 021-C10-010 (3) 021-C10-010 (3) 021-C10-010 (3)36 O-RING* 050-90-338 050-90-338 050-90-33837 BACK-UP RING* 045-00-338 (2) 045-00-338 (2) 045-00-338 (2)38 BOTTOM SUB** 688-73D-620 688-73D-620 688-73D-620

ITEM NO.

DESCRIPTION


DIMENSIONAL DATA

7 688-73A-000 4.750 2.688 5.375 6.188 5.4697 688-73B-001 4.750 2.688 5.375 5.954 5.4697 688-73C-001 4.750 2.688 5.375 5.781 5.4697 688-73D-001 4.750 2.688 5.375 5.525 5.469

7-5/8 688-75A-000 4.750 2.688 5.375 6.670 5.4697-5/8 688-75B-000 4.750 2.688 5.375 6.453 5.469

SIZE (IN.)

PRODUCT NUMBER F G

DIMENSIONS (IN.)

H J K


688-73B THRU 73D-001688-75A & 75B

PAGE: 3 OF 4


PARTS LIST

7" 7-5/8" 7-5/8"38.0 - 46.4 24.0 - 29.7 33.7 - 39.0

688-73D-001 688-75A-000 688-75B-0001 TOP SUB** 688-73D-610 688-73D-610 688-73D-6102 O-RING* 050-90-236 050-90-236 050-90-2363 BACK-UP RING* 045-00-236 (2) 045-00-236 (2) 045-00-236 (2)4 VOLUME TUBE 688-73D-220 688-73D-220 688-73D-2205 O-RING* 050-90-348 050-90-348 050-90-3486 BACK-UP RING* 045-00-348 (2) 045-00-348 (2) 045-00-348 (2)7 TORQUE SCREW*5/8-11 X 3/4" 021-C10-010 (3) 021-C10-010 (3) 021-C10-010 (3)8 HOLD DOWN BODY** 688-73D-310 688-73D-310 688-73D-3109 UPPER CAP 688-73D-865 688-75A-865 688-75B-86510 HOLD DOWN STRAP 681-70-360 (3) 681-70-360 (3) 681-70-360 (3)11 CARBIDE BUTTON* 688-73D-985 (6) 688-75A-980 (6) 688-75B-980 (6)12 BUTTON SPRING* 613-55-975 (12) 613-55-975 (12) 613-55-975 (12)13 O-RING* 050-A9-141 (6) 050-90-141 (6) 050-90-141 (6)14 BACK-UP RING* 045-00-141 (12) 045-00-141 (12) 045-00-141 (12)15 FLAT HEAD SCREW* 005-C5-006 (3) 005-C5-006 (3) 005-C5-006 (3)16 O-RING* 050-A9-240 050-90-240 050-90-24017 BACK-UP RING* 045-00-240 (2) 045-00-240 (2) 045-00-240 (2)18 TORQUE SCREW*5/8-11 X 3/4" 021-C10-010 (3) 021-C10-010 (3) 021-C10-010 (3)19 LOWER CAP 688-73D-820 688-75A-820 688-75B-82020 MANDREL** 688-73D-210 688-73D-210 688-73D-210

ITEM NO.

DESCRIPTION

PARTS LIST

7" 7-5/8" 7-5/8"38.0 - 46.4 24.0 - 29.7 33.7 - 39.0

688-73D-001 688-75A-000 688-75B-00021 PACKING ELEMENT* 688-73D-514 (2) 613-76-513 (2) 613-75-513 (2)22 RUBBER SPACER 688-73D-840 (2) 688-75A-840 (2) 688-75B-840 (2)23 PACKING ELEMENT* 688-73D-513 613-76-511 613-75-51124 RUBBER RETAINER 688-73D-850 688-75A-850 688-75B-85025 CONE 680-73D-410 680-75B-410 680-75B-41026 CARBIDE SLIP* 688-73D-125 (4) 688-75B-115 (4) 688-75B-115 (4)27 SLIP SCREW*10-24 X 3/8"NP 004-03-006 (4) 004-03-006 (4) 004-03-006 (4)28 SLIP SPRING* 688-73D-956 (8) 688-73D-956 (8) 688-73D-956 (8)29 CONTROL BODY** 688-73D-335 688-75B-335 688-75B-33530 DRAG BLOCK* 090-60-90P (6) 090-80-90P (6) 090-70-90P (6)31 DRAG BLOCK SPRING* 091-01-900 (36) 091-01-900 (36) 091-01-900 (36)32 DRAG BLOCK RETAINER 680-73D-910 688-75B-910 688-75B-91033 TORQUE SCREW*5/8-11 X 1/2" 021-C8-008 (4) 021-C8-008 (4) 021-C8-008 (4)34 J-BODY** 688-73D-351 688-73D-351 688-73D-35135 TORQUE SCREW*5/8-11 X 3/4" 021-C10-010 (3) 021-C10-010 (3) 021-C10-010 (3)36 O-RING* 050-A9-338 050-90-338 050-90-33837 BACK-UP RING* 045-00-338 (2) 045-00-338 (2) 045-00-338 (2)38 BOTTOM SUB** 688-73D-620 688-73D-620 688-73D-620

ITEM NO.

DESCRIPTION




688-73B THRU 73D-001688-75A & 75B

PAGE: 4 OF 4

REV. 00/DTD: 11-11-99

FIELD ADAPTATION INSTRUCTIONS EXAMPLE # 1

READ ALL NOTES BEFORE ASSEMBLY When counterbores exist and tapped holes are needed

EXAMPLE # 1**IMPORTANT**

Be sure to scribe a line for each of the four (4)counter bores before disassembly.

NOTES:1.) First, scribe a line on existing component in line with ALL counterbores. (See fig. A)

2.) Next, take a measurement from shoulder to the center of the counterbore and make a note of dimension “A”. (See fig. A)

3.) After noting the dimension, assemble the two components, (See fig. B) and torque to specs. (1,000 – 1,200 ft. lbs.)

4.) Next, after torque requirements have been met, mark a scribe line in line with the other line on the replacement part. (See fig. B)

5.) Transfer dim “A” to the replacement part, (See fig. A) and mark a scribe line. See dim. “B” on (fig. C).

6.) Last, disassemble components. Part is now ready to be tapped.

EXAMPLE # 2

When counterbores do not exist, but tapped holes are present.

NOTES:

1.) Assemble the two components as shown and torque to specs.

2.) Once the components have been shouldered and torque to spec. A center punch can be used to mark all holes to be counterbored. (See Fig. B).

3.) Last, disassemble components. All counterbores are now ready to be milled. Refer to (Fig. C) for counterbore dimensions and location.

INDEX NO.: 400UNIT NO.: 688-94PN: 688-94-000

688-95-001688-96-001

PAGE: 1 OF 2


9-5/8” DLT RETRIEVABLE PACKER

The Weatherford DLT Packer is a compression set packer with hydraulic hold down that is designedto provide an extra measure of dependability for rugged service. The hydraulic actuated upper holddown provides more than the usual surface area to assure the packer will not move up the hole. TheDLT includes the same reliable features as our C-5 packers. It is ideally suited for high pressure,high temperature service work. Some unique features of the DLT include positive rotational locks onall internal connections, which allow for extreme values of torque (left or right hand) to be transmittedthrough the packer. Back-up rings on all the o-rings provide for more reliable sealing at hightemperature and pressure. The DLT also comes with extra long top and bottom subs, which allow forhydraulic tong make-up and break out.

SPECIFICATION GUIDE

9-5/8 58.4 - 59.4 8.407 8.435 8.250 3.750 4-1/2" IF 688-94-0009-5/8 43.5 - 53.5 8.535 8.755 8.365 3.750 4-1/2" IF 688-95-0019-5/8 32.3 - 43.5 8.755 9.001 8.584 3.750 4-1/2" IF 688-96-001

PRODUCT NUMBER

CASING

O.D. (IN.)

WEIGHT (LBS./FT.)

RECOMMENDED CASING RANGE

THREAD CONNECTION

BOX UP PIN DOWN

MIN. I.D. OF

TOOL

MAX. O.D. OF

TOOLMAX. (IN.)

MIN. (IN.)


SETTING PROCEDURES

Run the DLT packer to setting depth in conjunction with a Type V-III Unloader. The unloader shouldremain open while running in. Pick up the tubing and rotate it ¼ turn to the right at the packer. Slackoff weight on the packer to set the slips and compress the packing elements (see setting forcesguide). Release the torque after slacking off 6” to allow the unloader to close and lock. The set d

DLT PACKER V-III UNLOADEV-III UNLOADERR STORM...

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