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(1)PRODUCT INFORMATION. DLT PACKER V-III UNLOADER STORM VALVE  Weatherford Completion Systems 2000 United Kingdom Address: Weatherford House • Lawson Road • Dyce • Aberdeen • Scotland • AB21 0GL • Phone: +44 (0)1224 770123 • Fax: +44 (0)1224 771309.

(2) SERVICE TOOLS. DLT RETRIEVABLE PACKER The DLT Retrievable Packer is a compression set packer with hydraulic hold down that is designed to provide an extra measure of dependability for rugged service. The hydraulic actuated upper slips provide more than the usual surface area to assure the packer will not move 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 PROCEDURE Run the DLT to setting depth in conjunction with a Type ‘V-III’ Unloader. The Unloader should remain 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 the torque after slacking off 6” to allow the unloader to close and lock. The set down weight must remain on the packer throughout well operation.. RELEASING PROCEDURE Rotate the tubing 1/4 turn to the right and pick up on the tubing to open the unloader. Allow time for the tubing and casing pressures to equalise. Continued upward movement of the tubing relaxes the packing elements, unsets the slips, and automatically re-jays the packer. The tool may now be moved and reset or pulled from the well.. DLT SPECIFICATION GUIDE CASING O.D. in/ 4 1/2” 5 5 1/2 7. 9 5/8. 10 3/4 11 3/4 13 3/8. PACKER WEIGHT (#/ft) 11.6 – 13.5 15.1 – 16.9 11.5 – 15.0 15.0 – 18.0 17.0 – 23.0 26.0 – 32.0 32.0 – 38.0 38.0 – 46.4 32.3 – 43.5 43.5 – 53.5 58.4 – 59.4 51.0 – 55.5 60.7 – 65.7 71.1 – 73.2 60.0 – 71.0 48.0 – 77.0. PRODUCT NUMBER 688-46-000 688-45-000 688-50-000 688-51-000 688-55B-000 688-73A-001 688-73B-001 688-73C-001 688-73D-001 688-96-000 688-95-000 688-94-000 688-10A-000 688-10B-000 688-10C-000 688-11B-000 688-13-000. ADDITIONAL SIZES AVAILABLE UPON REQUEST * 13 3/8” DLT – 8000 psi differential.  Weatherford Completion Systems 2000. DLT.

(3) DLT RETRIEVABLE PACKER OPTIONAL ELASTOMERS. 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 Bromide Calcium Bromide. 90(Fluorel)-80(Aflas)-90(Fluorel). Aflas. Max 350 deg F. Good - Excellent. Good - Excellent. Zinc Bromide Calcium Bromide. 90-80-90(Aflas). Aflas. Max 400 deg F. Excellent. Excellent. Zinc Bromide Calcium Bromide Cesium Formate. Problems:. Nitrile / HSN. :. Organic Solvents Some Oils. Fluorel. :. Formulation Some Gases. Aflas. :. Low Temperatures (<100 deg F).  Weatherford Completion Systems 2000.

(4) DLT RETRIEVABLE PACKER MINIMUM SETTING WEIGHTS FOR DLT PACKERS. MINIMUM SETTING WEIGHTS FOR DLT PACKERS SIZE (in). MIN. WEIGHT REQUIRED AT PACKER (lbs). HANG-OFF WEIGHT (lbs). MAX. TORQUE TRANSMITTED THROUGH TOOL (lbs). MAX. WORKING DIFFERENTIAL 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 allowable pressure 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 psi differential collapse pressure and 18,472 psi differential burst pressure. However, the above table shows a maximum working differential of 10,000 psi. Therefore the maximum differential burst pressure is 10,000 psi and the maximum differential collapse pressure is 7,500 psi..  Weatherford Completion Systems 2000.

(5) SERVICE TOOLS. V-III COMPRESSION UNLOADER 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 in the open position. After the packer is run to setting depth, the procedures required to set the packer will automatically close the V-III Unloader. The standard V-III slot locks in both the open and closed positions. With the packer set and the unloader closed, well operation may 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 and then picking up, (standard slot is right hand close, right hand open) After opening the unloader, allow differential pressure to equalise before releasing 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 and Packer.. V-III UNLOADER SPECIFICATION GUIDE Nominal Tubing Size. MAX. O.D. OF TOOL. MIN. I.D. OF TOOL. (in/mm). (in/mm). (in/mm). 2 3/8. 3.500 88,90. 1.750 44,45 2.000 50,80. 3.750 95,25. 2.500 63,50. 4.500 114,30 5.500 139,70. 2.500 63,50 2.688 68,28. 2 7/8. 3 1/2 4 1/2. TUBING THREAD. BASE PRODUCT NUMBER. 2 3/8 I.F.. 527-20. 2 3/8 EU 8RD. 529-20. 2 7/8 I.F.. 527-25. 2 7/8 EU 8RD. 529-25. 3 1/2 I.F.. 527-35. 4 1/2 I.F.. 527-45. ADDITIONAL SIZES AVAILABLE ON REQUEST. SERVICE TOOL SPECIFICATIONS FOR V-III UNLOADER TOOL TYPE. MAXIMUM TENSILE LOAD (lbs). MAXIMUM J-PIN WORKING LOAD (lbs). MAXIMUM WORKING DIFFERENTIAL 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.  Weatherford Completion Systems 1999.

(6) SERVICE TOOLS. STORM VALVE The Storm Valve is normally run above a compression set packer similar to a C/5, DC-5 and DLT packers. The Storm Valve provides means of disconnecting the drillpipe or tubing close to the surface without tripping the entire string. It is useful in situations where the rig must be abandoned quickly. The Storm Valve remains closed, providing a secure seal until the drillpipe or tubing is re-connected. OPERATION Normal well conditions will allow ample drill pipe to be run below the storm packer for proper weight and for proper well circulation. If the drill 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 tong tight 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 mating parts. Hand rotate twenty (20) rounds to the right. Tighten drill pipe connection holding back-ups on the top connector. Remove tongs and continue hand make-up of the back-off sub and tighten as you would any safety joint. Check the left hand break out several times, assuring proper torque. CAUTION:. DO NOT LIFT DRILL STRING UNTIL BACK-OUT THREADS ARE FULLY ENGAGED. SET AND BACK-OUT PROCEDURE After 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 to 1/2 the pressure required to shear pump out plug. Bleed to zero (0). An additional twelve (12) rounds will totally release from tool.. RE-CONNECT Lower 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 and casing 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 to zero (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 is recommended 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 in place.. STORM VALVE SPECIFICATION GUIDE SIZE. MAX. O.D. OF TOOL. (in). (in). 4 3/4 6 1/8. THREAD CONNECTION BOX UP / PIN DOWN. BASE PRODUCT NUMBER. 5.469. 3 1/2 I.F.. 682-10. 7.900. 4 1/2 I.F.. 682-20. SERVICE TOOL SPECIFICATIONS FOR V-III UNLOADER & STORM VALVE TOOL TYPE. MAXIMUM TENSILE LOAD (lbs). MAXIMUM J-PIN WORKING LOAD (lbs). MAXIMUM WORKING DIFFERENTIAL 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  Weatherford Completion Systems 2000.

(7) STORM VALVE SPECIFICATION GUIDE. 4 3/4” STORM VALVE SPECIFICATION GUIDE SIZE (in/). MAX. O.D. OF TOOL (in/). THREAD CONNECTION BOX UP / PIN DOWN. BASE PRODUCT NUMBER. 4 3/4. 5.469. 3 1/2 I.F.. 682-10. 4 3/4” STORM VALVE OPTIONS OPTIONAL GAUGE RING. PART NUMBER. O.D. (in). 682-65D-830. 4.950. 682-73D-830. 5.469. 6 1/8” STORM VALVE SPECIFICATION GUIDE SIZE (in). MAX. O.D. OF TOOL (in). THREAD CONNECTION BOX UP / PIN DOWN. BASE PRODUCT NUMBER. 6 1/8. 7.900. 4 1/2 I.F.. 682-20. 6 1/8” STORM VALVE OPTIONS OPTIONAL GAUGE RING. OPTIONAL SHEAR PINS. PART NUMBER. O.D. (in). 682-95-830. 7.900. 682-13-830. 11.000. PART NUMBER. SHEAR (psi). 682-20-910. 1500. 682-20-901. 6000.  Weatherford Completion Systems 2000.

(8) SERVICE TOOLS. DLT, V-III UNLOADER & STORM VALVE PERFORMANCE ENVELOPES UNDER BI-AXIAL LOADING. The performance envelopes produced by Weatherford Completion Services are intended to serve as a guideline for safe, reliable performance. Operation of Weatherford equipment in environments that are within the defined envelope is considered to be recommended service. Operation of the equipment outside the defined envelope is not recommended without first seeking expert advice from Weatherford personnel. The envelopes are produced by first analysing the product and identifying the weakest metallic component. This material cross section of the weakest component is then entered into the envelope program. The results of the program are printed in a chart form that is easy to use. The effect of combined loading, for example, tension and collapse 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 a conservative estimation of the strengths of the components. This conservative view is intentionally devised to keep the operator out of trouble. If a specific job requires operation of the equipment outside the envelope, Weatherford technical personnel will evaluate the situation and make necessary recommendations. It is important to note that these performance envelopes are representative of individual metallic strengths when subjected to loads. These components are listed in the information above the chart. The envelopes do not necessarily represent the entire product performance. In many of our products, the elastomers, however, are not considered in these performance envelopes. With proper understanding, these envelopes can be a very useful tool in predicting safe product operation. It is always recommended, however, that the operator asks questions any time situations arise when there is not a clear understanding of the product performance capabilities.. The information contained herein shall be considered the property of Weatherford Completion Systems, and the recipient agrees not to disclose the said information without written consent..  Weatherford Completion Systems 2000.

(9) DLT RETRIEVABLE PACKER Identification: Project: Critical component: Description:. 5” DLT Packer Mandrel Mandrel Strength – tubing open. Part No.: 688-50-210. Dimensional data: Minimum O.D.: Maximum I.D.: Material Yield:. 2.497 in. 2.145 in. 110,000 psi. Area: Minimum Wall: D/t:. Performance Envelope:. Internal Yield (Py): Collapse (Pc): Tensile pipe body (Ty):. 13,568 psi 12,800 psi 141,166 lbs. 1.283 in. 0.176 in. 14.188. If tubing plugged: (Py) = 10,641 (Pc) = 7,479. 20000. 15000. Internal Yield 13,568. 10000. Compression 141,166. Tension 141,166. 5000. 0 -250000. -200000. -150000. -100000. -50000. 50000. 100000. -5000. -10000. -15000. Collapse 12,800. -20000  Weatherford Completion Systems 2000. 1500000. 200000. 250000.

(10) DLT RETRIEVABLE PACKER Identification: Project: Critical component: Description:. 7” DLT Packer Mandrel Mandrel Strength – tubing open. Part No.: 688-73D-210. Dimensional data: Minimum O.D.: Maximum I.D.: Material Yield:. 3.740 in. 3.250 in. 110,000 psi. Area: Minimum Wall: D/t:. Performance Envelope: Internal Yield (Py): Collapse (Pc): Tensile pipe body (Ty):. 12,610 psi 11,056 psi 295,907 lbs. 2.690 in. 0.245 in. 15.265. If tubing plugged: Same Pressure as Open Tubing 20000. 15000. Internal Yield 12,610. 10000. Compression 295,907. Tension 295,907. 5000. 0 -500000. -400000. -300000. -200000. -100000. 100000. 200000. -5000. -10000. -15000. Collapse 11,056. -20000  Weatherford Completion Systems 2000. 300000. 400000. 500000.

(11) DLT RETRIEVABLE PACKER Identification: Project: Critical component: Description:. 9 5/8” DLT Packer Mandrel Mandrel Strength – tubing open. Part No.: 688-95-210. Dimensional data: Minimum O.D.: Maximum I.D.: Material Yield:. 5.276 in. 4.640 in. 125,000 psi. Area: Minimum Wall: D/t:. Performance Envelope:. Internal Yield (Py): Collapse (Pc): Tensile pipe body (Ty):. 13,185 psi 9,913 psi 451,868 lbs. 4.953 in. 0.318 in. 16.591. If tubing plugged: (Py) = 10,278 psi (Pc) = 6,820 psi 20000. 15000. Internal Yield 13,185. 10000. Compression 451,868. Tension 451,868. 5000. 0 -500000. -400000. -300000. -200000. -100000. 100000. 200000. -5000. -10000. Collapse 9,913. -15000 -20000  Weatherford Completion Systems 2000. 300000. 400000. 500000.

(12) DLT RETRIEVABLE PACKER Identification: Project: Critical component: Description:. 13 3/8” DLT Packer Mandrel Mandrel Strength – tubing open. Part No.: 688-13-210. Dimensional data: Minimum O.D.: Maximum I.D.: Material Yield:. 8.247 in. 7.015 in. 110,000 psi. Area: Minimum Wall: D/t:. Performance Envelope:. Internal Yield (Py): Collapse (Pc): Tensile pipe body (Ty):. 14,379 psi 14,272 psi 1,624,444 lbs. 14.768 in. 0.616 in. 13.388. If tubing plugged: (Py) = 10,844 (Pc) = 7,849. 20000. 15000. Internal Yield 14,379. 10000. Compression 1,624,444. Tension 1,624,444. 5000. 0 -2500000 -2000000 -1500000 -1000000. -500000. 500000. 1000000. -5000. -10000. -15000. Collapse 14,272. -20000  Weatherford Completion Systems 2000. 1500000. 2000000. 2500000.

(13) V-III COMPRESSION UNLOADER Identification: Project: Critical component: Description:. 2 3/8” V-III Unloader Mandrel Mandrel Strength. Part No.: 527-20-210. Dimensional data: Minimum O.D.: Maximum I.D.: Material Yield:. 2.240 in. 1.765 in. 110,000 psi. Area: Minimum Wall: D/t:. Performance Envelope: Internal Yield (Py): Collapse (Pc): Tensile pipe body (Ty):. 20,410 psi 20,853 psi 164,353 lbs. 1.494 in. 0.2375 in. 9.432. J-Pin Working Load is 75,000 lbs. Tailpipe limit 125,000 lbs.. 40000. 30000. Internal Yield 20,410. 20000. 10000. Compression 164,353 -250000. -200000. -150000. Tension 164,353. 0 -100000. -50000. 50000. 100000. -10000. -20000. -30000. Collapse 20,853. -40000  Weatherford Completion Systems 1999. 1500000. 200000. 250000.

(14) V-III COMPRESSION UNLOADER Identification: Project: Critical component: Description:. 3 1/2” V-III Unloader Mandrel Mandrel Strength. Part No.: 527-35-216. Dimensional data: Minimum O.D.: Maximum I.D.: Material Yield:. 3.459 in. 2.703 in. 110,000 psi. Area: Minimum Wall: D/t:. Performance Envelope: Internal Yield (Py): Collapse (Pc): Tensile pipe body (Ty):. 21,036 psi 21,414 psi 402,463 lbs. 3.659 in. 0.378 in. 9.151. J-Pin Working Load is 110,000 lbs. Tailpipe limit 246,800 lbs.. 40000. 30000. Internal Yield 21,036. 20000. 10000. Compression 402,463 -500000. -400000. Tension 402,463. 0 -300000. -200000. -100000. 100000. 200000. -10000. -20000. -30000. Collapse 21,414. -40000  Weatherford Completion Systems 2000. 3000000. 400000. 500000.

(15) V-III COMPRESSION UNLOADER Identification: Project: Critical component: Description:. 4 1/2” V-III Unloader Mandrel Mandrel Strength. Part No.: 527-45-216. Dimensional data: Minimum O.D.: Maximum I.D.: Material Yield:. 4.553 in. 3.765 in. 110,000 psi. Area: Minimum Wall: D/t:. Performance Envelope: Internal Yield (Py): Collapse (Pc): Tensile pipe body (Ty):. 16,658 psi 17,391 psi 402,463 lbs. 5.148 in. 0.394 in. 11.556. J-Pin Working Load is 150,000 lbs. Tailpipe limit 300,000 lbs.. 40000. 30000. Internal Yield 21,036. 20000. 10000. Compression 402,463 -500000. -400000. Tension 402,463. 0 -300000. -200000. -100000. 100000. 200000. -10000. -20000. -30000. Collapse 21,414. -40000  Weatherford Completion Systems 2000. 3000000. 400000. 500000.

(16) STORM VALVE Identification: Project: Critical component: Description:. 4 3/4” Storm Valve Body Body Strength. Part No.: 682-10-635. Dimensional data: Minimum O.D.: Maximum I.D.: Material Yield:. 4.740 in. 3.916 in. 110,000 psi. Area: Minimum Wall: D/t:. Performance Envelope: Internal Yield (Py): Collapse (Pc): Tensile pipe body (Ty):. 16,732 psi 17,460 psi 616,208 lbs. 5.602 in. 0.412 in. 11.505. The plug is pumped out in this condition. 20000. Internal Yield 16,732. 15000. 10000. Compression 616,208. Tension 616,208. 5000. 0 -1000000. -800000. -600000. -400000. -200000. 200000. 400000. -5000. -10000. -15000 -20000. Collapse 17,460.  Weatherford Completion Systems 2000. 600000. 800000. 1000000.

(17) STORM VALVE Identification: Project: Critical component: Description:. 6 1/8” Storm Valve Seal Mandrel Mandrel Strength. Part No.: 682-20-610. Dimensional data: Minimum O.D.: Maximum I.D.: Material Yield:. 4.928 in. 3.765 in. 110,000 psi. Area: Minimum Wall: D/t:. Performance Envelope: Internal Yield (Py): Collapse (Pc): Tensile pipe body (Ty):. 22,715 psi 22,897 psi 873,438 lbs. 7.940 in. 0.5815 in. 8.475. The plug is pumped out in this condition. 40000. 30000. Internal Yield 16,732. 20000. 10000. Compression 616,208. Tension 616,208. 0 -1000000. -800000. -600000. -400000. -200000. 200000. 400000. -10000. -20000. -30000. Collapse 22,897. -40000  Weatherford Completion Systems 2000. 600000. 800000. 1000000.

(18) SERVICE TOOLS. DLT RETRIEVABLE PACKER PROCEDURES. 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 data 2. Packer function test. APPENDIX 3. :. 1. Tool joint torque requirements 2. Trouble shooting  Weatherford Completion Systems 2000.

(19) 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 circulated clean prior to running the tools and/or spot a hi-vis pill over the packer especially if it is to be left in the hole 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..

(20) 2.. RIH and set DLT Packer:. 2.1. Make up and RIH with drill collars/pipe to give suitable buoyancy compensated weight below the tool to keep the packer set. This drill pipe/collar string will be run below the DLT Packer. The total weight/length of drill pipe/collars run will depend upon the setting weight required - see section 5, for minimum weights set on each tool.. 2.2. 2.3. Pick up DLT Packer with 6-1/8” Storm Valve and run in hole. Ensure correct torque is applied and the Storm Valve back-off sub is only hand right prior to running in hole. (Note: When running 7” tools and smaller 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 as possible in mouse hole.. -. Make up Storm Valve on the DLT Packer, use racking arms and tugger lines to keep tools vertical 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 torque up.. -. 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 breaking joint remaking.. 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 passing through 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 bypass or unloader on DLT Packer). 2.4. Test DLT Packer as soon as possible below wellhead: Set packer by picking up 5 ft, rotating tool string 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..

(21) 2.6. Pick back up 10 - 20 ft to place packing elements of packer at required setting depth: record string 'up weight'. (This depth may be adjusted for ease of setting operations on the drill floor or to compensate to 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 packer setting 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 4000 lbs are required to turn the string the setting procedure should be altered. When picking up to setting depth the right hand torque should be applied, as the string is moving this lower the force required to turn the drill string. The torque should be held as setting depth reached and then lower string with torque still applied.. 2.8. When the packer begins to take weight, release the right hand torque and slack off the weight of the B.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..

(22) 3.. Back-off Storm Valve to suspend well: Note: Maximum setting depth for Storm Valve is 2000 ft for deeper application a bridge plug should be 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 and the 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. Bleed off 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 from the Storm Valve slowly.. 3.5. -. 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.. POOH and inspect Storm Valve stinger sub at surface for damage or missing O-rings..

(23) 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; pressure may be trapped below Storm Valve and may need to be controlled/bled off when valve is engaged/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 'up weight' 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 in torque is noticed then stop rotation. After about 12 turns (valve starting to open) watch carefully for an indication of pressure trapped below the packer.. 4.9. -. 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 is opened and pressure moved into the drill string above the valve, do not proceed with unseating the packer until the OIM / DSV is informed. Well kill procedures should then be followed.. -. The packer cannot be un-set with positive pressure in the drill string as this will cause the upper packer slips to engage the casing. The annulus above the Packer should be pressurised to give a positive differential pressure (about 500 psi) from the annulus to drill pipe across the packer elements.. -. Observe for any pressure trapped below the tools and bleed off accordingly.. Once all pressures balanced or zero, pick-up to string 'up weight' then another 5 ft to de-energise packing 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 be made at this time. Circulation rates will not be a problem so long as no losses occur..

(24) 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 for slips 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 Plug conversion for the DLT Packer. When a tool is needed to plug the well at depths in excess of 2000 ft the proper size Bridge plug should be used..

(25) 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 procedures should be implemented. -. The weight of pipe to be hung off below the Packer will have to be calculated to take into account the pipe lying on the side of the casing and the drag this creates. These effects will all 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 the Storm Valve when backing off.. -. When setting the packer torque may have to be worked into the string. This is done by putting a couple of turns to the right into the string at a time and working them in by lowering the string to 20,000 lbs from the down weight, then pulling back up to 20,000 lbs from the up weight. Do this several times and then pull back up to the up weight and put another couple of turns into the string until the full turns have been worked into the string. Now the string may be lowered to see if the packer will take weight..

(26) 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 circulated clean prior to running the tool.. 1.3. Before running tools hydraulics calculations must be performed to decide what pipe has to be run and what 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 the bottom of the hole..

(27) 2.. RIH and set DLT Packer:. 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 weight above the packer to set down for the pressure test. If this is the case just run a joint or stand of pipe below the tools to guide them through the wellhead/BOP’s.. 2.2. 2.3. 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 as possible in mouse hole.. -. Make up VIII Unloader on to the DLT Packer, use racking arms and tugger lines to keep tools vertical 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.. RIH with tool assembly. -. 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 passing through 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 1/4 turn 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. The Packer should now be unset and the VIII Unloader open. Before running to test depth wait for 5 to 10 minutes to ensure elements have contracted fully..

(28) 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 release the torque and continue to slack off required weight onto tool for pressure test to compensate hydraulics.. -. Close annular preventor and perform casing pressure test..

(29) 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 the right hand torque used to set the packer was let out then 1 turn per 3000 ft depth to the right will 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 stand and watch the wall does not swab in..

(30) 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 Unloader to 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 clean prior 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.. 1.5. Perform all necessary calculations prior to job..

(31) 2.. RIH and set DLT Packer:. 2.1. Pick up DLT Packer with 4-1/2” VIII Unloader and run in hole. Ensure correct torques are applied and that 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 will take 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. 2.2. RIH with tool assembly. -. 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 passing through 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..

(32) 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 the required 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 and hold 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 the pressure 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 locked in the string to allow the packer to be set by just lowering the drill string again, until weight drops off the 'down weight'. If this does not reset the packer then the full setting procedure will have to be repeated.. -. Once packer is set, bleed down surface pressure in the drill string to perform inflow test on liner lap.. During this operation watch the level of fluid outside the drill string. If this level drops as the inside of the drill sting is bled off, then the unloader may still be open. Pressure up the drill pipe to stabilise the well and unset, then reset the packer. Follow inflow steps again..

(33) 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 10 minutes.. 4.3. POOH and break out tools at surface in same manner as made up..

(34) SECTION D : Outline:. DLT Packer: Inflow testing liner lap with open perforation, etc. This procedure has been designed for running a 7" DLT Packer with a 3 1/2" VIII Unloader into and old liner which is perforated, has a leaking shoe etc., to pressure test and inflow test the 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 circulated clean prior to running the tools and/or spot a hi-vis pill over the packer especially if it is to be left in the hole 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 packer operations to be performed without obstruction.. 1.6. -. When inflow testing on a floater, space-out is not a problem, whether equipped with a top drive or a kelly (BOP's on sea bed). Space-out should be planned to place the middle of a joint of drill pipe across the annular preventor, when the packer is set. This will allow the packer to be unset with the annular preventor closed while circulating to seawater under controlled 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 equipped with 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 there will be a +/- 20ft between the rotary table and the top of the BOP's. When the kelly bushings are engaged there will be +/- 6ft from the rotary table to the bottom of the first tool joint. With this short space available, the setting procedure must be altered. To set the packer the kelly bushings 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 string to set it, then start to lower the string until the packer starts to take weight. Putting the turns into the string with as much of the kelly out of the hole as possible will leave +/- 14ft to lower the string to set the packer while leaving the middle of the DP across the BOP's.. Perform all necessary calculations prior to job..

(35) 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 that 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 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 will travel high enough to take the extra height of the tools. If they will not, then make up a single or 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 packer See 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 passing through 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 the elements. 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.

(36) 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 at the 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 hold torque 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 to compensate 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 will allow 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 keep circulating 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 onto packer to compress elements..

(37) 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 another 5ft or as much as the kelly will allow. If more height is required, torque may now be released from 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..

(38) SERVICE TOOLS. DLT RETRIEVABLE PACKER APPENDIX : 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 2.75 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..  Weatherford Completion Systems 2000.

(39) SERVICE TOOLS. DLT RETRIEVABLE PACKER APPENDIX : 1. BUOYANCY / DEVIATION FACTOR. 0.9. Straight Hole. 0.8 20 Deg dev 0.7. 0.5 0.4 0.3. 30 Deg dev BUOYANCY FACTOR. 0.6. 40 Deg dev. 50 Deg dev 60 Deg dev. 0.2 0.1 0 8. 10. 12. 14. 16. 18. 70 Deg dev 80 Deg dev. 20. MUD WEIGHT (PPG) This chart has been made up to give a buoyancy factor which compensates for hole deviation which will reduce the neutral weight of pipe. To use this chart the mud weight in the hole deviation must be known..  Weatherford Completion Systems 2000.

(40) SERVICE TOOLS. DLT RETRIEVABLE PACKER APPENDIX : 2 1.. Pre-job meeting data MD (ft). TVD (ft). Incl. (deg). BHST (degF). MD (ft). TVD (ft). Weight (lb./ft). Min ID (in.). Grade. MD (ft). O.D. (in). Weight (lb./ft). Min ID (in). Conn / Thread. Packer Setting Depth(s). Previous Casing Casing Liner. Drill pipe / Tubing. Mud Wt (ppg). 2.. Well Head depth:. Hang-off weight:. 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 out of safety as it is picked up with a tugger to check the slips are functional.  Weatherford Completion Systems 2000.

(41) SERVICE TOOLS. DLT RETRIEVABLE PACKER APPENDIX : 3 1.. Required tool joint torque values TOOL JOINT SIZE 4 1/2" I.F. 3 1/2" I.F.. 2.. TORQUE VALUE 22-24,000 ft lbs. 12-13,000 ft lbs.. Troubleshooting PROBLEM. Tools will not pass through wellhead Packer will not pressure test Unloader will not close Unloader will not open Packer will not set Storm valve will not pressure test after screwing out. Storm valve cannot be screwed into at all. Full 21 turns cannot be put into Storm valve. Packer causes excessive drag after being set for a long time. DLT packer will not unset.. POSSIBLE SOLUTION Pull tools back to surface and inspect for defects. Check minimum I.D. of wellhead / wear bushing etc. 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. Unset packer and repeat setting procedure. Reset packer, hold torque in string and unset packer again. This should open the unloader. Repeat setting procedure. If setting in deep deviated hole, work torque into string. Try slacking off weight onto tool quicker. Check for surface leaks Screw back into valve, then screw out again. If this does not solve the problem, retrieve packer and pull back to surface. Strip tool. Repeat well suspension procedures 3.3 onwards 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 pull back to surface without getting the full 21 turns. 10 turns should be the minimum, but less may be adequate in extreme circumstances, depending on the weight of pipe below and drag. CAUTION! Always remember there may be pressure trapped below the packer which will not be seen until the Storm valve is open. The valve does not start to open until 12 turns have been made. Work string several times between ‘up-weight’ and neutral weight at packer. This should let the elements contract which may be extruded over the bottom gauge ring of the packer. 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 psi above the packer..  Weatherford Completion Systems 2000.

(42) INDEX NO.: 400 UNIT NO.: 688-45 PN: 688-45 & 46 PAGE: 1 OF 2. 4-1/2” X 2-3/8” DLT RETRIEVABLE PACKER. DISASSEMBLY. The Weatherford DLT Packer is a compression set packer with hydraulic hold down that is designed to provide an extra measure of dependability for rugged service. The hydraulic actuated upper hold down provides more than the usual surface area to assure the packer will not move up the hole. The DLT 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 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 provide for more reliable sealing at high temperature and pressure. The DLT also comes with extra long top and bottom subs, which allow for hydraulic tong make-up and break out.. 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 down straps (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.. SPECIFICATION GUIDE CASING O.D. (IN.) 4-1/2 4-1/2. WEIGHT (LBS./FT.) 11.6 - 13.5 15.1 - 17.7. RECOMMENDED CASING RANGE MIN. MAX. (IN.) (IN.) 3.920 4.000 3.696 3.826. MAX. O.D. OF TOOL 3.781 3.593. MIN. I.D. OF TOOL 1.750 1.750. THREAD CONNECTION BOX UP PIN DOWN 2-3/8" IF 2-3/8" IF. PRODUCT NUMBER 688-45 688-46. 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 should remain open while running in. Pick up the tubing and rotate it ¼ turn to the right at the packer. Slack off weight on the packer to set the slips and compress the packing elements (see setting forces guide). Release the torque after slacking off 6” to allow the unloader to close and lock. The set down weight must remain on the packer throughout well operation.. 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.. RELEASING PROCEDURES Rotate the tubing ¼ turn to the right and pick up on the tubing to open the V-III Unloader. Allow time for the tubing and casing pressures to equalize. Continued upward movement of the tubing relaxes the packing elements, un-sets the slips, and automatically re-jays the packer. The tool may now be moved and reset or pulled from the well.. 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 SETTING FORCES GUIDE SIZE (IN.) 4-1/2. MINIMUM WEIGHT REQUIRED AT THE PACKER (LBS.) 10,000. CLASSIFICATION LOW TEMPERATURE STANDARD TOOL MODERATE TEMP. HIGH TEMPERATURE. TEMP. RANGE 60 - 125 125 - 225 225 -275 275 - UP. ELEMENT DURO END MIDDLE END 80 60 80 90 70 90 90 80 90 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. REV. 00/DTD: 11-08-99.

(43) INDEX NO.: 400 UNIT NO.: 688-45 PN: 688-45 & 46 PAGE: 2 OF 2. PARTS LIST ITEM N0. 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18. PARTS LIST 4-1/2" 11.6 - 13.5 688-45 688-45-610 050-90-226 045-01-226 (2) 688-50-280 050-90-231 (2) 045-00-231 (4) 021-C8-007 (4) 688-45-311 688-45-370 688-45-360 053-01-129 (6) 688-45-975 (12) 688-45-980 (6) 005-03-006 (3) 688-45-210 021-C8-007 (4) 688-45-830 688-45-514 (2). DESCRIPTION TOP SUB** O-RING* BACK-UP RING* VOLUME TUBE O-RING* BACK-UP RING* TORQUE SCREW* HOLD DOWN BODY** HOLD DOWN CAP HOLD DOWN STRAP T-SEAL SLIP SPRING* CARBIDE BUTTON* SET SCREW* MANDREL** TORQUE SCREW* UPPER RETAINER CAP PACKING ELEMENT*. 4-1/2" 15.1 - 17.7 688-46 688-45-610 050-90-226 045-01-226 (2) 688-50-280 050-90-231 (2) 045-00-231 (4) 021-C8-007 (4) 688-46-310 688-46-370 688-45-360 053-01-129 (6) 688-45-975 (12) 688-46-980 (6) 005-03-006 (3) 688-45-210 021-C8-007 (4) 688-46-830 688-46-514 (2). DIMENSIONAL DATA CASING SIZE (IN.) 4-1/2 4-1/2. ITEM N0.. 4-1/2" 11.6 - 13.5 688-45 688-45-840 (2) 688-45-511 688-45-850 688-45-410 688-45-330 688-45-110 (4) 004-03-004 (4) 350-35-900 (8) 090-55-90P (4) 091-00-900 (16) 688-45-910 688-45-355 021-C8-007 (4) 021-C8-007 (4) 050-90-226 045-01-226 (2) 688-45-620. DESCRIPTION. 4-1/2" 15.1 - 17.7 688-46 688-46-840 (2) 688-46-511 688-46-850 688-45-410 688-45-330 688-46-110 (4) 004-03-004 (4) 350-35-900 (8) 090-55-90P (4) 091-00-900 (16) 688-45-910 688-45-355 021-C8-007 (4) 021-C8-007 (4) 050-90-226 045-01-226 (2) 688-45-620. 19 RUBBER SPACER 20 PACKIING ELEMENT* 21 RUBBER RETAINER 22 LOWER CONE 23 CONTROL BODY** 24 CARBIDE SLIP* 25 SET SCREW* 26 SLIP SPRING* 27 DRAG BLOCK* 28 DRAG BLOCK SPRING* 29 DRAG BLOCK RETAINER 30 J-BODY 31 TORQUE SCREW* 32 TORQUE SCREW* 33 O-RING* 34 BACK-UP RING* 35 BOTTOM SUB** *Common repair parts. **These parts are mated parts and cannot be replaced separately without field adaptation.. DIMENSIONAL DATA (cont.) DIMENSIONS (IN.). PRODUCT NUMBER. A. B. C. D. E. 688-45 688-46. 96.277 96.277. 18.292 18.292. 4.467 4.467. 2.000 2.000. 12.514 12.514. CASING SIZE (IN.) 4-1/2 4-1/2. DIMENSIONS (IN.). PRODUCT NUMBER. F. G. H. J. K. 688-45 688-46. 3.380 3.380. 1.750 1.750. 3.594 3.594. 3.781 3.593. 21.375 21.375. © 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.

(44) INDEX NO.: 400 UNIT NO.: 688-50 PN: 688-50 & 51 688-55 & 55B PAGE: 1 OF 3. 5” & 5-1/2” X 2-3/8” DLT RETRIEVABLE PACKER. DISASSEMBLY. The Weatherford DLT Packer is a compression set packer with hydraulic hold down that is designed to provide an extra measure of dependability for rugged service. The hydraulic actuated upper hold down provides more than the usual surface area to assure the packer will not move up the hole. The DLT 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 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 provide for more reliable sealing at high temperature and pressure. The DLT also comes with extra long top and bottom subs, which allow for hydraulic tong make-up and break out.. 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 inner mandrel (22). 10.) Remove upper retainer cap (16) from hold down body (3). Remove screws (12) from hold down straps (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 hold down 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.. SPECIFICATION GUIDE CASING O.D. (IN.) 5 5 5-1/2 5-1/2. WEIGHT (LBS./FT.) 11.5 - 15.0 15.0 - 18.0 13.0 - 17.0 17.0 - 23.0. RECOMMENDED CASING RANGE MIN. MAX. (IN.) (IN.) 4.408 4.560 4.276 4.408 4.892 5.044 4.670 4.892. MAX. O.D. OF TOOL 4.250 4.125 4.641 4.500. MIN. I.D. OF TOOL 1.750 1.750 1.750 1.750. THREAD CONNECTION PRODUCT NUMBER BOX UP PIN DOWN 2-3/8" IF 688-50 2-3/8" IF 688-51 2-3/8" IF 688-55 2-3/8" IF 688-55B. 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. CAUTION: If the DLT Packer is run with a retrievable bridge plug, make sure that the J-slots. Run the DLT packer to setting depth in conjunction with a Type V-III Unloader. The unloader should remain open while running in. Pick up the tubing and rotate it ¼ turn to the right at the packer. Slack off weight on the packer to set the slips and compress the packing elements (see setting forces guide). Release the torque after slacking off 6” to allow the unloader to close and lock. The set down weight must remain on the packer throughout well operation.. RELEASING PROCEDURES. SETTING FORCES GUIDE. 5 5-1/2. 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.. Rotate the tubing ¼ turn to the right and pick up on the tubing to open the V-III Unloader. Allow time for the tubing and casing pressures to equalize. Continued upward movement of the tubing relaxes the packing elements, un-sets the slips, and automatically re-jays the packer. The tool may now be moved and reset or pulled from the well.. SIZE (IN.). 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.. MINIMUM WEIGHT REQUIRED AT THE PACKER (LBS.) 10,000 15,000. 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.. PACKING ELEMENT GUIDE CLASSIFICATION LOW TEMPERATURE STANDARD TOOL MODERATE TEMP. HIGH TEMPERATURE. TEMP. RANGE 60 - 125 125 - 225 225 -275 275 - UP. ELEMENT DURO END MIDDLE END 80 60 80 90 70 90 90 80 90 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. REV. 00/DTD: 11-11-99.

(45) INDEX NO.: 400 UNIT NO.: 688-50 PN: 688- 50 &51 688-55 & 55B PAGE: 2 OF 3. PARTS LIST. PARTS LIST. ITEM N0. 1 2 3 4 5 6 7 8 9 10 11 12 13 14. 5" 11.5 - 15.0 688-50 688-50-610 688-50-370 688-50-310 021-C10-008 (8) 050-90-337 045-01-337 (2) 050-90-329 045-01-329 (2) 053-01-133 (6) 688-50-980 (6) 680-50-975 (12) 005-03-008 (3) 688-50-360 (3) 050-90-333. DESCRIPTION TOP SUB** HOLD DOWN CAP HOLD DOWN BODY** TORQUE SCREW* O-RING* BACK-UP RING* O-RING* BACK-UP RING* BUTTON T-SEAL* HOLD DOWN BUTTON* BUTTON SPRING* SET SCREW* HOLD DOWN STRAP O-RING*. 5" 15.0 - 18.0 688-51 688-50-610 688-50-370 688-50-310 021-C10-008 (8) 050-90-337 045-01-337 (2) 050-90-329 045-01-329 (2) 053-01-133 (6) 688-50-980 (6) 680-50-975 (12) 005-03-008 (3) 688-50-360 (3) 050-90-333. ITEM N0.. DIMENSIONAL DATA CASING SIZE (IN.) 5 5. BASE PRODUCT NUMBER 688-50 688-51. DIMENSIONS (IN.) A. B. C. D. E. F. G. 99.340 99.340. 43.000 43.000. 19.000 19.000. 1.750 1.750. 3.375 3.375. 4.125 4.125. 4.250 4.125. DESCRIPTION. 5" 11.5 - 15.0 688-50 045-01-333 (2) 688-50-830 688-50-280 650-50-514 (2) 650-50-840 (2) 650-50-511 688-50-850 688-50-210 688-50-410 688-50-330 680-50-110 (4) 004-03-006 (4) 450-55-900 (8) 090-56-90P (4) 091-00-900 (16) 688-50-910 688-50-355 021-C10-008 (4) 021-C10-008 (4) 050-90-329 045-01-329 (2) 688-50-620. 5" 15.0 - 18.0 688-51 045-01-333 (2) 688-51-830 688-50-280 602-50-513 (2) 601-50-840 (2) 602-50-511 688-51-850 688-50-210 688-50-410 688-50-330 680-50-110 (4) 004-03-006 (4) 450-55-900 (8) 090-56-90P (4) 091-00-900 (16) 688-50-910 688-50-355 021-C10-008 (4) 021-C10-008 (4) 050-90-329 045-01-329 (2) 688-50-620. 15 BACK-UP RING* 16 UPPER RETAINER CAP 17 VOLUME TUBE 18 PACKING ELEMENT* 19 RUBBER SPACER 20 PACKING ELEMENT* 21 LOWER RETAINER CAP 22 INNER MANDREL** 23 LOWER CONE 24 CONTROL BODY** 25 CARBIDE SLIP* 26 SET SCREW* 27 SLIP SPRING* 28 DRAG BLOCK* 29 DRAG BLOCK SPRING* 30 DRAG BLOCK RETAINER 31 J-BODY** 32 TORQUE SCREW* 33 TORQUE SCREW* 34 O-RING* 35 BACK-UP RING* 36 BOTTOM SUB** *Common repair parts. **These parts are mated parts and cannot be replaced separately without field adaptation.. © 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: 11-11-99.

(46) INDEX NO.: 400 UNIT NO.: 688-50 PN: 688-50 & 51 688-55 & 55B PAGE: 3 OF 3. PARTS LIST. PARTS LIST. ITEM N0. 1 2 3 4 5 6 7 8 9 10 11 12 13 14. 5-1/2" 13.0 - 17.0 688-55 688-55B-610 688-55-370 688-55B-310 021-C10-010 (8) 050-90-337 045-01-337 (2) 050-90-329 045-01-329 (2) 053-01-226 (6) 688-55-980 (6) 688-55-975 (18) 005-C5-006 (3) 680-55-360 (3) 050-90-333. DESCRIPTION TOP SUB** HOLD DOWN CAP HOLD DOWN BODY** TORQUE SCREW* O-RING* BACK-UP RING* O-RING* BACK-UP RING* BUTTON T-SEAL* HOLD DOWN BUTTON* BUTTON SPRING* SET SCREW* HOLD DOWN STRAP O-RING*. 5-1/2" 17.0 - 23.0 688-55B 688-55B-610 688-55B-370 688-55B-310 021-C10-010 (8) 050-90-337 045-01-337 (2) 050-90-329 045-01-329 (2) 053-01-226 (6) 688-55-980 (6) 688-55-975 (18) 005-C5-006 (3) 680-55-360 (3) 050-90-333. ITEM N0.. DIMENSIONAL DATA CASING SIZE (IN.) 5-1/2 5-1/2. DIMENSIONS (IN.). PRODUCT NUMBER. A. B. C. D. E. F. G. 688-55 688-55B. 99.218 99.218. 44.406 44.406. 22.531 22.531. 1.750 1.750. 3.380 3.380. 4.493 4.493. 4.641 4.500. DESCRIPTION. 5-1/2" 13.0 - 17.0 688-55 045-01-333 (2) 688-55-830 688-50-280 680-55-514 (2) 680-55-840 (2) 680-55-511 688-55-850 688-55B-210 688-55B-410 688-55B-330 680-55-110 (4) 004-03-004 (4) 350-55-956 (4) 090-55-90P (4) 091-00-900 (20) 688-55-910 688-55B-355 021-C10-010 (4) 021-C10-010 (3) 050-90-329 045-01-329 (2) 688-55B-620. 5-1/2" 17.0 - 23.0 688-55B 045-01-333 (2) 688-55B-830 688-50-280 680-56-514 (2) 680-56-840 (2) 680-56-511 688-55B-850 688-55B-210 688-55B-410 688-55B-330 680-55-110 (4) 004-03-004 (4) 350-55-956 (4) 090-55-90P (4) 091-00-900 (20) 688-55B-910 688-55B-355 021-C10-010 (4) 021-C10-010 (3) 050-90-329 045-01-329 (2) 688-55B-620. 15 BACK-UP RING* 16 UPPER RETAINER CAP 17 VOLUME TUBE 18 PACKING ELEMENT* 19 RUBBER SPACER 20 PACKING ELEMENT* 21 LOWER RETAINER CAP 22 INNER MANDREL** 23 LOWER CONE 24 CONTROL BODY** 25 CARBIDE SLIP* 26 SET SCREW* 27 SLIP SPRING* 28 DRAG BLOCK* 29 DRAG BLOCK SPRING* 30 DRAG BLOCK RETAINER 31 J-BODY** 32 TORQUE SCREW* 33 TORQUE SCREW* 34 O-RING* 35 BACK-UP RING* 36 BOTTOM SUB** *Common repair parts. **These parts are mated parts and cannot be replaced separately without field adaptation.. © 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: 11-11-99.

(47) INDEX NO.: 400 UNIT NO.: 688-73A PN: 688-73A-000 688-73B THRU 73D-001 688-75A & 75B PAGE: 1 OF 4. 7” & 7-5/8” DLT RETRIEVABLE PACKER. DISASSEMBLY. The Weatherford DLT Packer is a compression set packer with hydraulic hold down that is designed to provide an extra measure of dependability for rugged service. The hydraulic actuated upper hold down provides more than the usual surface area to assure the packer will not move up the hole. The DLT 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 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 provide for more reliable sealing at high temperature and pressure. The DLT also comes with extra long top and bottom subs, which allow for hydraulic tong make-up and break out.. 1.) 2.). SPECIFICATION GUIDE CASING O.D. (IN.) 7 7 7 7 7-5/8 7-5/8. WEIGHT (LBS./FT.) 17.0 -23.0 26.0 - 32.0 32.0 - 38.0 38.0 - 46.4 24.0 - 29.7 33.7 - 39.0. RECOMMENDED CASING RANGE MIN. MAX. (IN.) (IN.) 6.366 6.538 6.094 6.276 5.920 6.094 5.626 5.920 6.875 7.025 6.625 6.765. MAX. O.D. OF TOOL 6.188 5.954 5.781 5.525 6.670 6.453. MIN. I.D. OF TOOL 3.750 3.750 3.750 3.750 3.750 3.750. THREAD CONNECTION BOX UP PIN DOWN 3-1/2" IF 3-1/2" IF 3-1/2" IF 3-1/2" IF 3-1/2" IF 3-1/2" IF. 3.) 4.) 5.) 6.) 7.) 8.) 9.) 10.). PRODUCT NUMBER. 11.). 688-73A-000 688-73B-001 688-73C-001 688-73D-001 688-75A-000 688-75B-000. 12.) 13.) 14.) 15.) 16.). Place top sub (1) in vise. Remove J-body set screws (33) and remove J-body (34) from control body (29). (LEFT HAND THREAD) 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). 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). Remove control body (29) from mandrel (20). Remove slips (26) from control body (29). Remove slip spring screws (27) and slip springs (28) from slips (26). Remove cone (25) from rubber retainer (24). Remove cone (25) from lower end of mandrel (20). Remove set screws (18) from hold down body (8). Remove mandrel (20) from hold down body (8). Remove packing elements (21 & 23), rubber spacers (22), and rubber retainer (24) from rubber mandrel (20). 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) from hold down body (8). 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). Remove set screws (7) from top sub (1). 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). Remove o-ring (5) and back-ups (6) from top sub (1). Clean and inspect all parts. Replace all worn or damaged parts. Re-assemble in reverse order of disassembly.. 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 should remain open while running in. Pick up the tubing and rotate it ¼ turn to the right at the packer. Slack off weight on the packer to set the slips and compress the packing elements (see setting forces guide). Release the torque after slacking off 6” to allow the unloader to close and lock. The set down weight 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 time for the tubing and casing pressures to equalize. Continued upward movement of the tubing relaxes the packing elements, un-sets the slips, and automatically re-jays the packer. The tool may now be moved and reset or pulled from the well.. SETTING FORCES GUIDE SIZE (IN.) 7" & 7-5/8". MINIMUM WEIGHT REQUIRED AT THE PACKER (LBS.) 14,000. 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.. PACKING ELEMENT GUIDE CLASSIFICATION LOW TEMPERATURE STANDARD TOOL MODERATE TEMP. HIGH TEMPERATURE. TEMP. RANGE 60 -125 125 - 225 225 - 275 275 - UP. ELEMENT DURO END MIDDLE END 80 60 80 90 70 90 90 80 90 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. REV. 00/DTD: 11-11-99.

(48) INDEX NO.: 400 UNIT NO.: 688-73A PN: 688-73A-000 688-73B THRU 73D-001 688-75A & 75B PAGE: 2 OF 4. PARTS LIST. PARTS LIST ITEM NO. 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20. DESCRIPTION TOP SUB** O-RING* BACK-UP RING* VOLUME TUBE O-RING* BACK-UP RING* TORQUE SCREW* 5/8-11 X 3/4" HOLD DOWN BODY** UPPER CAP HOLD DOWN STRAP CARBIDE BUTTON* BUTTON SPRING* O-RING* BACK-UP RING* FLAT HEAD SCREW* O-RING* BACK-UP RING* TORQUE SCREW* 5/8-11 X 3/4" LOWER CAP MANDREL**. 7" 17.0 - 23.0 688-73A-000 688-73D-610 050-90-236 045-00-236 (2) 688-73D-220 050-90-348 045-00-348 (2) 021-C10-010 (3) 688-73D-310 688-73A-865 681-70-360 (3) 688-73A-980 (6) 613-55-975 (12) 050-90-141 (6) 045-00-141 (12) 005-C5-006 (3) 050-90-240 045-00-240 (2) 021-C10-010 (3) 688-73A-820 688-73D-210. 7" 26.0 - 32.0 688-73B-001 688-73D-610 050-90-236 045-00-236 (2) 688-73D-220 050-90-348 045-00-348 (2) 021-C10-010 (3) 688-73D-310 688-73C-865 681-70-360 (3) 688-73B-980 (6) 613-55-975 (12) 050-90-141 (6) 045-00-141 (12) 005-C5-006 (3) 050-90-240 045-00-240 (2) 021-C10-010 (3) 688-73B-820 688-73D-210. 7" 32.0 - 38.0 688-73C-001 688-73D-610 050-90-236 045-00-236 (2) 688-73D-220 050-90-348 045-00-348 (2) 021-C10-010 (3) 688-73D-310 688-73C-865 681-70-360 (3) 688-73B-980 (6) 613-55-975 (12) 050-90-141 (6) 045-00-141 (12) 005-C5-006 (3) 050-90-240 045-00-240 (2) 021-C10-010 (3) 688-73C-820 688-73D-210. DESCRIPTION. 7" 17.0 - 23.0 688-73A-000 602-72-514 (2) 611-72-840 (2) 602-72-513 688-73A-850 680-73D-410 688-73A-115 (4) 004-03-006 (4) 688-73D-956 (8) 688-73C-335 090-90-90P (6) 091-01-900 (36) 680-73A-910 021-C8-008 (4) 688-73D-351 021-C10-010 (3) 050-90-338 045-00-338 (2) 688-73D-620. 7" 26.0 - 32.0 688-73B-001 602-70-514 (2) 611-70-840 (2) 602-70-513 688-73B-850 680-73D-410 688-73B-115 (4) 004-03-006 (4) 688-73D-956 (8) 688-73C-335 090-90-90P (6) 091-01-900 (36) 680-73A-910 021-C8-008 (4) 688-73D-351 021-C10-010 (3) 050-90-338 045-00-338 (2) 688-73D-620. 7" 32.0 - 38.0 688-73C-001 602-67-514 (2) 688-73C-840 (2) 602-67-513 688-73C-850 680-73D-410 688-73B-115 (4) 004-03-006 (4) 688-73D-956 (8) 688-73C-335 090-90-90P (6) 091-01-900 (36) 680-73A-910 021-C8-008 (4) 688-73D-351 021-C10-010 (3) 050-90-338 045-00-338 (2) 688-73D-620. 21 PACKING ELEMENT* 22 RUBBER SPACER 23 PACKING ELEMENT* 24 RUBBER RETAINER 25 CONE 26 CARBIDE SLIP* 27 SLIP SCREW*10-24 X 3/8"NP 28 SLIP SPRING* 29 CONTROL BODY** 30 DRAG BLOCK* 31 DRAG BLOCK SPRING* 32 DRAG BLOCK RETAINER 33 TORQUE SCREW* 5/8-11 X 1/2" 34 J-BODY** 35 TORQUE SCREW* 5/8-11 X 3/4" 36 O-RING* 37 BACK-UP RING* 38 BOTTOM SUB** *Common repair parts. **These parts are mated parts and cannot be replaced separately without field adaptation.. DIMENSIONAL DATA. DIMENSIONAL DATA CASING SIZE (IN.) 7 7 7 7 7-5/8 7-5/8. ITEM NO.. DIMENSIONS (IN.). PRODUCT NUMBER. A. B. C. D. 688-73A-000 688-73B-001 688-73C-001 688-73D-001 688-75A-000 688-75B-000. 103.438 103.438 103.438 103.438 103.438 103.438. 18.000 18.000 18.000 18.000 18.000 18.000. 4.875 4.875 4.875 4.875 4.875 4.875. 1.000 1.000 1.000 1.000 1.000 1.000. DIMENSIONS (IN.). E. SIZE (IN.). PRODUCT NUMBER. F. G. H. J. K. 12.750 12.750 12.750 12.750 12.750 12.750. 7 7 7 7 7-5/8 7-5/8. 688-73A-000 688-73B-001 688-73C-001 688-73D-001 688-75A-000 688-75B-000. 4.750 4.750 4.750 4.750 4.750 4.750. 2.688 2.688 2.688 2.688 2.688 2.688. 5.375 5.375 5.375 5.375 5.375 5.375. 6.188 5.954 5.781 5.525 6.670 6.453. 5.469 5.469 5.469 5.469 5.469 5.469. © 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: 11-11-99.

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