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OVERVIEW: Recommended pulling and installation techniques for the different types of side pocket devices installed in the side pocket mandrels SPECIFIC REQUIREMENTS Pressurebalancing, Preoperational checks HSE REQUIREMENTS PermittoWork, portable single well control unit PROCEDURE ACTION ITEMS Assembly of Gas lift Valve Running ToolsPalling Tool, Preparing the Kick over Tools, and Pulling and Installing Side Pocket Devices ATTACHMENT Calculation of Pressure Balance, Recovery Of dropped Gas lift Valve or Dummy during Operation
STANDARD OPERATING PROCEDURE & guideline WIRELINE Rev: 00 MARCH, 2008 DOCUMENT NAME: WLP 19 OPERATIONS OF SIDE POCKET MANDRELS SUMMARY OF SCOPE:OVERVIEW: Recommended pulling and installation techniques for the different types of side pocket devices installed in the side pocket mandrels SPECIFIC REQUIREMENTS Pressure-balancing, Pre-operational checks HSE REQUIREMENTS Permit-to-Work, portable single well control unit PROCEDURE ACTION ITEMS Assembly of Gas lift Valve Running Tools/Palling Tool, Preparing the Kick over Tools, and Pulling and Installing Side Pocket Devices ATTACHMENT Calculation of Pressure Balance, Recovery Of dropped Gas lift Valve or Dummy during Operation REVISION REGISTER Revision No Date Details of Revision Edited By 0.1 0.2 0.3 0.4 0.5 1.0 CONTENTS THIS IS A CONTROLLED DOCUMENT Page of 153 STANDARD OPERATING PROCEDURE & guideline WIRELINE Rev: 00 MARCH, 2008 OVERVIEW SPECIFIC REQUIREMENTS HSE REQUIREMENTS PROCEDURE ACTION ITEMS 4.1 ASSEMBLY OF GAS LIFT VALVE RUNNING TOOL 4.1.1 Pinning GLV’s to Camco GA-2 Running Tool 4.1.2 Pinning GLV’s to Camco JK Running Tool 4.2 ASSEMBLY OF GAS LIFT VALVE PULLING TOOL 4.2.1 Pinning Camco JDC Pulling Tool 4.3 CAMCO "OK" SERIES KICK OVER TOOL 4.3.1 Preparing OK-6 Kick over Tool 4.3.2 Preparing OK-DS And OD-1 Kick over Tool 4.4 TELEDYNE MERLA KICK OVER TOOL 4.4.1 Preparing the Merla Kick over Tool 4.5 RETRIEVAL OF SIDE POCKET DEVICES 4.5.1 Pressure Balancing 4.5.2 Installing Gas lift Valve Catcher 4.5.3 Pulling Side Pocket Devices 4.6 INSTALLATION OF SIDE POCKET DEVICES 4.6.1 Preparation 4.6.2 Installing SPDs Using Camco GA-2 Running Tool 4.6.3 Installing SPDs Using Camco JK Running Tool ATTACHMENT 5.1 5.2 Calculation of Pressure Balance Recovery Of Dropped Gas lift Valve or Dummy during Operation OVERVIEW Side pocket mandrels are installed in all the wells during completions Devices are installed in them to provide communication between the tubing / casing annulus for the purposes of gas lifting, chemical injection or circulation of fluids, or to isolate the annulus from the tubing if the mandrel is not in use In most cases, the side pocket mandrels are THIS IS A CONTROLLED DOCUMENT Page of 153 STANDARD OPERATING PROCEDURE & guideline WIRELINE Rev: 00 MARCH, 2008 used for gas lifting purposes, hence much wireline work is carried out in the retrieval and installation of gas lift valves and dummies This procedure is intended to cover all aspects of the recommended pulling and installation techniques for the different types of side pocket devices installed in the side pocket mandrels SPECIFIC REQUIREMENTS 2.1 Prior to carrying out any side pocket mandrel operations, the following mandatory precautions shall be observed strictly 2.1.1 Installation of a gas lift valve catcher below the deepest mandrel where the gas lift valve change operation is to be performed 2.1.2 Ensuring that there is no over-balance of pressure on the annulus side Refer to Attachment for the pressure-balancing calculation 2.2 In the event the required pressure balancing source is not available, e.g., production station being shut down, it may be necessary to open the Sliding Side Door (SSD) above the top packer in the long string to allow the fluid in the annulus to "U tube" into the tubing for a few hours, and then closing back the SSD and bleeding off any pressure in the annulus This will reduce the hydrostatic column in the annulus, and less pressure will be required to counter balance that hydrostatic pressure 2.3 If gas lift valve change operation is to be carried out in the short string, Step 2.2 shall be first carried out in the long string, since there is no SSD in the short string above the top packer HSE REQUIREMENTS 3.1 The safe execution of the entire operation is governed by the Permit-To-Work system 3.2 The custodianship of a particular Xmas tree shall be transferred to the Well Services Supervisor or Wireline Senior Foreman upon successful application of the PTW and the associated remote control for the Surface Safety valve (SSV) and SCSSV shall be lined up to the Well Services portable control unit As such, there is no direct access by unauthorized personnel to the tree without the consensus of the Well Services Supervisor or Wireline Senior Foreman Important: No lock-out cap shall be used for the SSV when it is operated by the Well Services portable control unit PROCEDURE ACTION ITEMS 4.1 ASSEMBLY OF THE GAS LIFT VALVE (GLV) RUNNING TOOL 4.1.1 Pinning Gas lift Valve (GLV) to 1.1/4" Camco GA2 Running Tool The 1.1/4" Camco "GA2" running tool is used in conjunction with the kick over tool to run and set 1" gas lift valves with integral bottom latches It consists of an adjustable plunger and stabilizer pinned to the body Downward tapping/jarring impact is transmitted on the plunger to the running head of the gas lift valve When the gas lift valve is set in the side pocket, the opposing action of the plunger and body will shear both the telltale pins (which hold the stabilizer to the body) and the releasing pins (which hold the gas lift valve in the running position) simultaneously 4.1.1.1 Preparation of GA2 Running Tool 4.1.1.1.1 Ensure the 15/16" pin threads are in good condition 4.1.1.1.2 Remove the 1/8" retaining roll pins from the body and inspect If pins are not in good condition, replace with new ones 4.1.1.1.3 Remove adjustable plunger together with the stabilizer from the bottom end of the body and inspect for any damage to the plunger Replace damaged parts as necessary THIS IS A CONTROLLED DOCUMENT Page of 153 STANDARD OPERATING PROCEDURE & guideline WIRELINE Rev: 00 MARCH, 2008 4.1.1.1.4 Knock out the remains of all shear pins from the body 4.1.1.1.5 Screw the stabilizer until it bottoms out against the end of threads on the adjustable plunger Insert this assembly back through the bottom into the body until it shoulders up at- the top inside the body 4.1.1.1.6 Insert the 1/8" retaining roll pins into the body 4.1.1.1.7 Push the adjustable plunger downwards until the stabilizer stops on the 1/8" retaining roll pins 4.1.1.1.8 Rotate the adjustable plunger with a flat screwdriver from the top end and align the pin grooves in the stabilizer with the upper set of telltale shear pin holes in the body Insert 1/8" brass pins to pin the stabilizer to the body 4.1.1.1.9 Flare the ends of all pins to ensure they will not drop out when in the hole, especially when the tool is travelling down or up the hole at moderate speeds The running tool is now ready for use 4.1.1.2 Assembly of Gas lift Valve to GA2 Running Tool 4.1.1.2.1 Insert the running head of the gas lift valve into the bottom of the running tool body Align the releasing pin grooves on the gas lift valve running head with the releasing shear pin holes in the bottom part of the running tool body 4.1.1.2.2 Insert 1/8" aluminium pins into these shear pin holes to pin the gas lift valve to the running tool Flare the ends of the shear pins to prevent them from dropping out 4.1.1.2.3 Screw down the adjustable plunger from the top end of the body using a flat screwdriver until it bottoms out against the top of the gas lift valve running head Tighten the adjustable plunger snugly so that the running tool and gas lift valve form a rigid assembly Note: Do not over tighten, as this can shear the two aluminium releasing pins 4.1.1.2.4 4.1.2 Lightly grease the packings of the gas lift valve with an all purpose grease The valve and running tool are now ready for assembly to the kick over tool Pinning Gas lift Valve (GLV) to 1.5/16" Camco JK Running Tool The 1.5/16" Camco "JK" running tool is used in conjunction with the kick over tool to run and set 1" gas lift valves with "BK2" top latches It consists of a single piece body with shear pin holes for the insertion of releasing pins which hold the BK2 latch assembly in the running position Downward tapping/jarring impact is transmitted to the running head of the BK2 latch/gas lift valve assembly When the gas lift valve is set in the side pocket, upward jarring will shear the releasing pins and free the JK running tool 4.1.2.1 Preparation of JK Running Tool 4.1.2.1.1 Ensure the 15/16" pin threads are in good condition 4.1.2.1.2 Knock out the remains of all shear pins from the body 4.1.2.2 Assembly Of Gas lift Valve to JK Running Tool THIS IS A CONTROLLED DOCUMENT Page of 153 STANDARD OPERATING PROCEDURE & guideline WIRELINE Rev: 00 MARCH, 2008 4.1.2.2.1 Insert the running head of the BK2 latch/gas lift valve into the bottom of the JK running tool body until the running head of the BK2 latch is seated against the internal taper in the JK running tool body Note: Ensure the bottom shoulder of the running tool body is not contacting the tapered shoulder above the latch body If there is contact, damage will result to the BK2 latch, and the particular JK running tool should not be used 4.2 4.1.2.2.2 Insert 1/8" brass pins into these shear pin holes to pin the BK2 latch of the gas lift valve to the running tool Flare the ends of the shear pins to prevent them from falling out 4.1.2.2.3 Lightly grease the packings of the gas lift valve with an all purpose grease The running tool attached with the valve is now ready for assembly to the kick over tool ASSEMBLY OF THE GAS LIFT VALVE (GLV) PULLING TOOL 4.2.1 Pinning 1.1/4" Camco JDC Pulling Tool 1.1/4" Camco JDC pulling tool is the pulling tool used in retrieving 1" O.D gas lift valves It is used in conjunction with a kick over tool to pull 1" O.D gas lift valves from side pocket mandrels It is a jar down to shear and release pulling tool 4.2.1.1 Preparation 4.2.1.1.1 Check that the 15/16" pin threads on the fishing neck are in good condition 4.2.1.1.2 Ensure the dog spring is in good condition and the brazed ends are intact 4.2.1.1.3 Check the dogs’ shoulders are not worn Replace if worn 4.2.1.1.4 Ensure the core extension is in place if pulling gas lift valves or dummies with integral bottom latches Note: A standard JDC pulling tool will not be able to shear and release once latched onto a valve or dummy with an integral bottom latch due to its long reach 4.2.1.2 Shear Pin Replacement 4.2.1.2.1 Back off the fishing neck from the tool assembly at the connection between the fishing neck and body and remove the fishing neck 4.2.1.2.2 Remove the shear pin retainer and let the remains of the shear pin drop out 4.2.1.2.3 Push the core downwards against the skirt until the shear pin hole in the core is aligned with that in the body Note: The core may be pushed down easily by placing in a vice and pushing against the skirt with hand If a spacer is used in conjunction with the fishing neck to compress the spring to push the core down, ensure the spacer is removed from inside the fishing neck after installation of the shear pin in the pulling tool THIS IS A CONTROLLED DOCUMENT Page of 153 STANDARD OPERATING PROCEDURE & guideline WIRELINE Rev: 00 MARCH, 2008 4.2.1.2.4 Insert a 3/16" pin punch through the holes in the body and core, driving out the remaining part of the shear pin from the core at the same time 4.2.1.2.5 Drive a 3/16" steel pin through the other side of the hole until it protrudes out at the other side Knock back the end of the shear pin flush with the edge of the hole and cut the shear pin to length 4.2.1.2.6 Install back the shear pin retainer and screw back the fishing neck Tighten all connections, taking care not the grip the pipe wrench jaws on the dogs The pulling tool is now ready for use Caution: If using the pulling tool to pull 1" GLV’s or dummies with the BK-2 top latches, ensure that the core extension is removed, otherwise the pulling tool will not be able to latch If pulling 1" GLV’s or dummies with integral bottom latches, ensure that the core extension is installed on to the ain core, otherwise the pulling tool will not be safely released from the GLV’s or dummies 4.3 CAMCO "OK" SERIES KICK OVER TOOL The Camco "OK" series of kick over tools are used extensively in side pocket mandrel work for the setting and retrieval of gas lift valves, chemical injection valves, dump kill valves and dummies It is a selective tool which can locate into any one side pocket mandrel in a tubing string by a built-in device in the mandrel itself called the "Orienting Sleeve" In simple terms, the OK series kick over tool consists of a locating finger which locates and orients the alignment of the kick over tool arm with the valve pocket when the finger is pulled against the orienting sleeve It in turn activates the arm to kick out at the slot in the "tool discriminator" to guide the pulling tool or gas lift valve dummy towards the valve pocket The first kick over tool in use in PCSB is the Camco "OKDS" kick over tool Over the years, various upgrades of the OK series kick over tools were introduced, namely the "OK 1" and "OK 5" kick over tools, culminating in the present "OK 6" kick over tool The OK-6 kick over tool comes with an integral valve catcher on the bottom of the tool housing This feature was foreseen as more problematic than advantageous, hence all integral valve catchers were cut off Moreover, it is a prerequisite to install a valve catcher below the side pocket mandrels before carrying out any side pocket mandrel work in the hole The following guide covers the disassembly/assembly and pinning process of all the Camco kick over tools in use in PCSB Although there are not many OKDS and OK1 kick over tools in use, the guide is still covered here separately 4.3.1 Preparing Camco OK-6 Kick over Tools 4.3.1.1 Disassembly of OK-6 Kick over Tool 4.3.1.1.1 Remove the socket headset screws from the top of the finger cage 4.3.1.1.2 Place the kick over tool finger cage in a backup wrench 4.3.1.1.3 Back off the fishing neck from the finger cage 4.3.1.1.4 Back off the set screw in the arm adaptor 4.3.1.1.5 Depress the locating finger into the finger housing and pull out the finger housing together with the release plunger and release plunger spring Note: If the pin is sheared, invert the kick over tool to let the release plunger and release plunger spring drop out THIS IS A CONTROLLED DOCUMENT Page of 153 STANDARD OPERATING PROCEDURE & guideline WIRELINE Rev: 00 MARCH, 2008 4.3.1.1.6 Check for slack in the arm joints If the joints are slack, the kick over tool should be returned to the workshop for replacement of the detents and springs 4.3.1.1.7 Check to ensure that the arm pins are not loose If necessary use a 5/16" pin punch to further flare out the countersunk end of the pin 4.3.1.1.8 Check that the finger springs are sufficiently strong to push the finger out at all times 4.3.1.2 Pinning the Kick over Tool 4.3.1.2.1 Remove the shear pins from the finger housing which pin the release plunger and the locating finger 4.3.1.2.2 Pin the locating finger to the finger housing with a cut to length 1/4" brass shear pin 4.3.1.2.3 Insert release plunger into the bottom end of the finger housing such that the slot at the bottom end of the release plunger is directly opposite the locating finger 4.3.1.2.4 Align the shear pin holes in the release plunger and the finger housing Insert a 3/16" brass pin into this hole and cut/file flush with the O.D of the finger housing 4.3.1.3 Assembling the Kick over Tool 4.3.1.3.1 Slip the release coil spring over the release plunger Insert the finger housing/release plunger/release spring assembly into the finger cage with the locating finger lined up with the window for the locating finger in the finger cage 4.3.1.3.2 Push the assembly all the way in until the locating finger pops out of the window in the finger cage 4.3.1.3.3 Screw the fishing neck into the finger cage and tighten the connection Insert the set screws to secure the fishing neck 4.3.1.3.4 Press down the arm assembly fully against the housing and screw in the release set screw until resistance is felt Note: Do not tighten the release lock screw Tightening the lock screw may prevent proper operation of the kick over tool down hole 4.3.1.3.5 Hold the kick over tool upright Using a flat file, activate the kick over tool by pressing the file down on the locating finger until the arm assembly kicks out Check the stiffness of the arm assembly in this position by pressing it against the housing If the arm springs are found to be weak, replace the arm springs Ensure the socket head lock screw is tightened 4.3.1.3.6 Press down the arm assembly and back out the release lock screw to deactivate the kick over tool Screw in the release lock screw again as in Step 4.3.1.3.4 4.3.1.3.7 Check that the fin at the bottom end of the housing is aligned with the locating finger If they are not aligned, slack off the lock THIS IS A CONTROLLED DOCUMENT Page of 153 STANDARD OPERATING PROCEDURE & guideline WIRELINE Rev: 00 MARCH, 2008 nut and rotate the housing until they-are-aligned; -then tighten the lock nut The kick over tool is now ready for use 4.3.2 Preparing Camco "OK-DS" And "OK-1" Series of Kick over-Tools Both the "OKDS" and "OKI" kick over tools used to have locking mechanisms to lock the tool in the activated, position However, it was discovered that the release set screw could keep the kick over tool in the activated position, and that these locking mechanisms were found unnecessary, hence were all removed The guide for disassembling, pinning and assembling is similar to that for the OK-6 kick over tool 4.3.2.1 Disassembly of the Kick over Tool 4.3.2.1.1 Place the kick over tool finger cage in a backup wrench 4.3.2.1.2 Back off the fishing neck from the finger cage 4.3.2.1.3 Back off the release set screw in the arm adaptor 4.3.2.1.4 Depress the locating finger into the finger housing and pull out the finger housing together with the release plunger and release plunger spring Note: If the pin is sheared, invert the kick over tool to let the release plunger and release plunger spring drop out 4.3.2.1.5 Check the arm pins are not loose If necessary use a 5/16" pin punch to further flare out the countersunk end of the pin 4.3.2.1.6 Check that the finger springs are sufficiently strong to push the finger out at all times 4.3.2.2 Pinning the Kick over Tool 4.3.2.2.1 Knock out the shear pins from the arm, arm adaptor and lower adaptor 4.3.2.2.2 Check the condition of the arm springs and ensure they are sufficiently strong Replace if necessary and ensure the socket head lock screw is tightened 4.3.2.2.3 Insert new 3/16" brass pins to pin the arm, arm adaptor and lower adaptor Cut and file all pins flush with the O.D of the arm assembly 4.3.2.2.4 Replace the pin in the finger housing/locating finger with a new 1/4" brass pin 4.3.2.2.5 Replace the pin in the finger housing/release plunger with a new 3/16" brass pin 4.3.2.3 Assembling the Kick over Tool 4.3.2.3.1 Slip the release coil spring over the release plunger Insert the finger housing/release plunger/release spring assembly into the finger cage with the locating finger lined up with the window for the locating finger in the finger cage 4.3.2.3.2 Push the assembly all the way in until the locating finger pops out of the window in the finger cage 4.3.2.3.3 Screw the fishing neck into the finger cage and tighten the connection THIS IS A CONTROLLED DOCUMENT Page of 153 STANDARD OPERATING PROCEDURE & guideline WIRELINE Rev: 00 MARCH, 2008 4.3.2.3.4 Make up the release set screw into the arm adaptor until resistance is felt Press down the arm assembly fully against the housing and screw in the release set screw until resistance is felt Note: Do not tighten the release lock screw Tightening the lock screw may prevent proper operation of the kick over tool down hole 4.2 4.3.2.3.5 Hold the kick over tool upright Using a flat file, activate the kick over tool by pressing the file down on the locating finger until the arm assembly kicks out Check the stiffness of the' arm assembly in this position by pressing it against the housing If the arm springs are found to be weak, replace the arm springs Ensure the socket head lock screw is tightened 4.3.2.3.6 Press down the arm assembly and back out the release lock screw to deactivate the kick over tool Screw in the release lock screw again as in Step 4.3.2.3.4 4.3.2.3.7 Check that the fin at the bottom end of the housing is aligned with the locating finger If they are not aligned, slack off the lock nut and rotate the housing until they are aligned, then tighten the lock nut The kick over tool is now ready for use TELEDYNE MERLA HICK OVER TOOL The Teledyne Merla Positioning (kick over) tool's working principle is 'similar to the Camco "OK" series of kick over tools However, it is a much simpler tool with only one shear pin to change out, and it is a much shorter tool in comparison After completing operations in the side pocket mandrel, the tool will be recocked once it is pulled into the tubing, hence reducing wear and tear on the arm assembly This kickover tool has gone through many improvements over the years,', and Teledyne Merla further came up with the "HD" (Heavy Duty) version of the kick over tool which incorporates stronger springs to ensure that the pivot arm will remain in the furthest position once activated This improvement further enhances working with this tool in a deviated well Total disassembly of the kick over tool on site is not recommended, but the following guide applies for disassembly for the purposes of pinning and inspection 4.4.1 Preparing Merla Kick over Tool 4.4.1.1 Disassembly of the Kick over Tool 4.4.1.1.1 Place the body in a backup wrench or vice, gripping on the flats 4.4.1.1.2 Using another wrench, grip on the hoisting plug Back off the hoisting plug slowly until the pin in the trigger housing is aligned with the hole in the body 4.4.1.1.3 Punch out the pin in the trigger housing and remove the key and trigger assembly from the housing through the window in the body 4.4.1.1.4 Remove the trigger spring from the trigger housing through the window in the body 4.4.1.1.5 Slide the trigger housing out from the tool body THIS IS A CONTROLLED DOCUMENT Page of 153 STANDARD OPERATING PROCEDURE & guideline WIRELINE Rev: 00 MARCH, 2008 4.4.1.1.6 Punch out the key pin and inspect for any damage/defect Replace as necessary and re-pin the key to the trigger 4.4.1.1.7 Punch out the brass shear pin and replace with a new 3/16" brass pin to pin the key to the trigger in the cocked position 4.4.1.1.8 Punch out the pivot arm pin and inspect its condition If there is the slightest sign of shearing, replace the pin with a new one 4.4.1.2 Pinning and Assembly of the Kick over Tool 4.5 4.4.1.2.1 Re-pin the pivot arm to the bottom of the tool body Ensure the ends of the pivot arm pin are flush with the flats on the tool body Check for any loose play in the joint The pivot arm should be able to hinge freely 4.4.1.2.2 Smear some "Lubriplate" grease on the sides of the trigger housing Slide the trigger housing into the body 4.4.1.2.3 Screw the hoisting plug into the body until the retaining pin hole in the trigger housing is aligned with the hole in the body 4.4.1.2.4 Place the trigger spring through the window in the body into its profile in the trigger housing 4.4.1.2.5 Insert the trigger/key assembly through the window in the body and align the hinge pin holes in the trigger housing and the trigger 4.4.1.2.6 Insert the hinge pin through the hole in the body to pin the trigger to the housing 4.4.1.2.7 Screw the hoisting plug all the way in until it shoulders up with the top of the tool body Tighten the connection 4.4.1.2.8 Check for proper function of the trigger by depressing it until flush with the O.D of the tool body, and then allow it to spring out again to ensure it can move in and out of the window freely Tool is now ready for use RETRIEVAL OF SIDE POCKET DEVICES 4.5.1 Pressure Balancing 4.5.1.1 Pressures Balancing In A Gas Lifted Well Where a well has been producing, or currently on gas lift, the annulus contents would have been evacuated down to the deepest valve set in the tubing string Therefore, pressures exerted by the hydrostatic column in the casing / tubing annulus will no longer present-an-overbalance situation unless the CHP (Casing Head Pressure) is higher than the CITHP (Closed In Tubing Head Pressure) For wells which are currently on gas lift, pressures in the annulus and tubing will balance out after a short period of closed-in time It would be observed that the CITHP will be equal to the CHP after all the necessary drift nets, retrieval of the SCSSV and installation of the gas lift valve catcher In the event that the CHP is higher than the C=, carry out as follows: 4.5.1.1.1 THIS IS A CONTROLLED DOCUMENT Close in the gas lift supply if the other string in a dual string well is producing on gas lift Page 10 of 153 STANDARD OPERATING PROCEDURE & guideline WIRELINE Rev: 00 MARCH, 2008 4.5.1.1.2 Record the CITHP and CHP If the CHP is higher than the C=, proceed to Step 4.5.1.1.3 4.5.1.1.3 Bleed down the CHP via the blow down facility until it is lower than the CITHP of the string to be worked on Note: The bleed down should be made at a reasonably fast rate to effect closure of the velocity check valves in the fluid operated type gas lift valves and orifice valves (viz BKR3 and BKR5 gas lift valves, BK and DKO-2 orifice valves) 4.5.1.1.4 If the bleed down rate is slow, stop bleeding after 1/2 hour and observe the CHP 4.5.1.1.5 If the CHP builds up, hook up an equalizing loop from the annulus side outlet valve to the wireline lubricator bleed off valve Equalize the CHP into the tubing until the CITHP is the same as the CHP 4.5.1.1.6 The gas lift valve change operation may now proceed after installation of the gas lift valve catcher 4.5.1.2 Pressures Balancing In a Non-Gas Lifted Well In a well which has never been gas lifted before (this applies to both strings in a dual completion), the casing/tubing annulus will either be full of completion fluid (brine) or diesel This column of fluid in the annulus will exert hydrostatic pressure, increasing with depth In most cases, there will be an overbalance of pressure (higher pressure) in the annulus even though the surface pressure (CHP) is zero Therefore, extra precaution is required prior to carrying out any side pocket mandrel work due to the fact that a gas lift valve or dummy valve (in most cases) once unseated from the pocket will allow the casing content (fluid) to "U tube" into the tubing and blow up the wireline tools, resulting in unacceptable consequences To this end, the following guide shall be observed and carried out: 4.5.2 4.5.1.2.1 Record the string's CITHP and bleed off CHP if any 4.5.1.2.2 Record the fluid level in the tubing when making the drift run prior to installing the gas lift valve catcher 4.5.12.3 Inject pressure into the tubing until the CITHP is sufficient to counter balance the hydrostatic pressure in the annulus 4.5.1.2.4 Inmost cases, the lift gas pressure is sufficient to overbalance the hydrostatic pressure in the annulus For simplicity of calculations and safe operations, it is best to assume the annulus content to be brine with a fluid gradient of 0.465 psi/fl, and oil in the tubing with a fluid gradient of 0.350 psi/ft, unless otherwise stated inthe objective programme Refer to Attachment in 5.1 Calculation of Pressure Balance required to be injected into the tubing 4.5.1.2.5 Once the required injected pressure is reached, the injection may be stopped and the gas lift valve change operation proceeds after installation of the gas lift valve catcher Installing the Gas lift Valve Catcher Prior to carrying out any side pocket mandrel work, a gas lift valve catcher shall be installed below the deepest mandrel where the gas lift valve change operation is to be performed To this end, the gas lift valve catcher will be installed in the top X-profile in the tubing string; either in an Otis X-landing nipple or in an SSD (Sliding Side Door) THIS IS A CONTROLLED DOCUMENT Page 11 of 153 STANDARD OPERATING PROCEDURE & guideline WIRELINE Rev: 00 MARCH, 2008 4.5.3 Pulling Side Pocket Devices 4.5.3.1 After carrying out the pressure balancing exercise, prepare the 1.1/4" JDC pulling tool and kick over tool as per Sections 4.2/4.3/4.4 of this procedure 4.5.3.2 Make up the JDC pulling tool to the kick over tool and tighten connection 4.5.3.3 Set the wireline tool string "zero" reference depth Note: The bottom of the kick over tool is not to be used as the zero reference point because the top of the kick over tool when oriented and located is at the top end of the side pocket mandrel, and all along hole reference depths are based on top of the down hole accessories 4.5.3.4 Make up the kick over tool assembly to the wireline tool string and pull into lubricator, taking care that the locating finger does not hang up against the quick union bottom pin end shoulder on the way up, otherwise this will cause the kick over tool to trip (activate) Caution: Do not press the locating finger inwards by hand this may cause one's hand to be pulled with the kick over tool, into the lubricator bottom and result in injury to the hand Align the kick over tool by holding to the tool housing which is far away from the bottom of the lubricator 4.5.3.5 Make up and pressurize the lubricator assembly 4.5.3.6 Run in hole the kick over tool at moderate speed until about 50 feet above the depth of the side pocket mandrel where the valve is to be pulled Check pulling weight of the tool string Note: When running in hole, slow down when passing any other side pocket mandrels above the depth of the mandrel where the valve is to be pulled 4.5.3.7 Continue o owes e tool string at a slow speed until it is about 10 feet below the desired side pocket mandrel, noting any indication of the kick over tool passing the mandrel 4.5.3.8 Switch to first gear on the wireline winch and pick up the tool string slowly, noting the pulling weight Continue to pull up until an over pull is observed Stop and note the depth where the over pull is encountered, and correlate this depth with the depth of the side pocket mandrel in the well status diagram These two depths should be within a difference of a few feet 4.5.3.9 Once the depth is observed to be correct, continue to pull up on the tool string with an over pull of at least 200 lbs above the pulling weight observed in Step 4.5.3.8 4.5.3.10 Using the hydraulics of the wireline winch, lower the kick over tool very slowly until weight loss is observed, i.e the kick over tool has tripped and the pulling tool is now sitting on the top of the gas lift valve, and the mechanical link jar is closed Note: Do not use the brake on the winch to control the lowering speed of the drum The brake is inefficient for speed control of the drum due to sticking and/or slippage THIS IS A CONTROLLED DOCUMENT Page 12 of 153 STANDARD OPERATING PROCEDURE & guideline WIRELINE Rev: 00 MARCH, 2008 4.5.3.11 Pickup the tool string very slowly again until the link jar is fully open Note this depth and compare with that observed in Step 4.5.3.9; it should be just more than foot deeper 4.5.3.12 Continue to pull up an additional 200 lbs to check for positive engagement of the pulling tool on the valve in the side pocket If no over pull is encountered above the depth noted in Step 4.5.3.9 until the tool is at the depth noted in Step 4.5.3.8, it means the pulling tool has not engaged on the valve yet, and the over pull seen at this juncture is that of the locating finger engaging into the orienting sleeve in the side pocket mandrel Repeat Step 4.5.3.10 through Step 4.5.3.12 until positive engagement is achieved A few light taps may be made in attempt to get the pulling tool to engage onto the valve/dummy Note: If the pulling tool still fails to engage after repeating the above 10 times, the kick over tool should be pulled out of hole for further evaluation/ analysis There is a good possibility of the presence of wax or scale in the side pocket mandrel, or that the valve or dummy to be pulled is not in place 4.5.3.13 Proceed to jar up with the mechanical/hydraulic jars to free the valve/dummy from the side pocket Record the number of jars required to free the valve/dummy, and note any change in the CITHP and CHP once the valve/dummy is free Note: Due to the small size and light weight of the 1" side pocket valve/dummy, it is not possible to see any increase in pulling weight even though the valve/dummy is successfully pulled This can only be confirmed when it is at surface 4.5.3.14 Pull out of hole the wireline tool string into the lubricator and close the Xmas tree swab valve Bleed off all pressure from the lubricator 4.5.3.15 Disconnect the lubricator and lower the kick over tool to confirm physically that the valve/dummy has been retrieved 4.5.3.16 Remove the kick over tool from the wireline tool string and lay it down on the wireline deck Disconnect the JDC pulling tool from' the kick over tool and remove the gas lift valve dummy Check for any visual damage and lost packings on the valve/dummy and report as appropriate Record the valve/dummy identification number Note: If using a Teledyne Merla kick over tool, it is then not necessary to disconnect the kick over tool from the wireline tool string since it can be re-pinned without opening up the tool, unlike the Camco OK series kick over tools Disconnect the JDC pulling tool only from the Merla kick over tool 4.6 INSTALLATION OF SIDE POCKET DEVICES In order to install a valve or dummy in a side pocket mandrel, the pocket of the particular mandrel must be empty, i.e the valve or dummy originally in that pocket has been retrieved There will be no pressure differential between the tubing and the annulus since there is communication through the empty pocket of the mandrel Pressure balancing is therefore not required 4.6.1 Preparation 4.6.1.1 Assemble the gas lift valve or dummy to the appropriate running tool as per Section 4.1-Assembly of the Gas lift Valve Running Tool, whichever is applicable If it is a gas lift valve, make sure the correct one is picked up for assembly to the running tool THIS IS A CONTROLLED DOCUMENT Page 13 of 153 STANDARD OPERATING PROCEDURE & guideline WIRELINE Rev: 00 MARCH, 2008 4.6.1.2 Record the valve number, setting pressure and programmed setting depth in the daily operations report 4.6.1.3 Prepare the kick over tool as per Section 4.3 - Camco Kick over Tool and Section 4.4 - Teledyne Merla Kick over Tool, with respect to type of kick over tool to be used 4.6.1.4 Make up the running tool with the gas lift valve attached to the kick over tool arm and tighten thread connection 4.6.1.5 Set the wireline tool string "zero" reference depth 4.6.1.6 Make up the kick over tool assembly to the wireline tool string and pull into the lubricator, taking care that the locating finger does not hang up against the quick union bottom pin end shoulder on the way up, otherwise this will cause the kick over tool to trip (activate) Caution: Do not press the locating finger inwards by hand this may cause one's hand to be pulled with the kick over tool into the lubricator bottom and result in injury to the hand Align the kick over tool by holding on the tool housing or pivot arm which is far away from the bottom of the lubricator 4.6.1.7 Makeup and pressurize the lubricator 4.6.2 Installing Side Pocket Devices Using Camco GA2 Running Tool The Camco GA2 running tool is a jar down to shear and release running tool Any upward jarring applied to release the running tool will result in improper setting of the 1" valve or dummy 4.6.2.1 Run in hole the kick over tool at moderate speed until about 50 feet above the depth of the side pocket mandrel where the valve/dummy is to be set Check pulling weight of the tool string Note: When running in hole, slow down when passing any other side pocket mandrels above the depth of the mandrel where the valve / dummy is to be set 4.6.2.2 Continue to lower the tool string at a slow speed until it is about 10 feet below the desired side pocket mandrel, noting any indication of the kick over tool passing the mandrel 4.6.2.3 Switch to first gear on the wireline winch and pick up the tool string slowly, noting the pulling weight Continue to pull up until an over pull is observed Note this depth where the over pull is encountered, and correlate this depth with the previous run when pulling the old valve/dummy, and the depth of that side pocket mandrel in the well status diagram 4.6.2.4 Once the depth is observed to be correct, continue to pull up the tool string with an over pull of at least 200 lbs above the pulling weight observed in step 4.6.2.3 4.6.2.5 Using the hydraulics of the wireline winch, lower the kick over tool very slowly until weight loss is observed, i.e the kick over tool has tripped and the valve/dummy is now seated at the entrance of the valve pocket, and the mechanical link jar is closed Note: Do not use the brake on the winch to control the lowering speed of the drum The braking system is inefficient for speed control of the drum due to sticking and/or slippage THIS IS A CONTROLLED DOCUMENT Page 14 of 153 STANDARD OPERATING PROCEDURE & guideline WIRELINE Rev: 00 MARCH, 2008 4.6.2.6 Pick up the tool string very slowly until the link jar just starts to open Note this depth on the counter 4.6.2.7 Pull up another foot to open the link jar (approximately 70% of its full stroke) Lower the tool string to close the jar at a moderate speed Repeat this for at least 30 times to drive the valve/ dummy into the pocket and to lock it in place It may be necessary to switch to 2nd or 3rd gear on the wireline winch, depending on the response of the winch drum in relation to the deviation of the well Caution: Do not attempt to open the link jar fully as it will shear the valve releasing pins in the running tool prematurely and the valve/dummy not properly set and locked in place Moreover, the body bottom of the running tool may not slip over the running head of the valve/dummy Further jarring down will damage the running head and the body bottom portion of the running tool 4.6.2.8 Jar down a few times with the link jar opening at 70% (i.e foot with reference to counter depth) to ensure that the valve or dummy is set and locked in the valve pocket Note: This action will shear both the releasing and telltale pins in the GA2 running tool 4.6.2.9 Pick up the tool string until the link jar is fully open If immediate over pull is seen, lower down the tool string and repeat Step 4.6.2.8 Note: Over pull is an indication that the valve is not locked in place yet 4.6.2.10 If no immediate over pull is seen, it indicates that the valve is set and locked in place, and the running tool has released from the valve/dummy Pick up the tool string further until over pull is observed (the locating finger is engaging the orienting sleeve) This depth should be feet higher than the depth noted in Step 4.6.2.6 4.6.2.11 Continue to over pull to activate the hydraulic or upstroke jars to shear the pin in the kick over tool plunger and collapse the locating finger The kick over tool will come free from the side pocket mandrel 4.6.2.12 Pull out of hole the kick over tool to surface and into the lubricator Close swab valve and depressurize the lubricator 4.6.2.13 Remove the kick over tool (or the GA2 running tool if a Merla kick over tool is used) from the wireline tool string and lay it down Disconnect the GA2 running tool from the kick over tool arm lower adaptor 4.6.2.14 Check that the telltale, pins in the GA2 running tool are sheared (the pin grooves in the stabilizer will be in line with the round window in the body of the running tool) If unsure, check for play of the stabilizer by using a 5/16" pin punch to push in either ends of the adjustable plunger If the pins are sheared, the stabilizer and adjustable plunger will be free to move up and down, confirming the valve/dummy is set and locked in place Alternatively, the pins may be punched out to check if they are indeed sheared 4.6.2.15 Continue with the next part of the wireline programme 4.6.3 Installing Side Pocket Devices Incorporated With BK Latch Using Camco JK Running Tool The Camco JK mining tool is a jar up to shear and release running tool Shearing of the releasing pins is in itself a confirmation that the valve or dummy is set and locked in place THIS IS A CONTROLLED DOCUMENT Page 15 of 153 STANDARD OPERATING PROCEDURE & guideline WIRELINE Rev: 00 MARCH, 2008 4.6.3.1 Carry out as per Steps 4.6.2.1 through 4.6.2.8 4.6.3.2 When satisfied that the valve/dummy is locked in place, pick up the tool string until the link jar is fully open If no immediate over pull is seen, it indicates that the valve / dummy is not yet set / locked in place Lower down the tool string slowly 'to close fink jar and repeat Steps 4.6.2.1 through 4.6.2.8 4.6.3.3 If immediate over pull is seen, it indicates the valve / dummy is set and locked in place 4.6.3.4 Continue to over pull to activate the hydraulic or upstroke jars to shear the releasing pins in the running tool and to free the kick over tool from the side pocket mandrel 4.6.3.5 Pull out of hole the kick over tool to surface and into the lubricator Close swab valve in Xmas tree and bleed off pressure in the lubricator 4.6.3.6 Remove the kick over tool (or the JK running tool if a Merla kick over tool is used) from the wireline tool string and lay it down 4.6.3.7 Continue with the next part of the wireline programme The gas lift valve catcher will be removed at the end of the wireline programme Note: If side pocket devices are found in the catcher, the catcher shall be reinstalled in the well prior to attempting any wireline work with the side pocket mandrels ATTACHMENT 5.1 CALCULATION OF PRESSURE BALANCE Applicable to well which has never been gas lifted before For safe operations, it is recommended to assume the annulus content to be brine with a fluid gradient of 0.465 psi/ft, and oil in the tubing with a fluid gradient of 0.350 psi/ft, unless otherwise stated in the objective programme The following mathematical relationship shall be used for calculation of the pressure required to be injected into the tubing The fluid level in the tubing is tagged at z ft The gas lift or dummy valve to be pulled is at y ft Hydrostatic pressure in tubing at valve depth = [0.350(y - z) + CITHP psi (If the fluid level is below the valve depth, then this value = CITHP) Hydrostatic pressure in annulus at valve depth= (0.465 x y feet) psi Therefore, pressure required to be injected into tubing to balance hydrostatic pressure in annulus = (0.465 x y) - [0.350(y - z) + CITHP] psi (This is assuming CHP is psig.) For simplicity, the above calculations assume all depths to be vertical depths (instead of converting all along hole depths into true vertical depths), gas gradient is also neglected If the fluid level is at surface, then injection of pressure will not be necessary 5.2 RECOVERY OF DROPPED GAS LIFT VALVE OR DUMMY DURING OPERATION THIS IS A CONTROLLED DOCUMENT Page 16 of 153 STANDARD OPERATING PROCEDURE & guideline WIRELINE Rev: 00 MARCH, 2008 When a gas lift valve or dummy is inadvertently dropped while running in or pulling out of hole, this valve or dummy requires to be accounted for before the next gas lift valve operation can proceed This is due to the small OD of the valve/dummy that it can be lying in any of the side pocket and cause wireline problem during subsequent runs The following guides should be followed whenever a gas lift valve/dummy is dropped in hole, or whenever problem is encountered during a gas lift valve change operation 5.2.1 If any hold up is encountered in any side pocket other than the mandrel where the valve / dummy is to be installed when RIH to set a valve / dummy, not attempt to work through the HUD, but pull out of hole immediately and check the kick over tool Make an LIB run to check the SPM for obstruction 5.2.2 A wire scratcher run should be run to clean all side pocket mandrels, starting from the mandrel where the kick over tool was last up prior to dropping/losing the valve/dummy, to below the bottom-most mandrel A 1.1/2" OD tool string should be used at all time to run the scratcher so that the freed or dislodged valve/dummy can bypass the tool string and drop down into the catcher 5.2.4 Thereafter, run a maximum size LIB pass all the SPMs to ensure no hold-up to the top of the valve catcher, prior to retrieving the valve catcher 5.2.5 The dropped/lost valve/dummy should be accounted for before proceeding any further gas lift valve operation THIS IS A CONTROLLED DOCUMENT Page 17 of 153 .. .STANDARD OPERATING PROCEDURE & guideline WIRELINE Rev: 00 MARCH, 2008 OVERVIEW SPECIFIC REQUIREMENTS HSE REQUIREMENTS PROCEDURE ACTION ITEMS 4.1 ASSEMBLY OF... THIS IS A CONTROLLED DOCUMENT Page of 153 STANDARD OPERATING PROCEDURE & guideline WIRELINE Rev: 00 MARCH, 2008 used for gas lifting purposes, hence much wireline work is carried out in the retrieval... Replace damaged parts as necessary THIS IS A CONTROLLED DOCUMENT Page of 153 STANDARD OPERATING PROCEDURE & guideline WIRELINE Rev: 00 MARCH, 2008 4.1.1.1.4 Knock out the remains of all shear pins