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INTERMEDIATE WIRELINE COURSE

1 INTRODUCTION

The intermediate wireline course will cover various operating tools, service tools and their procedures. Dis-assembly and assembly of discussed equipment. The practical application of installing and retrieving downhole flow control devices and wireline unit maintenance. The course will cover most of the standard tools available for deviated and problem wells, wireline reporting and safety talks. 1.1 WIRELINE TOOLSTRINGS Toolstrings come in sizes from 1.25” to 2 ½” OD, the connections can be either threaded or Quick lock design. The tools that consist of a standard toolstring are: Rope sockets Stem Jars Knuckle joint Swivels Toolstring connections BRAIDED CABLE ROPE SOCKETS When braided cable is used for wireline operations the rope socket can be either a slip type where line tension increases the grip of the rope socket to the cable, slip assembly with preset cutters, the cable can be cut when 50% maximum line tension is reached, and pre-loaded clamp assembly. Braided cable slip type

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Braided cable pre- loaded rope socket The pre-loaded type of rope socket has Belleville springs to pre-load the initiator clamp. The braided cable maintains tension on the clamp even if the tension is reduced. The rope socket is also available with a swivel to minimize line twist when running or pulling

Braided or slickline TDR rope socket The time delay releasable rope socket can be used in fishing operations, or to deploy gauges and delicate instrument into completion profiles. To release the rope socket and to leave a clean fishing neck for later recovery, weight is slacken off to a predetermine, this then activates the release system. The release function can be stopped at any time by re-applying tension.

Lower assembly

Slickline upper assy. Braided cable assy. Slick line rope socket

The rope socket is the means of attaching the wire to the toolstring, the most common used rope socket for slick line is the tear drop type.

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Rope socket – wire preparation tool The wire forming tool is used to shape the wire to suit a pear drop rope socket, the tool is useful for larger sizes of slickline like 0.125.

WIRELINE STEM The Wireline stem serves a dual purpose. It provides the necessary weight to overcome the effects of friction, fluid viscosity and pressure. It also provides the kinetic energy which is converted into upward and downward jarring force. Should there be height restrictions for accommodating sufficient lubricator, shorter and heavier stem would be employed. The Stem is available in lengths of 2ft, 3ft and 5ft. The OD 1.25” – 2 ½”, The Material used carbon steel, tungsten, uranium and lead filled stem. Tungsten and uranium are the heaviest but the uranium is expensive and not commonly used.

LEAD FILLED STEM The stem consists of tubular steel outer barrel, and the inside is filled with lead. This stem is used primarily to run flowing pressure surveys to obtain maximum weight and minimum cross sectional area to protect against floating or being blown up the hole by pressure surges.

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Note: Lead filled stem should not be used for jarring, the lead creeps down and will split the outer barrel.

Comparison Weight of stem:

Max OD Length ft Steel Lead Tungsten

1.25 2 8.4 8.8 10.4

1.25 3 12.8 14.3 16.3

1.25 5 20.9 24.3 28.4

1.5 2 11 13.9 15.9

1.5 3 17.6 20.9 23.6

1.5 5 28.7 36.4 41.7

1.875 2 17.6 20.7 28.3

1.875 3 26.5 32.2 38.6

1.875 5 45.2 56.7 65.3

2.125 2 22.9 26.9 31.1

2.125 3 34.8 41.9 49.4

2.125 5 58.6 68.8 86

2.5 2 31.3 37.5 40

2.5 3 48.5 57.3 68.8

2.5 5 81.6 99.2 120

JARS The jars are the force required downhole to manipulate tools and shear pins is generated by the impact of the jars. If the jars are not being operated correctly or if the jar action is lost then very little force can be exerted on the tools. Most types of mechanical jars have a stroke length of 20 inch or 30 inch, for heavy jarring the 20 inch stroke jars are used. Where additional impact from hydraulic or spring jars is used the 30 inch stroke jars can “scissor” when this occurs the jar force is lost. Choice of jars is determined by the well fluids, tubing size, well deviation and the operation to be performed. The types of Jars available: Mechanical (Spang) Tubular Linear Hydraulic Spring Hydraulic/mechanical

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MECHANICAL JAR The Spang or Link jars are the basic standard toolstring. Available with 20 or 30 inch stroke.

TUBULAR JARS Tubular jars are used in fishing operations where debris or wire could have an adverse impact on conventional mechanical jars. The tubular jars outer body has fluid by pass holes to optimize the velocity of the anvil to impact and prevent debris ingress during fishing operations.

HYDRAULIC JARS Hydraulic jars are designed for upward jarring during wireline operations. When jar forces are required a strain is taken on the wire, with the mechanical jars open. The top sub and mandrel are pulled upwards while the piston is impeded in it upward movement by the hydraulic fluid. This delaying action allows sufficient strain to be taken on the line to strike a blow of the required intensity. When the piston passes the restricted cylinder bore to the enlarged section, fluid resistance ceases allowing the mandrel to travel at great speed to strike the middle body insert and transmit the jarring force. The jar is closed by slowly slacking off toolstring weight. With the hydraulic jars impact forces can be adjusted by the amount of over pull that is applied. The use of Hydraulic jars in Gas wells is not recommended as gas can ingress and the jar action is lost. The jars most always be positioned above mechanical jars, if the jars become gassed up they act more as a shock absorber. This would make shearing pins unlikely if placed below the link jars. The hydraulic oil used will alter the time for the jars to impact; heavier oil is used where the tool will operate in high well temperatures. Hydraulic jars

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SPRING JARS Spring jars are a telescoping up stroke jar run with stem installed above them. The jars are set on surface to a predetermined release force. The toolstring is slowly picked up and when the set tension is reached the inner mandrel is unlocked and the upward movement of the mandrel will impact the jar force. To reset the jars toolstring weight is slackened off, this resets the locking device and upward jarring can be repeated. To reset the release force the jars are pulled to surface, a calibrated key is used to adjust the jars release force. With some manufacturers there is a test sub which when hydraulic pressure is applied will check the unlatching force on surface.

HYDRO MECHANICAL JAR The hydro mechanical jar is a combination of the spring and hydraulic jars. Being principally hydraulic, the jar does not require presetting or calibration. It can be activated by exerting any over pull desired by the operator. The release/delay mechanism comprises a short stroke hydraulic unit linked to a mechanical jarring system. This design reduces the possibility of gas infiltration.

TUBULAR LINEAR JAR The linear jar is similar to the tubular jars except has bearing to create a frictionless action, allowing full force of impact from the stem above. The Liner jars are used in deviated wells, the jars can operate in wells with 65 – 75 degrees.

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KNUCKLE JAR The knuckle Jar is used normally on pressure survey operations where standard link jars are not used, should toolstring become held up with wax or debris light jarring can be applied. The normal length of stroke is 2 inches.

ACCELERATORS Accelerators were designed to augment the performance of upstroke power jars. Although commonly run only when jarring near surface, accelerators significantly improve the effectiveness of power jars at any depth. By storing energy in the spring when an over pull is taken, then releasing this energy at the point when the jars release the mass of the stem on the toolstring is “accelerated” up to the point of impact and increases the force generated. The accelerator also acts as a shock absorber, protecting the rope socket when jarring at shallow depths.

UNIVERSAL PULLING TOOLS The Universal pulling tools were designed to enable pulling tools to be converted, either by the direction of shear or by changing the reach, in situations where additional equipment would need to be available; one tool can be converted to cover for three or four pulling tools. Some of the universal tool design will not stand up to heavy jarring. Where the core length is adjusted by a threaded stem, heavy downward jarring on the threaded stem will damage it.

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1.2 PCE UNIVERSAL PULLING TOOL

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1.3 HEAVY DUTY PULLING TOOL The heavy duty pulling tool (HDPT) was specifically designed for use in conjunction with upstroke spring jars to withstand high impact jarring forces. Conventional pulling tools have between two and four latching dogs which when are subjected to impact forces tend to either damage the fishing neck or, in the worst case, shear off. The HDPT uses a full circumference latch mechanism, which spreads any load evenly around the fishing neck. This feature combined with the robust construction and fully encapsulated housing gives a fivefold strength increase over conventional tools and minimises fishing neck wear and damage. The pulling tool shears with downward jarring.

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Heavy duty pulling tool

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1.4 Otis “B” Pulling tool

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1.5 OTIS “SS” Adapter

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OTIS “SSJ” PULLING TOOL

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1.6 OTIS “N” TEST TOOL The “N” and “X” test tools are a non locking device, they are run and seat on the no-go within the nipple. Normally the test tools are used to pressure test tubing and during well completions to set production packers. The “SSJ” is used to run the test tool, the tool can be sheared can be sheared by jarring down on the skirt to shear the pin. As the skirt makes contact with the top of the cage and the reach of the tool no forces act on the dart to damage the seal and seat. When the seals on the test tool enter the seal bore of the nipple fluid will lift the dart allowing fluid bypass. The movement of the dart is not restricted owing to the long reach of the SSJ.

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1.7 PULLING TOOLS USES

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1.8 OTIS TYPE “X” and “R” PLUGS

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“X” PLUG ASSEMBLY

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1.9 OTIS “PX” and “PR” PLUGS

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“P” PLUG ASSEMBLY

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2.0 OTIS “X” SELECTIVE TEST TOOL

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“X” TEST TOOL

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2.1 OTIS PLUG SETTING PROCEDURE

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SETTING PROCEDURE

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2.2 OTIS PLUG PULLING PROCEDURE

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“X” LOCK PULLING PROCEDURE

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2.3 KICKOVER TOOLS A kickover tool is required to run and pull valves and accessories into and from side pocket mandrels (SPM). For the Camco “”KBMG” and “KBUG side pocket the type “OK” kickover tool is required. The kickover tools consist of a fishing neck and a pin thread connection on the upper end, a locating trigger, kick springs and arm assembly with a box thread connection on the lower end, for attachment of a running or pulling tool, and an arm housing with a nose on the lower end. A knuckle joint is installed directly on the kickover tool to facilitate operations. The OK kickover is used to set and pull 1 inch OD valves. Normally before gaslift work commences a valve catcher is set below the SPM that are to be worked on. The valve catcher tube attached to a lock, the tube should accommodate more than one valve. Some catchers can be set on a nipple no-go and are not locked. During retrieval or installation should a valve drop the valve will be arrested in the catcher.

A VALVE CATCHER

Camco “O” series include “OK 1” and “OK 5”, all have the same basic design features but with the OK 1 re-pinning require some disassembly. RUNNING PROCEDURE The kickover tool is run in the hole, with associated valve and latch attached, to a point below the selected SPM. Pick up the tool slowly until it stops. The finger on the kickover tool has engaged, the orientation sleeve aligning the kickover arm with the pocket. An overpull kicks over the tool. The toolstring is lowered until the valve locates the side pocket. The toolstring is jarred down to latch the valve in the side pocket. Upward jarring confirms the valve is latched and releases the running tool when the pins are sheared. Contact with finger against the top of the orientation sleeve, shears a pin collapsing the finger The toolstring can be pulled out of the hole.

Note: Pressure across the valve should be equalized prior to pulling the valve.

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PULLING PROCEDURE A Camco JDC pulling tool is attached to the KOT arm. The KOT is run to below the selected SPM. The tools are picked up slowly until the finger has engaged the top of the orientation sleeve aligning the pulling tool with the pocket, an overpull trips the arm with the pulling tool out. Slowly lower the toolstring until the pulling tool engages the latch of the valve. An overpull confirms engagement, upward jarring shears a pin in the latch allowing recovery of the valve. Impact of the finger to the top of the orientation shears the pin in the finger allowing the KOT to be recovered. The toolstring is pulled out of the hole. THE LATCH SYSTEM

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“OK” KICKOVER TOOL

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SHEARING OF JDC ON LATCH

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BK LATCH

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“JK” RUNNING TOOL