Construction
 
1. Inflatable Packer Element: A Wellbore seal is provided by a steel reinforced inflatable element that also anchors the tool in the hole against differential pressures.
 
2. Poppet Valve: Inflation pressure is held in the element by a spring loaded, hydraulic-actuated
check valve.
 
3. Shear Plug: The Shear Plug facilitates inflating the packer element by sealing off the ID of the tubing. The plug shears out after inflation to open the tubing below the tool. The shear pin in the shear plug controls inflation pressure and must be properly sized. A solid plug or ball seat shear plug can be used.
 
4. Releasing Mechanisms:
 
a. Packer mandrel is held in the set position by the release coupling which has left hand threads. Right hand rotation releases the mandrel to move up into the deflate position. Travel is controlled by the bumper sub.
 
b. A pull release version of the PIP is also avail-able. The tool is released by pulling on the tool, shearing preset shear pins, and stroking the tool to the deflate position.
 
c. Grooves in the mandrel move across seals when the mandrel is in the deflate position al-lowing the packing element to deflate into the tool ID and the annulus
 
PIP Options

The PIP is available with different configurations depending on the application and well conditions. A PIP checklist is available from Inventory Control to facilitate in ordering a PIP.
 
1. Release: The standard PIP is available with Right Hand Rotational Release. A pull release version is also available. The Pull Release version is used where rotation of the tubing for unsetting is not possible or desired. It is not recommended for use where the tubing must be tensioned to operate other downhole equipment.
 
2. Shear Plug: Two types of shear plugs are available, solid and ball-and-seat. The solid plug is used where it is necessary to isolate the tubing completely from the hole and when a ball can not be dropped. The ball-and-seat plug is used where it is necessary to fill the tubing going in the hole, circulate, or spot fluid prior to setting the packer.
 
3. Packer Element: The inflatable packer element is available in either open-hole or casing anchor types. The open hole element has a full rubber sealing surface and comes in either 66 or 136" lengths. The 66" length is standard but where problems of formation communication exist due to permeability or fracturing, the longer length is recommended. The casing-anchor type element is 66" long. It comes in either a single anchor or double anchor version. The anchor section has the rubber removed to ex-pose the stainless steel ribs. The anchor sections, along with the rubber covered section, expands upon inflation and forms a combination anchor and seal. Different elastomeric materials are available and used depending on the well conditions that the tool will be run in.
 
4. Delayed Inflate Valve: The delayed inflate valve prevents the element from being prematurely inflated when fluid is circulated down the tubing or when the tubing is filled in low fluid level wells. It is located in the inflation fluid path between the thread release sub and element and closes the path off with a shear pinned sleeve
valve. Tubing pressure over the shear pin value opens the valve and allows the element to inflate.
 
5. Double Element Connector: Two elements can be connected by a double-element connecting sub to provide a dual seal packer. This packer is used in applications requiring a longer seal than provided by a single element.
 
6. Packer Element Adapters: By use of the Packer Element Adapter, several size elements can be adapted to the same tool body.
 
7. Mandrel: Some PIP sizes have a choice of mandrel ID's available, depending on the tubing string being run and or Customer requirements.
 
8. No Turn Tail Pipe Assembly: When two or more PIP tools are run in the tool string, it may be un-desirable to release them all at the same time. The torque required to turn all the mandrels at one time may be excessive or the pressure im-balance in the hole may make it desirable to re-lease one tool at a time. When the no-turn tailpipe assembly is run, torque to the top tool is not transmitted to the next tool until the top tool is released and pulled into tension. Therefore only one mandrel is turned at a time and only one tool is released at a time. When tools are run in straddle configuration and fluid is injected between them, a large load can be created tending to push the tools apart. If one PIP tool is attached to the mandrel of a second PIP tool, the load from the injection pressure is taken by the mandrel of the top tool which has limited strength. (See Tensile Rating on Specification Chart) When the no-turn tail pipe assembly is used, the injection pressure load is transmitted through the packer element giving the straddle section a higher pressure rating
 

Drawing references

 

2.00" ID And 2.50" Single Set PIP™/Rotational Release Assembly