The Last Line of Defence in Subsurface Safety

It is recommended, and in the majority of cases mandatory, to incorporate a secondary means of closure for all wells that are capable of natural flow to surface into the design of the completion string. The installation of a Subsurface Safety Valve accommodates this requirement by providing a positive emergency closure mechanism. Usually located below the surface Tubing Hanger, the valve can be either designed to close automatically when a predetermined flow condition occurs in the well or remotely operated on a fail-safe principle from surface.

All of our Safety Valves incorporate the PTP Wedge Fitting connection as standard, to accept the Control Line and introduce communication between the valve and surface for successful operation. Our Safety Valves are designed and manufactured to provide positive subsurface control of oil and gas in, Production, Injection and Gas Storage wells both offshore and on land. PTP provide a range of Tubing Retrievable and Wireline Retrievable models supplied in 5,000 psi – 10,000 psi pressure ratings. We also offer a full and extensive family of accessories for all valves; including Lock Open Tools, Puncture Communication tools and Running/Pulling Prongs. Valves are available based on Metallurgic and Elastomeric requirements to suit virtually any well environment.


Innovation in Zonal Isolation

In respect of potential damage that can be caused to the production casing, a method of annulus isolation is required in the majority of production and injection wells. This annular isolation is performed by installing a Packer in the completion string. The Packer is a sealing device that isolates and contains well pressure and production fluid within the wellbore to protect the casing and other formations above or below the producing zone. This is essential to the basic functioning of most wells. The Packer is lowered into the wellbore with an elastomeric element in the retracted position. At the prescribed depth, the element is set by mechanical or hydraulic manipulation, to fill the annular space between the tubing and the annulus. PTP Packers fulfill the industry’s goal of increased downhole efficiency and offer an economic solution to the oil industry’s well completion demands and ever increasing costs.

PTP can provide a range of Permanent and Retrievable Packers each with a full family of accessories including Seal Assemblies, Anchor Latch Assemblies and Mill out Extensions.  A wide variety of material and elastomer options are also available to suit virtually any well environment.


Influence the Production String

It is necessary to consider a range of Tubular Mounted accessories which are both worthwhile and in cases compulsory for incorporation into the completion string design as a future contingency. Below are some of the more prevalent instances where one of these components will be required.

  1. Downhole Tubing Detachment – In the event of Tubing failure, it will become necessary to pull the completion from the well to effect replacement of certain completion componen This detachment can be obtained by installing a removable locator device which seals with the rest of the tubing string to be left in the well during normal conditions but which can be pulled as required. In such cases a means of hydraulic isolation of the tubing below the point of detachment is required. Examples of this are a packer seal system that allows the tubing above the packer to be disconnected and retrieved, or a downhole hanger system that suspends the tubing in the well beneath the wellhead. Completion components that require frequent replacement will be located above such devices.
  2. Tubing Stresses – During the normal cycle of well operations, the tubing string can expand or contract due to variations in both subsurface pressure and temperatur The tubing string is normally landed off in the wellhead and in contact downhole with the casing through the packer. Considering this, if the amount of movement were severe, it would give rise to damage to the packer, wellhead or the tubing itself. A moving seal system can be installed which would allow expansion and/or contraction of the tubing without mechanical failure or disengagement. Various systems are available; however, they all feature a concentric sleeve approach where seals are located in the concentric annulus and one of these sleeves is stationary.
  3. Ability to suspend P & T Monitoring Equipment – It is commonly required to monitor the bottom-hole pressure during production tests and, in such cases, there will be a requirement to run and install a pressure or temperature gauge at a specific location in the This is most commonly accommodated by the installation of a Landing Nipple in the completion string. Its location is normally as deep in the well as possible.
  4. Wireline Re-Entry Guide – It will be necessary, in most wells, to conduct wireline or coiled tubing operations below the bottom of the tubing string, or across the perforated interv In such cases, whilst pulling the tool string, a Wireline Re-Entry Guide is installed to aid in guiding the tools back into the lower end of the tail pipe of the tubing string.

PTP offers a range of Tubular Equipment and Accessories as solutions to the above mentioned requirements, for tubing sizes ranging from 2-3/8” through to 7.000”.


Complete Control in Downhole Flow Manipulation

In the majority of completions, a specific piece of equipment is installed to allow the opening and subsequent closure of a circulation port between tubing and annulus in a production environment.This can be provided by installing one or more of the following devices; Sliding Sleeve (SSD), Side Pocket Mandrel (SPM) or a Ported Nipple to supplement the downhole SSSV and also provide isolation if the well is hydraulically dead and the SSSV is to be removed. Thus, the provision of this isolation is normally provided deep within the wellbore either just above or just below the packer.

The isolation can be provided by lowering a plug down the inside of the tubing string until it lands and locks into a nipple at a predetermined depth which has been incorporated into the design of the completion string.

PTP have the capability to supply industry proven flow control equipment to allow control of your well through intervention methods.


Superior Assistance in the Production of Well Fluids

In a flowing well there is enough energy stored in the reservoir to flow the well to the surface, this energy is furnished by a combination of reservoir pressure and formation gas. Under some reservoir conditions, for example, if the differential pressure is not sufficient enough to drive the production fluid to surface and maintain production at an economic level, it becomes necessary to install artificial lift. Gas Lift is the process of injecting high pressure gas into the production tubing to boost the reservoir energy and lighten the hydrostatic head. This artificial lift is achieved by either the expansion of injected gas in the well, reducing the fluid gradient, the displacement of fluid by compressed gas, or a combination of one or more of these. There are two recognized types of artificial lift, ‘Continuous Flow’, most common in wells with high fluid levels but insufficient gas pressure and/or volume to flow naturally; and ‘Intermittent Flow’, in wells with low productivity wells where the injection of gas on an intermittent basis is used to drive a build-up of liquid in the wellbore to surface. The Gas Lift installation may also be used when produced fluids contain corrosive components such as CO2, or have high pour points with attendant flowing pressure loss problems. In such cases, it may be necessary to introduce specific chemicals into the flow string at a location deep within the well to provide maximum benefit and counteract the impact of these characteristics.PTP provides complete Gas Lift and Chemical Injection Systems tailored to specific requirements.


Oversee the Actuation of Downhole Completion Devices

Service tools are designed for the use of running, retrieving or activating subsurface locks, plugs and other downhole flow control devices from the tubing bore. These subsurface devices are designed to incorporate an industry standard profile in which the service tool can engage/locate for pulling and shifting operations and will generally incorporate a shear mechanism running operations. Shifting profiles are internal, however, fishing profiles can be either internal or external, and therefore the fishing profile will designate which retrieval tool must be used.

Each service tool is designed to incorporate an emergency shear release feature. This is so that they may be released from the profile downhole in the event that the device becomes stuck. The Emergency Shear Release feature is most commonly achieved through the utilization of a shearing pin. This feature is activated at the surface by the manipulation of the wireline to apply upward or downward jarring action.

PTP Manufacture, Sell and Service a complete line of wireline service tools for generalized and specialized wireline well service.


Resolute Wellbore Provision and Maintenance

The Toolstring shown opposite is the standard supplied by PTP for downhole wireline work. Non-standard Toolstring configurations can be required depending on well conditions such as depth, drag, or hole size. In most cases these conditions can be overcome by adapting the toolstring make up. For alternative configurations please contact a PTP sales representative.

Any components below the Knuckle Joint will vary depending on the operation to be performed such as fishing, bailing, downhole installation, downhole retrieval, etc.

Standard Toolstring consisting of:

  • Rope Socket (0.092”, 108” or 0.125” Wire Size)
  • Means of attaching the Toolstring to the Wire.
  • Standard Stem (2, 3 & 5 ft Lengths)
  • Provides weight to overcome friction and pressure acting on cross section of the wire created by the packing located in the Stuffing Box.
  • Spang Jar (20” & 30” Stroke)
  • To increase jarring impact downhole.
  • Heavy Duty Knuckle Joint
  • Ball & Socket design to allow for Rotational and Angular motion when running in hole in the event that the tubing is crooked or corkscrewed.

Wireline tools are designed to provide one of three very basic functions. These functions are to ensure the tubing ID is clear in order to pass subsurface flow control devices to their desired locations (Tubing Swage, Tubing Gauge, Tubing Broach), identifying objects or obstructions (Lead Impression Block, Blind Box) or finally to remove them from the well (Prong Grab, Wireline Magnet, Fishing Spear).

Coming Soon!


Containment in the most Arduous Conditions

Pressure Control Equipment is essential for wireline and coiled tubing services, when moving tools in and out of a live wellbore. This equipment is made up to the wellhead as services are being performed and is designed and assembled with lengths and ID’s sufficient to accommodate the length and diameter of the toolstring being run. PTP’s Pressure Control Equipment are designed and tested with the same emphasis on Quality Assurance which conforms to the rigorous and internationally recognized ISO9001 Standard and compliance to API6A Wellhead & Christmas Tree Equipment Standard.

Coming Soon!


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