electric downhole safety valve in stock

Our downhole safety valves provide your testing operations with fail-safe sustained control downhole in the event of an emergency or to facilitate test procedures.

Surface-controlled subsurface safety valves (SCSSVs) are critical components of well completions, preventing uncontrolled flow in the case of catastrophic damage to wellhead equipment. Fail-safe closure must be certain to ensure proper security of the well. However, this is not the only function in which it must be reliable—the valve must remain open to produce the well. Schlumberger surface controlled subsurface safety valves exceed all ISO 10432 and API Spec 14A requirements for pressure integrity, leakage acceptance criteria, and slam closure.

Through decades of innovation and experience, Schlumberger safety valve flapper systems are proven robust and reliable. The multizone dynamic seal technology for hydraulic actuation of subsurface safety valves is a further improvement in reliability performance when compared with traditional seal systems in the industry.

The multizone seal technology is currently available in the GeoGuard high-performance deepwater safety valves, which is validated to API Spec 14A V1 and V1-H.

Baker Hughes’s portfolio of subsurface safety valves deliver reliable performance when it matters the most, providing emergency closure in the event that well control is lost. We offer a full range of valves to suit applications ranging from shallow- to deep-set, and the valves are available in surface- and subsurface-controlled, tubing-retrievable, and wireline-retrievable options. All Baker Hughes valves undergo stringent prototype testing and conform to standards and specifications such as API and ISO, as well as requirements requested for your unique situation.

Operators must be confident in reliability of these mission critical components. Tejas designs and tests their API-14A Safety Valves to the most stringent standards.

Camco* Products & Services built the first eValve under license from the original inventors in the mid 1970s. There have been 12 or more installations of this valve design in wells over the years, deployed by Camco. At that point in its history Camco was the world leader in the hydraulic SCSSV market and subsequently made a business decision not to pursue further development of the eValve believing it was consuming its own market. Deep set SCSSV applications at that time were non-existent. As a result, assignment and ownership of eValve returned to the original inventor/licensors. With recent renewed industry interest in electric SCSSVs for deep set applications, the owners of the eValve contacted Tejas about bringing it up to current industry standards.

The Tejas tubing retrievable injection valve, or TRIV™, is a subsurface controlled, injection safety valve that features the patent-pending Tejas VOi™ variable orifice insert. It is designed to prevent injection fluid from flowing back out of the well if the surface control system becomes damaged or malfunctions. The TRIV also provides pressure management as the surrounding reservoir wells are produced.

The Tejas HPHT Tubing Retrievable Surface Controlled Subsurface Safety Valve (SCSSV) is a 25,000 psi rated working pressure, non-equalizing, xHPHT safety valve. It is designed to minimize the loss of reservoir fluids or production equipment by shutting in the well in the event a catastrophic surface or subsurface event were to occur.

The Tejas TRCF series surface controlled subsurface safety valves (SCSSV) are rated to 10,000 psi [68,948 kPa] working pressure at 350deg F [176.7degC]. TRCF valves are designed to automatically shut in the well and prevent unrestricted well flow in the event of a catastrophic surface or subsurface event.

This valve is a rod piston actuated, normally closed, fail-safe safety valve which is held open with control pressure supplied from the surface by an emergency shut-down (ESD) system to a hydraulic control line that connects to the valve. Loss of control line, ESD system, pressure returns the valve to the closed postion.

The Tejas TRSV is a 5,000 psi rated working pressure, safety valve with a self-equalizing option. It is a rod piston actuated, normally spring closed, fail safe, safety valve which is held open with independent control pressure supplied from the surface by a hydraulic control line that extends through the wellhead to an emergency shut-down (ESD) system at the surface. Removing the control line pressure will return the valve to its normally closed position.

Halliburton provides proven, high-performance tubing-retrievable and wireline-retrievable subsurface safety valves (SSSV) designed to reliably shut-in (fail safe) if a catastrophic event occurs, allowing operators to maintain safe operations.

The valve operates on a hydraulic piston principle. To open, hydraulic pressure slightly higher than the well pressure is applied to move the piston downward. This pressure unseats the secondary seat, allowing pressure to enter through equalizing ports. Then, as additional hydraulic pressure is applied to the piston, it continues downward movement, pushing the flapper open.

The TSS series subsurface safety valves are tubing retrievable surface controlled subsurface safety valves. Compared with the TS series, the safety valve features super slim outer diameter design. The control line connects the valve to the surface, and the pressurization from surface on the control line controls the opening and closing of the flapper. This series of products includes self-equalizing and non-equalizing types.

Safety valves are designed to automatically shut in the flow of a well in the event surface controls fail or surface equipment becomes damaged. They are classified according to the location from which they are controlled – surface or subsurface. In this article, subsurface safety valve types, operating systems, working principle, setting depth, and selection process are presented.

It is advisable, and in most cases mandatory, to have a secondary means of closure for all wells capable of natural flow to the surface. The installation on of a sub-surface safety valve (SSSV) will provide this emergency closure capability.

Operating systems may be either remotely operated on a fail-safe principle from surface (SCSSV) actuated from a control panel located on surface, or will be a subsurface controlled (SSCSV), designed to close automatically when a predetermined flow condition occurs in the well (actuated by the pressure differential/flow velocity across the valve).

In case of SCSSV, a 1/4″ inch stainless steel control line is attached to the outside of the tubing string and installed when the tubing is installed. Depending on the wellhead pressure, it may be necessary to keep as much as 4000 to 5000 psi on the control line to keep the valve open.

The differential type subsurface controlled subsurface safety valve senses pressure drop across a flow bean. There are several variations of the differential type SSCSV. Although they employ different sealing devices, such as a flapper or ball, they all are controlled with a flow bean and spring tension.

As shown in the following video, when hydraulic pressure is applied down a control line, the hydraulic pressure forces a sleeve within the valve to slide downwards. This movement compresses a large spring and pushes the flapper (in case of flapper type SCSSV) or the ball (in case of ball type SCSSV) downwards to open the valve. When hydraulic pressure is removed, the spring pushes the sleeve back up and causes the flapper (or the ball) to shut. In this way, it is failsafe and will isolate the wellbore in the event of a loss of the wellhead.

The location of the downhole safety valve within the completion is a precisely determined parameter intended to optimise safety. There are arguments against it either being too high or too low in the well and so the final depth is a compromise of all factors. MMS regulations state that the valve must be placed no less than 100′ below the mudline.

Aberdeen-based oil and gas production technology business Pragma said it has developed an advanced downhole safety valve to create an improved well control solution for cable deployed Electric Submersible Pumps (ESPs) retrofitted to production wells.

The new valve will enable on and offshore installations to meet all safety regulations while improving the operational footprint at the wellsite during installation and retrieval by reducing time, cost, personnel and risk.

An API 14A qualified subsurface safety valve (SSSV) is a legal requirement for producing wells in many regions. These devices generally use a flapper style mechanism and are incorporated in the production tubing during completion. However, when an ESP is retrofitted to a well, its surface control lines run through the inside of the production tubing, obstructing the SSSVs and creating the requirement for an additional safety valve. A rig would usually be mobilized to deploy the valve and then the ESP in separate runs, however cable deployment now provides significant cost and efficiency savings.

Pragma said its ESP safety valve has been designed to complement this type of deployment. It is a compact device, integrated within the lower portion of the ESP assembly and is deployed and retrieved through the production tubing in the same run as the ESP. It is the only device on the market which offers wellbore closure below the ESP control lines, the developer said. By installing the valve between the ESP and ESP packer, the valve does not rely on the integrity of aged well completion components unlike alternative systems.

The valve’s functionality is based on a novel pressure differential, or lift actuated design, requiring no pressurized chambers, hydraulic control lines or electrical power, which safeguards reliability. The valve will fail-safe close when the ESP is switched off and can be opened and closed as many times as required. The technology can also be applied to alternative artificial lift systems including capillary strings, gas lift velocity strings, progressive cavity pump and jet pump systems. A high temperature version is also available.

Pragma Technology Manager, Matt Manning, said, “Like a demand valve, or pressure regulator between the tank and mouthpiece of deep-sea diving equipment, our valve uses the ESP’s lifting capability to open or close it in line with production. The unique design advantages of this technology, combined with its compact nature, not only provide greater safety and reliability assurances to the operator, but also lower installation, operation and retrieval costs. The technology has been developed in-house and we are conducting prototype testing, with field trials and API 14A certification planned later this year.

“As the oil and gas industry continues to evolve, it’s important the supply chain also adapts to deliver quality solutions to support cost reduction and production optimization. The ESP safety valve is just one example of how Pragma continues to pioneer advanced technologies to deliver safety and efficiency gains.”

A well with a malfunctioning tubing retrievable sub surface safety valve (TRSSSV) was shut in until a lock-out operation could be undertaken, one which would secure the valve in a fully open position, enabling subsequent intervention programs to be carried out and the well put safely back on production. The TRSSSV design utilized a flapper valve with a power spring mechanism which forces the valve to a normally closed position. Control to the flapper had been lost as the hydraulic communication had been cut off. Repeated attempts to lock open the valve using the conventional lock out tool were unsuccessful, with its flapper returning to the closed position over time.

The innovative solution presented in this paper was to engineer a simultaneously operated dual stroker electric line toolstring assembly, one leveraging several technology elements and executing several steps in a single run operation: (1) to position the work string correctly prior to engaging with the TRSSSV flow tube, (2) to operate the upper stroker to provide the axial force and stroke distance required to push the flow tube down to fully open the TRSSSV and hold it there until "locked", and (3) to simultaneously operate the lower stroker with expander adapter and dimple tool, to deform the valve flow tube and integral lock out sleeve when in a precise and predetermined position and in doing so permanently locking the valve in the open position. Carrying this out as a single trip operation would ensure the dimpling occurred only with the flow tube in the exact required "valve open" position.

Some initial electric line runs were also carried out as part of the overall operation, namely a broach and a brush for cleaning possible scale accumulation. Following the successful lockout, the required diagnostic logging was completed, a straddle deployed to hold a wireline retrievable subsurface safety valve, and the well brought back into production.

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