Skip to main content

Dry-Running Sealing Technology: Pump Applications (P1)


Non-contacting, dry-running seal technology, a revolutionary technology for pumping equipment, was developed and pioneered by John Crane and meets the USA Clean Air Act of 1990. This Act defines emission standards for rotating equipment. Designed for emissions control, this sealing concept has resulted in improved reliability, efficiency, and cost benefits when compared to competing technologies such as canned and magnetic drive pumps.

A non-contacting, dry-running seal solves the tribological problems when pumping certain fluids rather than transferring those problems to other areas of the equipment as in the case of competing technologies.

Many plant operators have a Mean Time Between Planned Maintenance (MTBPM) of less than two years. In some cases, equipment is down for repair every two to three months. This has a major impact on the cost of owning the equipment and may also impact the amount of product being manufactured. By properly applying non-contacting, dry-running seal technology, the benefits in improved reliability are significant.


What the User Expects

The user expects exceptional performance throughout the life of the equipment. Running a plant with fewer operators and mechanics means the complete pumping system must run when it is needed and last a long time. The pump must operate safely and meet existing regulations while reducing cost. Pump and seal systems are vital to a plant’s operation. They must be carefully selected for each application to achieve the design reliability.

Causes for Short Seal Life

At the 1997 International Pump User’s Symposium in Houston, TX, users attending a forum on mechanical seals were asked to identify the causes for short seal life at their plant. The problems identified were:

· Improper operation of the pump
· Dirt flushed in the seal chamber
· Start-up without venting
· Vibration of equipment
· Misalignment/pipe strain
· Worn seal chamber bushing
· Pump control/level flow control
· Installation
· Loss of seal flush
· Cavitation
· Process problems
· Low NPSH
· Dry run

Solutions to Common Problems

Read more:

Comments

Popular posts from this blog

Top 8 Reasons for Mechanical Seal Failure and How to Prevent Them

Mechanical seals are critical components of pumps, responsible for maintaining a fluid-tight seal between the rotating shaft and the stationary pump housing. However, these seals can fail due to various factors, leading to leakage, reduced pump efficiency, and costly downtime. In this article, we will discuss the top reasons for mechanical seal failure in pumps and how to prevent them. 1-Improper Seal Selection Choosing the wrong mechanical seal can cause it to fail. Consider the following factors that can contribute to seal failure: • Chemical compatibility: All seal components, such as the seal faces and O-rings, must be compatible not only with the process fluid being pumped, but also with non-process fluids used for cleaning, steam, acid, and caustic flushes, etc. • Physical degradation: Using soft seal faces on abrasive liquids will not last. Shear-sensitive liquids, like chocolate, can break down and leave behind solids (such as cocoa powder) and force out liquids (like oil). • S...

Dry Gas Seal Failure Modes

BY BHUSHAN NIKAM. Invented in the mid-20th century and typically equipped in process gas centrifugal, dry gas screw compressors and expanders, dry gas seals (DGS) are the preferred gas lubricated dry seal solutions available on the market. They have become the standard for new machines. DGS are robust, simple, consume less power, and are more efficient in reducing leakage than their predecessor. Various configurations such as tandem with and without an intermediate labyrinth ( Figure 1 ), single ( Figure 2 ), and double ( Figure 3 ) are available & shall be selected based on process requirements. In this article, we discuss the various DGS failure modes and how they should be addressed:  PRESSURIZED HOLD/STANDBY Pressurized hold, also called settle-out condition, occurs when the compressor remains at a standstill, but the casing is pressurized. If an alternate process gas lacks sufficient pressure and flow, process gas enters the seal cavity through the process labyrinth ...

Why Pump Shafts Often Break at the Keyway Area

By NTS Pump shaft failure can lead to significant downtime and repair costs in industrial plants. One of the most common locations for pump shaft failure is at the keyway area. In this article, we will explore the reasons why pump shafts often break at the keyway and what can be done to prevent such failures. The keyway is a high-stress point (weakest point)  on the shaft, where a key is inserted to transmit torque between the shaft and the pump impeller or coupling. During operation, the keyway experiences cyclic loading that creates a bending moment in the shaft, which is concentrated in the keyway area. Over time, this cyclic loading can cause fatigue failure in the shaft material, leading to a fracture at the keyway. In addition to cyclic loading, other factors can contribute to shaft failure at the keyway. Improper keyway design or installation can lead to stress concentrations or inadequate clearance between the key and keyway . Misalignment or overloading can also cause ex...

John Crane's Type 28 Dry Gas Seals: How Does It Work?

How Does It Work? Highest Pressure Non-Contacting, Dry-Running Gas Seal Type 28 compressor dry-running gas seals have been the industry standard since the early 1980s for gas-handling turbomachinery. Supported by John Crane's patented design features, these seals are non-contacting in operation. During dynamic operation, the mating ring/seat and primary ring/face maintain a sealing gap of approximately 0.0002 in./5 microns, thereby eliminating wear. These seals eliminate seal oil contamination and reduce maintenance costs and downtime. John Crane's highly engineered Type 28 series gas seals incorporate patented spiral-groove technology, which provides the most efficient method for lifting and maintaining separation of seal faces during dynamic operation. Grooves on one side of the seal face direct gas inward toward a non-grooved portion of the face. The gas flowing across the face generates a pressure that maintains a minute gap between the faces, optimizing flui...

FACTORS IMPACTING COMPRESSOR SURGE

BY AMIN ALMASI. Surge can be a major challenge for turbo compressors. Operation in the surge area will result in instability, exposing the machine to destructive stresses and forces, high vibration, and even serious damage. Surge during shutdown (trip) has been reported for many turbo-compressors. This is particularly possible if the machine operates at high head and low flow, immediately before the trip, when the operating point can move toward the surge line and even pass it during coast-down (when the turbo-compressor reduces flowrate). When a turbo-compressor experiences a serious alarm, an emergency shutdown is usually initiated. But an immediate shutdown could result in a surge. In this case, the surge happens shortly after the shutdown (trip) and at a high energy level. This could be a surge at a high head (operating point could pass the surge line at high head). In many cases, there are advantages to not removing the driving power from the turbocompressor (tripping) immediately...