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Virtuoso condition monitoring compressor performance software

Best-in-class reliability and asset management relies on an effective monitoring program. The challenge is finding the right service that meets your operating needs and budget. Wood Group understands machinery reliability. We also understand that monitoring must deliver value to your maintenance and operations teams.

Our approach offers many advantages:

  • Monitoring of any rotating and reciprocating machine (turbines, engines, motors, compressors, pumps, etc.)
  • Comprehensive program tailored to your needs. Analysis options include:

    • Vibration

    • Performance

    • Lube oil

    • Troubleshooting

    • Optimization and reliability support

  • Practical recommendations and advice from our machinery experts

  • Competitive costs compared to OEM-based approaches
  • Real time trending, alarming and reporting without the need for expensive software or hardware purchases

We deliver:

  • Unit, fleet or plant summary and report cards
  • Alerts and recommendations to avoid downtime and production losses
  • Advice on where to focus your maintenance efforts to achieve the best financial return.

Contact us for a demo of our system, or to discuss monitoring options for your facility.

The following examples illustrate how Wood Group’s program can generate significant value. 

1 Declining Engine Oil Pressure Caught

An engine oil pressure pattern anomaly was observed by a Wood Group analyst. The pressure was seen to be on a downward trend, though still at acceptable levels.


First alert was sent to customer on Aug 20


Second alert was sent to customer 11 days later, on Sep 1, with a high risk level calling for immediate action.

Customer’s Reaction: 
“Looks like B Pool engine oil pressure is fading. We'll lose an engine if we don't take action.“

Customer reported finding the oil relief spring worn into the housing. 
The problem was corrected and oil pressure returned to the normal range.


Feedback from customer: "Thank goodness Wood Group [formerly BETA Machinery Analysis] identified the problem, which avoided unplanned downtime and may have saved the engine."

2 Centrifugal Compressor Examples
2.1 Motor Driven Centrifugal Compressor

This example is from a motor driven centrifugal compressor. Performance was analyzed over a one year period using control system data.

The graph shows that polytropic efficiency (red curve) decreased steadily from 66% to 58%. Motor power (black curve) to deliver the same flow increased by about 100 kW. If the driver is operating below its rated power, as was the case here, the main consequence is an increase in operating cost. When the driver reaches its limit, any further efficiency decrease causes a loss of throughput, which is usually very costly.

Decreasing efficiency is likely due to some combination of impeller fouling, impeller wear, and/or increased clearances. Monitoring enables planning and scheduling maintenance on an informed basis.

2.2 Centrifugal Compressor Deviation from Baseline

In this case, centrifugal compressor performance is evaluated against the wheel curve baseline for this particular unit. This is the best approach to monitoring centrifugal compressor performance, especially where operating conditions vary significantly.

In the figure below, this unit had an 11% deviation in head at the point shown, likely due to impeller fouling, impeller wear, and/or increased clearances.

The decrease in stage performance (measured as head deviation) required extra power to compress this gas; about 325 BHP in this case. It was estimated that the extra fuel cost was over $250,000 per year, based on prices at the time.

2.3 Offshore Platform Units - Varying Gas Turbine Inlet Differential Pressure Indicates Air Filters Being Bypassed

Several large gas turbine/centrifugal compressor units located on offshore platforms were being monitored under BETA’s Performance Assessment service. One important parameter is the measured differential pressure across the inlet air filters on the gas generator section of the gas turbine.

Air inlet differential pressure had been quite steady at 1.5 – 2.0 in. H2O. Then, near the end of September, 2011, the reading started to vary, from about 2 in. H2O down to zero.
The concern in this case is the low, near zero readings as these indicate that air was bypassing the filters at that time. 

A closer inspection shows that there were peaks about every 24 hours. The zero readings were mostly occurring during the hottest part of the day. (This site is around 20 degrees north latitude.)

It was concluded that a filter had been replaced and the fit of the replacement filter was not quite correct; thermal distortion of the inlet ducting allowed air to bypass the filter during the hottest part of the day. The problem with this situation is that dust and other contaminants can accumulate on the initial stages of the gas generator compressor causing performance to decrease rapidly.

2.4 Predictive Maintenance - Oil Filter Differential Pressure Change

Operating data from eight large gas turbine/centrifugal compressor units is reviewed regularly by one of BETA’s monitoring specialists, who communicated the following issue to the customer on November 24th:

ISSUE NOT YET RESOLVED
Observation/Action Unit 1 power turbine oil filter differential pressure (tag DPT-301) has been trending up and reached 11 psi on November 19. 
Recommendations Plan for filter change; probably within 1 month
Probability 2 - Medium (likely)
Consequences 2 - Medium - equipment shutdown
Risk Level 1 - Perform action ASAP

The graph below illustrates what happened to that point and subsequently. The cursor (vertical red line) is parked at November 19th. The horizontal solid black line is an alarm level of 15 psi. By December 2, eight days later, the differential pressure reached the alarm level. The customer changed the filter on December 7th. Early warning from BETA enables planned maintenance, avoiding, or minimizing lost production that could occur due to a machine trip.

3 Reciprocating Compressor Examples
3.1 Fouled Heat Exchanger Identified

An FPSO has three large motors driving critical reciprocating compressors. BETA’s Performance Assessment service was monitoring these compressors and motors. Rising winding temperatures were seen in the B unit motor. Although well below alarm levels, the temperatures were higher than the equivalent readings from the A and C motors. The customer was alerted.

NEW ISSUE
Observation/Action B1105, created Jan 16, 2012. Unit B motor winding temps are near 115 ºC and have been rising steadily since Dec 30. Comparable unit A temperatures are about 95 °C and unit C about 85 °C. 
Recommendation Verify measurements; ensure proper cooling flow.
Probability 2 - Medium (likely)
Consequences 1 - Major - major equipment failure
Risk Level 2 - Perform action as soon as possible

The customer promptly investigated, found and corrected problems with a heat exchanger.

ISSUE RESOLVED
Observation/Action B1105, created Jan 16, 2012. Unit B motor winding temps reached 116 °C and were rising steadily. Unit A motor winding temperatures were about 95 °C, and unit C motor about 85 °C.
Recommendation Verify measurements; ensure proper cooling.
Resolution Inadequate cooling flow and fouled seawater exchanger were found and corrected.
Probability 0 - Not analyzed
Consequences 0 - Not analyzed
Risk Level 5 - No action required

This proactive intervention enabled correcting the problem with no loss of production. Without monitoring, the exchanger performance may have degraded until temperatures hit alarm level, requiring emergency response and possible lost production.

For more information about BETA’s cost effective remote condition and performance assessment service, contact info@BetaMachinery.com. The service covers all types of equipment used in gas compression.

3.2 Identifying a Subtle Compressor Vibration Change Prevents a Costly Major Failure

On August 27, 2012, when performing a regular review of reciprocating compressor units for a customer, one of BETA’s analysts sent the following communication to the customer:
“I am seeing a clear compressor vibration increasing trend. Current level of vibration is not very high but a trend is obvious. I do not see any speed/load change on this unit.”

The vibration was still well below the alert level, but was recognized as abnormal by the remote monitoring specialist.

On October 11, 2012 BETA received this communication from a grateful customer:
“Because of your alert we investigated and found that the small end bushing in the #2 throw of the compressor had failed. We have corrected the issue and the unit has been online since Oct 5th, 2012 with the new bushing installed. The vibration levels appear to have returned to their nominal values. Thank you.”

Connecting rod bushing failure

Significant and costly damage was avoided thanks to BETA monitoring the unit. This failure would likely have eventually resulted in seizure of the assembly and a major wreck.

3.3 Pipeline Company - Significant Damage to Reciprocating Compressors Averted

While monitoring a fleet of compressors owned by a large pipeline company, the assigned BETA specialist found a discharge temperature deviation on unit 3 and alerted the customer.
The following alert identifies what was observed, the probability and consequences of risk and provides a recommended course of action. In both cases shown, the consequence of inaction is significant equipment failure.

New Issue for Unit 3
Observation/Action Issue raised Feb. 11, 2013. Discharge temperature deviation on throw 4 has been increasing since Jan. 30 2013 and reached from 14 to 24 °C on February 11, 2013.
Recommendations Check throw 4 for a valve problem. Also check lubrication rates on this throw.
Probability 1 - High (very likely)
Consequences 2 - Significant - equipment failure
Risk Level 2 - Perform action as soon as possible
Unit 3, Throw #4

The unit was discovered to have one failed head end discharge valve.

A similar problem occurred on unit 21, throw # 2 and the unit was discovered to have two failed crank end discharge valves.

New issue for Unit 21
Observation/Action Issue raised Feb 11, 2013: Discharge temperature deviation throw 2 stage 1 has increased from 8 to about 16 °C since Feb 05, 2013.
Recommendations Check throw 2 for a valve problem and/or lube rates on this throw.
Probability 1 - High (very likely)
Consequences 2 - Significant - equipment failure
Risk Level 2 - Perform action as soon as possible

Benefit of the Monitoring Program
The early detection of failing compressor valves preserved compressor capacity and efficiency, and prevented secondary damage that can occur if a valve disintegrates. The second case is particularly significant; failed crank end discharge valves can lead to catastrophic failure, as the rod load tends toward continuous tension with little, or no reversal. Fortunately, the customer took immediate action and both units were repaired within four days of receiving the alert, averting significant equipment failure.

3.4 Subtle Compressor Performance Problem Detected

Subtle faults usually turn into big problems and early warning can head off major failures. This example arises from remote monitoring of a four throw, two stage gas compressor. Throws 2 and 4 are on stage 1; throws 1 and 3 are on stage 2.

Rather than monitoring raw temperature data, the following chart is based on a derived measure called “discharge temperature deviation.” The “deviation” is the difference between expected versus measured discharge temperature.

This graph shows a history of cylinder 4 discharge temperature (the black curve). Close examination shows a small increase, but not enough to cause any concern.

For more information about BETA’s cost effective remote condition and performance monitoring service, contact info@BetaMachinery.com. The service covers all types of equipment used in gas compression. 

However, we see significant increase (red curve). This usually points to a valve leak or possibly a ring leak.

For confirmation we can check the stage compression ratios. The stage 1 compression ratio decreases and the stage 2 compression ratio increases. This is consistent with performance degradation on stage 1.

Further confirmation is found from measured flow (after the recycle valve) and recycle valve position. Over the same time period as the previous graphs, the flow is essentially constant. But the recycle valve position decreases from about 20% to about 15%. 

The data indicates a loss of compressor throughput. Conclusion: There is a valve or ring leak on throw 4.

This example illustrates that detecting subtle problems like this one requires advanced techniques in the hands of trained specialists. Automated processing procedures that rely on simple methods such as looking for a significant temperature change would likely not have detected this.

4 Virtuoso Monitor Software

Virtuoso monitor best performance monitoring software for compressors

Wood Group uses Virtuoso®/Monitor - a robust, online, real-time, dynamic simulator for monitoring oil and gas production.

Monitor's functionalities include liquids inventory management, line pack monitoring, composition and chemical tracking, hydrate warnings, leak detection, pig tracking, instrument/equipment surveillance and much more. Monitor's functionality makes it an essential tool for monitoring production systems. Read more


 

Compressor Performance Monitoring Software Virtuoso
 

 

 
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