Hamad K. Al-Ruzihi is currently a turbomachinery engineer and vice chair of Saudi Aramco’s Compressors, Gears, and Steam Turbines Standards Committee. He earned a bachelor’s degree in mechanical engineering from Colorado State University and a master’s degree from Texas A&M University. Al-Ruzihi is responsible for providing support to Saudi Aramco operating facilities and projects on various turbomachinery applications. He is a certified machinery lubricant analyst I, vibration analyst category II, and taproot analyst.

Hamad K. Al-Ruzihi

Two multistage 16,000 HP electrical motors are used to drive two onshore gas compressors feeding a gas plant commissioned in 1984. These compressors needed to produce gas at a higher capacity. Unfortunately, the existing units were unable to meet the new demand. One option considered was purchasing and installing an additional compressor.

However, engineers also evaluated the possibility of utilizing the existing adjacent offshore compressors available capacity. Although onshore and offshore gas compressors are located on the same platform and discharge to a common header, they were designed to process different gas molecular weight (MW) due to separate feeds for onshore and offshore units (Figure 2). The challenge was to ensure that offshore compressors can handle not only the new capacity but the new gas conditions.

As the plant receives gas from two different associated crude oil fields that are producing different API oil grades, changing gas MW is prevalent due to the number of online producing wells. Understanding the effect of changes in gas molecular weight can enhance performance prediction and capacity control of centrifugal compressors.

The original 1980s design assumed a molecular weight of 32 g/mole. But recent simulations and forecast predicted a 12-18% reduction in molecular weight. This simulation was validated through test samples that showed a molecular weight of 27 g/mol.

In addition, inlet temperature and pressure have significant impact on centrifugal compressor performance. The required system polytropic head and differential pressure are indirectly proportional to molecular weight. Generally, centrifugal compressors operating at higher molecular weight than design are able to deliver higher actual volumetric flow rate at the new gas condition. But at a lower molecular weight, more head needs to be developed by the compressor to achieve the mandated head. Therefore, the inlet flow rate would need to be decreased, moving to the left on the Head-Flow curve, to satisfy higher head requirements.

In fact, varying centrifugal compressor operating conditions result in different dynamic behavior which in adverse cases become impossible to accommodate.

To assess existing compressors for the new conditions, a site performance test was conducted. It revealed that the onshore compressors could handle an additional 5% capacity. When added to offshore compressor capacity, this enabled the facility to meet the new requirements by expanding an existing jump-over line that connects the feed stream header.

During the conducted site performance test, the inlet conditions (MW, inlet pressure and temperature) differed from the originally designed inlet parameters in terms of high pressure and low temperature. This change had a positive impact on compressor capacity and developed head. This is mainly attributed to the fact that onshore compressors are operated within different compression stages which allow for better control of any compression stage inlet conditions in case of any compression stage poor performance.

It is evident that differential pressure is not maintained due to increased gas rates. The more pipeline compressors operating, the lower the required differential pressure and the lower the system head pressure required from onshore compressors.

The compressor was operated at five different flow rates but stopped before the choke region as the targeted flow was achieved and to prevent any negative impact on the downstream compressor performance (Figure 3).

Figure 4: Plot of Onshore Compressor Capacity, showing the corrected flow of the onshore compressor based on the corrected flow measurement correction and MW changes.

To estimate the impact of MW changes in the available compressor flow, a correlation was used to calculate the compressor inlet flow rate by accounting for flow measurement corrections based on internal company procedure. Therefore, it is imperative to draw a correlation formula between the flow element design conditions to the actual measured gas conditions. It is known that the compensation or correction of flow measurements are common pitfalls that could be major sources of errors in site tests (Figure 4).

The current onshore compressors at the given average MW of 27 g/mole are capable of exceeding the required new flow demand. The business needs for an additional compressor were substituted by full utilization of existing available compression capacity at adjacent units which also acts in line with company circular economy. It is obvious that the new rated point per each compressor is conservatively 5% more capacity available than the design point. This is based on an average MW of 27 g/mole. Also, the motor has enough horsepower to run at the new capacity required and new molecular weight. As a result, their was no need to add a new compressor with all associated auxiliaries, resulting in significant capital savings.

Hamad K. Al-Ruzihi

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