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Keep the Process Analyzers On-Stream

Feb. 3, 2012
Despite Computer Operation Simplicity, Personal Skills Are Still Needed to Achieve the Full Benefits of Process Monitoring
About the Authors
Terry McMahon, Steve Walton and Jim Tatera are principals at PAI Partners, Leonia, N.J.
By Terry McMahon, Steve Walton and Jim Tatera

Analytical instruments used for online chemical analysis of process streams or plant environments are generally called process analyzers. On-stream analytical data have proven to be crucial to safe and efficient operation in the petroleum, chemical, pharmaceutical, pulp and paper, power and other industries. Historically speaking, these instruments have been complex, even temperamental, systems with relatively unique operational and maintenance needs. If online instrumentation, sample-handling systems and data-analysis software are to realize optimum performance, they will require continual attention from the analyzer support staff.

Increasingly, however, regulatory and high-priority economic concerns such as operator health and safety, emissions control and energy conservation are raising the importance of analyzer reliability to normal operations. Particularly with respect to regulatory and safety uses, the time logged as out-of-limits because of an analyzer outage can result in stiff fines.

In these situations, it's important to be able to deal with routine maintenance needs, as well as to recognize and characterize maintenance needs that require more specialized skills. Sourcing such specialized skills and an expedited response to an incident frequently become high-priority items.

Looking Back

A brief overview of analyzer history can put the current situation into perspective. The technology for on-stream chemical analysis dates back about 70 years. The first non-dispersive infrared (NDIR) photometers were developed and deployed in the late 1930s at the Ludwigshafen Research Lab of I.G. Farbenindustrie, A schematic of UltraRotAbsorptionSchreiber (URAS), the first on-stream analyzer, is shown in Figure 1. The URAS trade name belongs to the original manufacturer, Hartmann & Braun, which is now a unit of ABB.

The first on-stream analyzer
The first on-stream analyzerFigure 1. This block diagram shows the major components and configuration of the first on-stream analyzer.U.S. chemical and petroleum companies began using on-stream analyzers in the 1950s. By 1960, Standard Oil of New Jersey's (later Exxon) Baton Rouge Refinery had a significant complement of on-stream analyzers (Table 1).

The emergence of real-time digital computers in the 1960s, followed by the microelectronics revolution and the large-scale integration microprocessor in the 1970s, eventually allowed exploitation of highly sophisticated analytical techniques for on-line analysis. During the past 10 years or so, the full power of on-stream chemical analysis, combined with modern information technology, has taken hold throughout the process industries and is generating higher productivities, yields, efficiencies and product quality.

Realizing these benefits required highly skilled and experienced technical personnel. The analyzer community evolved into a culture suited to the care and tending of these useful industrial analyzer tools. The question facing plant operations management is this: How do you realize the enormous potential benefits of on-stream analysis without the overhead of on-site analyzer specialists?


Analyzer Costs and Suppliers (Circa 1960)

In the beginning, the computer was a highly specialized tool surrounded by a cadre of expert practitioners. During the late 1950s, mere mortals never were allowed to approach the computational machines. The high priests, who tended the main console, changed magnetic tape drives and otherwise managed the care and feeding of the electronic monster were the only humans allowed to have access to the air-conditioned inner sanctum. These operators accepted your deck of punched cards, and a day later handed you a printout of your results or, more frequently, a memory-dump to help you with your program fault analysis. What happened between your two visits was known only to the Most High.

Ultimately, Microsoft and Intel turned Everyman into a high priest, but with a big difference. Today's user needs to know very little about hardcore programming. The large software producers already have done it. Save for a very few exceptions, computer specialists rely on preprogrammed software tools that come with the operating system.

A Digital Parallel

Analyzers are now at a somewhat similar juncture. Plant operators need the data analyzers provide, but often can't afford to dedicate a highly skilled individual to provide it.

The big questions are these: Are analyzers ready to cut the cord and fly without a lifeline? What steps should plant operations management take to realize the benefits of analyzer-derived data, while ensuring that the data flow maintains a high level of reliability?

Paul Pulicken is in charge of analyzer technology at BP's Texas City Refinery, as well as working with others in this technology at the company's five U.S. refineries. With 23 years of analyzer experience in a variety of petroleum and chemical processes, Pulicken is well-positioned to offer direction in this field. [Editor's note: Pulicken is now head of process analyzer technology at Bayer Americas.]

The Texas City Refinery, with roughly 1500 analyzers, isn't your typical manufacturing operation. Servicing these instruments with a staff of fewer than 40 people, however, is every maintenance manager's analyzer challenge—in spades.

The No. 1 challenge, Pulicken's experience shows, has been presenting a representative sample to the analyzer. This is a problem, not only in the sample system's fundamental design, but also in its continuing maintenance. Much effort is currently directed at standardizing and rationalizing sample system design and component interfacing, and assuring integrated data flow for sample-system troubleshooting and optimization. Traditionally, this activity has been long on experience and ad hoc decision-making, which leaves operating management vulnerable to key personnel reassignments.

Challenge No. 2 is the shortage of qualified project engineers and managers who have sufficient experience with modern analyzers. This situation often shortchanges the analyzer's value as a provider of key process performance measures.

The third challenge is the lack of analyzer knowledge at the plant operations level. This usually translates to less-than-optimum use of analyzer data, as well as slower response to impending maintenance issues. These three chief challenges don't even include instrument problems.

In Pulicken's view, education and training are the major needs. For instrument training, particularly with a new or advancing technology, he relies on the instrument manufacturer. For more system-level training, particularly with multiple vendors involved, he generally opts for training courses from analyzer systems engineering firms.
According to a PAI 2008 worldwide process analyzer market study, the annual expenditures for instruments, sample systems, installation/commissioning and maintenance) was almost $7 billion. The current economic malaise is likely to defer some, perhaps many, capital projects, and cause substantial reductions in analyzer-related spending, but it's unlikely to seriously reduce the value of the analyzer enterprise. This technology is now an integral part of the safe and efficient operation of much of the world's production capacity.

According to PAI Partners' new worldwide process analyzer market study (PAI/2012), "The Process Analyzer Enterprise," annual expenditures for instruments, sample systems, installation/commissioning and maintenance was $6.6 billion in 2010. The credit crunch of 2008-2009 caused many capital projects to be deferred, resulting in substantive reductions in analyzer-related spending. Analyzer technology, however, is now a deeply embeded component of safe and efficient operation in the petrochemical industry, and is likely to rebound strongly.  

[Editor's note: A version of this article first appeared in Plant Services, April 2009 and has been revised for this issue.]

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