Oil and Gas News

How oil & gas pipeline reached 99.5% reliability

By modernising its operational environment with an information-enabled, virtualised system, a gas transmission company improved reliability and reduced maintenance costs by $2.3 million.

Changes to the oil and gas industry in the United States have put pressure on transmission companies to optimise their systems, add flexibility and respond more quickly to a fluctuating industry landscape. While many companies have been struggling to change, others have been more forward-thinking in applying new technologies.

One of those firms is Columbia Pipeline Group (CPG), which recently modernised its operational environment by implementing a Modern distributed control system (DCS) to improve reliability, gain better insight into its production data, and ease maintenance. The company saved about $2.3 million in reduced maintenance costs in one year, showing that gas transmission companies can reach over 99 per cent reliability while running at 100 per cent capacity.

Increasing Capacity Challenges
CPG runs nearly 15,000 miles of natural gas pipelines from the Gulf Coast to the Northeast, serving customers in 16 states. Before 2009, the transmission company left 20 per cent capacity available in case of horsepower unit failures.

When the company increased production to 100 per cent capacity in 2009, it needed to gain reliability to help make sure production wouldn’t come to a stop and negatively impact contractual obligations. The company had to either add more pipelines or increase the horsepower redundancy at its compressor stations.

The company also needed to gain better insight into production data and manage the long-term costs to more effectively maintain the system. The existing disparate and homegrown control systems had been increasingly difficult and costly to maintain. CPG used an in-house SCADA system that only one person knew how to support. Replacement parts were becoming difficult to find. Existing suppliers didn’t have good training programs for new maintenance staff, and current employees were retiring — taking their system expertise with them.

In addition, the existing systems didn’t provide the information management needed to proactively optimise operations or easily integrate with the corporate-level data warehouse. The lack of a secure user access and authentication system also put information security at risk.

Standardised System
The existing system wasn’t sustainable and the cost for adding additional pipeline was prohibitive. CPG management evaluated the company’s long-term needs and developed a five-year plan to modernise the control system across its pipelines.

The team decided to standardise on one system to improve reliability through added redundancy, share information between stations and executive offices, and simplify long-term maintenance. CPG set a goal of reaching 100 per cent reliability — at 100 per cent capacity — by the end of the five years.

After a thorough review of options, the CPG engineering team decided to standardise on a virtualised PlantPAx® process control system from Rockwell Automation. The modern distribution control system (DCS) would share more information across facilities and the executive level, allow remote access and improve security.

“We were planning to modernise our entire control system across 16 states and didn’t want to be managing multiple points of contact at the same time,” notes Brian Sloan, automation and electrical engineering manager for Columbia Pipeline Group. “Working directly with one contact at Rockwell Automation throughout the entire process has made a complex project easier to tackle.”

The CPG team installed redundant horsepower at strategic points across the footprint to meet the required pressure for reliable transmission. Programmable automation controllers (PACs) control engine functions. Operators manage individual engine operation via redundant human-machine interfaces (HMIs), and all engine PACs connect to the main compressor station control panel.

Allen-Bradley® technology is used throughout. CENTERLINE® motor control centres (MCCs) with IntelliCENTER® technology support the auxiliary functions of the compressor station and engine units. The networked MCCs easily integrate with controllers in the existing system. Motor control components within the MCCs include PowerFlex® AC drives, SMC™ Flex soft starters, PowerMonitor™ 5000 energy monitors, and E3 Plus™ electronic overload relays.

When designing the process control system, the CPG team realised each station would require more servers than physically possible to handle all applications needed for security, data analytics and system management. The team decided to implement virtualised servers using the PlantPAx selection guide and best practices for adopting a virtualised automation system.

The Rockwell Automation team deployed high-availability, virtualised servers from Rockwell Automation Encompass™ Product Partner, Stratus Technologies. The Stratus servers reduced the physical hardware space, the need to procure hardware for each new application, and the likelihood of downtime because of hardware errors.

Each virtualised server runs multiple Rockwell Software® FactoryTalk® applications including Historian, View Machine Edition, View Site Edition, AssetCentre and ViewPoint software.

ViewPoint software allows CPG operators to access the HMI applications from any location through a Web browser, allowing them to make real-time decisions about any issues that arise.
Combined with historian software, the system’s visualisation capabilities help monitor, report and record data for immediate and future access. In addition, the historian platform tightly integrates with the corporate-level OSIsoft PI data warehouse system from Encompass™ Partner OSIsoft, LLC — further increasing operation data visibility and availability.

The information-enabled system runs on EtherNet/IP™, allowing data to flow easily from engines to the main control panel, the MCCs to the PACs, one compressor station to another, and stations up to executive offices. Allen-Bradley Stratix™ industrial Ethernet switches manage the secure, real-time information sharing.

AssetCentre software helps manage changes and control user access in the field. The CPG team set authentication parameters within the software to manage the rights and capabilities each user is granted when using other FactoryTalk applications. AssetCentre also tracks and records user actions for increased security and future reference.

Because the system is information-enabled, CPG can develop reports on station operations to improve predictive maintenance. When replacement parts are needed, the engineering team can easily purchase them off-the-shelf from local suppliers.

System Reliability
By early 2015, CPG reached 99.5 per cent reliability. Working with one point of contact at Rockwell Automation, they implemented the virtualised control system to 40 compressor stations and plan to roll out the redundancy upgrades to 52 more stations.

The team can use the same system to design any new compressor stations, and expects the enterprise-wide system to run for at least 10 years before additional upgrades are needed.

With the system’s added redundancy, the company can meet contractual obligations and improve beyond that, making business changes based on specific data.

“We’re making more educated decisions based on real-time and historical operations data that we can access anywhere, including from our headquarters,” Sloan said. “We’ve been able to significantly improve company profitability as a result.”

Based on new insights into engine operations, the CPG engineering team conducts more active and ongoing preventive maintenance — and it’s yielding results quickly. The company saved about $2.3 million from reduced maintenance costs and downtime in 2014.

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