HART Communication proves valuable on a major project, contributes to a successful startup
The 2011 HART Plant of the Year is Shell’s Scotford Upgrader, recognized after programming and commissioning 1,500 devices. Link to prior winners.
Andy Bahniuk, RET, Lead Instrumentation Technologist, Shell Canada
Editor’s note: As Canadian oil production from oil sands has been growing, many energy companies have been building new or adding to existing facilities to help fill demand for product from these sources. In 2011, Shell commissioned a 100,000 bpd (barrel per day) expansion to its existing 155,000 bpd capacity Scotford Upgrader facility near Fort Saskatchewan, Alberta. Shell Scotford is also home to a refinery and chemical plant. Supporting a safe and successful start-up of the upgrader expansion meant the Scotford instrumentation team had to work quickly and efficiently with a minimum of mistakes. The team found that HART technology provided a way to streamline testing and pre-configuration of devices so when they were installed, everything was ready to run for a smooth start-up. At bottom of the article, link to prior winners.
Shell instrumentation technologist Andy Bahniuk worked hands-on through the process. Here is his account of the experience, which has earned the Scotford Upgrader the 2011 HART Plant of the Year Award, presented by the HART Communication Foundation to recognize innovative use of HART technology in real-time industrial process plant applications.
A major challenge
In late 2010, the team at Shell’s Scotford Upgrader Expansion faced a dilemma. How do we safely program and commission over 1,500 HART devices from 26 vendors (including HART Communication Foundation member companies Rosemount, E+H, Fisher, Krohne, K-Tek, Magnetrol, Metso, and Ohmart Vega), in a timely fashion? How do we gain the trust of operations and upper management during loop checks and control narrative testing to guarantee a safe and successful start-up and continued smooth plant operation? How can we continue to provide daily instrument trouble-shooting, and not only preventable but predictable ongoing maintenance?
The answer was easy with the capabilities of HART Communication and a flexible asset management system. All the HART information was readily available in a centralized control room gathered either by a network of MTL multiplexers or our distributed control system (DCS) with HART I/O. A majority of the HART instruments are connected to the SIS (safety instrumented system), or to third-party vendor provided skids. Other, more critical instruments are used for regulatory control with more conventional HART-enabled 4-20 mA control.
The existing Shell Scotford facilities had experienced success using HART technology but were using only some of the capability of the technology. With an interest in leveraging the full intelligence of their HART-enabled devices, the upgrader expansion project team got approval to broaden the application of HART on this project beyond the use of handheld device configuration. This decision made valuable device information available to staff in operations, maintenance and instrumentation.
Measurement and control devices were to be shipped pre-configured, but when the devices arrived not configured, the challenge for the instrumentation and control team became downloading 1,500 instruments with ranges, engineering units, NAMUR values, and transmitter body temperature alarms. They began by creating a database to provide these values in tabular form and establishing a systematic process of 24/7 transmitter downloading, allowing these critical values to be loaded in a timely fashion. This process saved time and enabled us to proceed with the next steps of commissioning: loop function and control narrative testing.
Loop function testing and process variable simulations were done using HART communication and standard HART methods on the devices. All testing was centralized from one location and witnessed by both the operations and engineering teams. In some cases, where a device could not be tested without process present, such as a vortex or ultrasonic flowmeter, testing with device methods provided a perfect substitute. This ensured total confidence for both the operator and engineer that all field devices functioned properly. This procedure confirmed that all critical parameters were loaded successfully and saved 30% of the time normally required. It also eliminated the potential for human error associated with this work.
During control narrative and safety cause-and-effect testing, loop test methods were also used to simulate various process values and to walk through different process scenarios. This testing saved considerable time before the final phase of commissioning and start-up. Some of the critical and complex safety narratives involved more than 15 inputs as well as multiple outputs. Using HART communication and simulating all these inputs from the control room enabled us to test and complete with confidence. The overall time saving was over 50% during this phase.
The value and versatility of HART technology during commissioning and start-up activities proved even more critical while trying to achieve a steady-state process condition. HART communication was used for tuning the smart Fisher DVC positioners for optimal process control and valve response time. It also allowed us to use the DVC6000 methods to fine tune the positioner to match the controller as well as perform valve calibrations in half the time.
Smart valve positioners also provide the ability to read the digital feedback of the valve position value without any additional hardware. With the information we receive from the positioner on the control valve, we are able to pass the digital feedback value using the HART fourth variable (QV) through the FDM gateway. This value is used on graphics to show the actual valve position feedback. This has eliminated the need for any external hardware in addition to the valve positioner, saving approximately $2,000 per valve.
It gets cold up there
During our long, cold Canadian winters the temperature can go as low as -45 °C. To protect the instruments from freezing, our transmitters have been mounted in insulated enclosures with heaters. During these winter months, monitoring the status of this heater is a critical task to ensure safe operation in our facility. With HART technology we have the ability to monitor transmitter temperature variables and pass this parameter through our asset management system to alert maintenance if it starts freezing. We pass the temperature to operator graphics for live monitoring and surveillance. This has helped us improve our efficiency in executing annual preventative maintenance on heater boxes, saving us more than $200,000 per year. Most importantly, it ensures trouble free operation throughout the winter.
Having a central location for device configuration and historian data collection is valuable during the life cycle of a HART device. Simple re-calibration, parameter checks, and device diagnostics can be performed right from the central control room. In the case of device replacement all parameters are stored in a central location and can be readily downloaded to a new device. When considering the expense of permits and gas testing as well as having to carry a handheld device to each individual transmitter, the cost saving is in the magnitude of $100,000 annually.
Safety and reliability
At Shell, safe and reliable operation is a core value. From the beginning, Shell took important steps to ensure the focus on a safe and steady start-up were the priority throughout the process.
During the initial project phase, Shell decided to use the NAMUR settings to prevent spurious trips or unsafe operations caused by faulty transmitters. HART devices compliant with NAMUR standard values provided that infrastructure. Risk of instrument failure tends to be higher during the start-up and by setting our device compliance to NAMUR standard values we could ensure that our start-up went smoothly and without any major instrument issues.
Another challenge was to have a higher SIL rating on some critical furnace gas valves to ensure safety and reliability. The partial stroke test (PST) function supports testing valves without the need to isolate them from the process. With the PST process, the respective valve is moved by approximately 5% to 15% during normal process operation. This testing supports online diagnosis of the actuators and reduces the probability of failure on demand (PFD). Our HART asset management system with Metso positioners using an FDT/DTM driver can execute the PST to provide a sophisticated and quick solution.
All the functionalities, beginning with pre-commissioning to normal operation, were the same for HART and Foundation fieldbus devices. Shell uses both and has taken full advantage of both technologies; the biggest benefit being that we did not have to subject our HART devices to any separate interoperability testing. All our HART devices were plug-and-play, connected through an asset management system. This provided full advantage of EDDL and FDT/DTM technology without any additional testing. We are using the ability to open a virtual window and unlock all the power of HART Communication for any type of measurement device as well as all manufacturers.
Shell uses HART status byte information (sent with each communication request) to represent the device health status on maintenance graphics. HART device status gives important information such as device malfunction, device in simulation, device variable saturated, and most importantly, the device has more status information available. These graphics create an easy visual of the device status at a glance. Monitoring real-time device diagnostics with more status available will direct maintenance to troubleshoot the device in detail and has reduced trouble-shooting time tremendously. Finding “bad actors” has never been easier.
Andy Bahniuk, R.E.T., is a lead instrumentation technologist for Shell Canada at the Scotford Upgrader facility.
About Shell Scotford
Shell Scotford is home to three distinct operating facilities:
- Chemicals—Manufactures 530,000 tpy of styrene monomer and 604 tpy of ethylene glycol
- Refinery—Capacity 100,000 bpd
- Scotford Upgrader—Total capacity 255,000 bpd (including 100,000 bpd expansion, commissioned in 2011)
- Total staff on site is more than 1,300 (plus contractors).
- Refinery—Foxboro DCS
- Upgrader—Honeywell DCS and Field Device Manager
See last year's winner and link to prior year's articles
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