Create a View-Only Account (which was described in the second part of this discussion emersonexchange365.com/.../3717 ) or just modify Operator to be a view only account - Note, If you are not using a Domain, you will have to create the Windows User Account on all the machines which makes modifying the generic Operator account the better option. Then setup each machine to have a screen saver using the DeltaVScreenSaver, click the Settings, Uncheck the Log Off User and enter the information for the View-Only Account. The users will always have to login after whatever you have defined time of inactivity. - Note, screen saver settings is user specific so it is usually best to always login with the same account on all the systems Instead of using Regedit, you can just put a line of script in UserSettings.grf in the standard directory to login as a default user (View-Only Account) when DeltaV Operate opens. If Workgroup: frsRunTask "c:\deltav\bin\hlo.exe -user USER -password PASS -computer frsVariables.gs_weName.CurrentValue" If Domain system: frsRunTask "c:\deltav\bin\hlo.exe -user USER -password PASS -computer DOMAIN" If using Remote Sessions: frsRunTask "c:\deltav\bin\hlo.exe -user USER -password PASS -computer DOMAIN -session SESSIONNAME" Replace the USER, PASS, DOMAIN, SESSIONNAME with the appropriate values for your system.
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Forum Post: RE: DeltaV Operator Login
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Forum Post: Gaining boiler stability and efficiency through changing load requirements using level measuring technology
Here is an article about managing water levels in your feedwater heater and how it impacts efficiency. www.processingmagazine.com/.../
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Forum Post: Filtering of changes in tuning parameters
It is my understanding that for a PID controller, changes to the tuning parameters are filtered using the Reset time as the time constant for the filter. I am working on using Gain Scheduling and I am seeing some things that don't make sense. Since there are a lot of things happening at one time, I'd like to get a better picture of what is happening to the tuning parameters that the PID module is using. Is there anything comparable to working set point for tuning parameters? That way I could see what parameter values the control module is actually using. It would greatly help sorting out what I'm seeing. Thanks!
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Forum Post: RE: Flow rate
Travis Hi , I wanted to have a clear understanding & your answer is very clear for me ,thank you
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Forum Post: How do you control the levels in your desalter?
Recently customers have been asking about what technologies are used to measure interface levels in a desalter. How a Desalter works: Raw crude oil contains a lot of salt contaminants and water. If the salts are not removed, then they can cause significant corrosion of downstream refinery equipment due to high operating temperatures. To remove the salts, emulsifying chemicals and additional water are mixed with the oil to wash the salts out of the oil. This emulsified oil water mixture then needs to be separated quickly and efficiently. An electrostatic grid causes the dispersed water droplets and salts to coalesce and drop. This electro-static field operates at maximum efficiency when the water and oil interface is maintained at a level just below the electrostatic grid. Guided Wave Radar Solution: Emerson does have experience with using guided wave radar on these applications. The vessel is typically entirely filled with liquid with hydrocarbons on top of the water. The important matter is to keep the water out from the grid area, so you need to keep track of the interface between the oil and the water – and thus the 5300 Guided Wave Radar provides a good solution. For optimum performance, they want to keep the water level as close to the grid as possible – without touching the grid. By adjusting the threshold of the 5300 to sense the emulsion – or by sensing the water layer, it is possible to control the vessel to its maximum performance. As the vessel typically is fully immersed, you can use either a Rosemount 5301 or a 5302. The guided wave radar can be installed in an external chamber or direct Nozzle mount. Emulsion is always a challenge. However, if GWR is installed in a chamber, the emulsion will be less than the vessel. Emerson installations of GWR for Desalter Interface level measurement include IRAQ, Kuwait, Saudi and USA Desalter Interface Measurement with Guided Wave Radar white paper (link) Reliable Desalter Interface Measurement Proven Result (link) Displacer Option: There are also customers that use the Fisher DLC3010 displacers in still pipes, and others that still have the older Fisher pneumatic controllers. Displacers are mechanical devices, so often people think about using a technology with less maintenance, but others choose to continue using the displacer technology especially if it is currently meeting their needs.
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Forum Post: RE: Filtering of changes in tuning parameters
Kent, The change to tuning parameters is not filtered. However, the change in OUTPUT due to a change in the GAIN with a non-zero error, is absorbed in a "temporary bias" so that the output does not change when the GAIN is change (and the error is non-zero). The "internal bias" is then diminished to 0 in a first order shape with the time constant of the RESET. If you are using the Gain Scheduling template, there can be an iterpolation of the tuning constants from one region to next using the DEADBAND that you configured. If you use the Detail Display shown in the PID_GAINSCHED module template, you can see the actual GAIN, RESET and RATE from that are being trasnferred to the PID block from the Gain Scheduler. The PCSD loop detail does not show the interpolated values though you can expose them in the module and see them with Control Studio On-line. What kind of things are you seeing that don't make sense? James
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Forum Post: RE: Filtering of changes in tuning parameters
I have noise in the system (which I am in the process of dealing with), that is causing the error to fluctuate enough that the parameters from the Gain Scheduler to jump around when I have a disturbance big enough to move things out to zone 2 on the schedule. When I get this fluctuation, the system sometimes acts as if there was little or no reset in the tuning. The first order of business is to deal with the noise. Once I have that taken care of, I’ll watch and see if it acts more like I think that it should. Thank you for the help. Kent E Mitchell, P.E. 92-H PRC Bartlesville, OK 74003-6670 918-977-4654 office 918-977-7520 fax Confidential Information - This email is for use by the intended recipient(s) and may contain privileged, confidential or copyrighted information. Unauthorized use, copying or distribution of this e-mail, in whole or in part, is strictly prohibited. If you should not be an intended recipient of this e-mail, please notify the sender by return e-mail and delete this e-mail. No Contract Formation - This e-mail does not constitute a contract or an offer or acceptance of an offer to enter into a contract. Further, this e-mail may not be used to modify, supplement, novate, or waive any rights with respect to an existing contract or other binding commercial terms.
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Forum Post: RE: Filtering of changes in tuning parameters
Kent, Yes, we have seen this impact when the process is noisy and/or the GAIN or RATE is being changed. I have seen this on other system's PID fucntion, not just DeltaV. It is caused by the non-symmetrical response of the changes in tuning. As you say, it has the appearance that the integral is turned off but that is not what is happening. If the noise is fast, you might be able to use a smaller filter time constant if you speed up the module execution (due to signal aliasing of fast noise with a slow sample rate). Another PID parameter setting that can cause this same sympton is improper ARW high and low limits on the PID block. As you probably know, the ARW limits are in EU's of the OUT_SCALE and in all but rare cases, should be set equal to the high and low OUT limits. James
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Forum Post: RE: Filtering of changes in tuning parameters
Thanks. I appreciate the help. Kent E Mitchell, P.E. 92-H PRC Bartlesville, OK 74003-6670 918-977-4654 office 918-977-7520 fax ________________________________
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Forum Post: RE: Filtering of changes in tuning parameters
Hope this helps! Let me know what you find out! James
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Blog Post: Remote and Continuous Tank Floating Roof Monitoring
As oil & gas supplies continue to exceed demand and the need to store crude oil, natural gas liquids and other petroleum-based products increases, storage tanks remain critical elements in the global supply chain. In a Tank Storage magazine article, Stay Afloat Using Radar Technology , Emerson’s Ulf Johannesson describes how radar technology is used to improve safe and reliable operation on storage tanks with floating roofs. He opens the article noting that more: …than half of the world’s larger tanks used for storing common petroleum products have floating roofs, and this proportion is likely to rise due to tightening demands for reduced vapour emissions. Floating roofs have an advantage over fixed-roof tanks in cost and vapor balancing and recovery. They also come with their own set of issues: …such as sinking, tilting, leaking and sticking decks can affect the performance of floating roofs – potentially leading to costly structural damage and major environmental and safety risks. Traditionally, manual inspection of these floating roofs has been the way to try to spot these issues. Not only does this practice put operating personnel in hazardous areas, this inspection can be only performed on a periodic basis, it may also not find the issues in time before an abnormal situation develops. Tank farm operators: …are increasingly favouring a continuous and automated roof monitoring solution that offers greater efficiency and reliability, and keeps personnel out of harm’s way as much as possible. Ulf cites other problems that may occur with floating roof such as excessive water or snow buildup, tilt from strong winds and unbalanced weights, leaking pontoons or a punctured deck, and rim seals that are either too loose or too tight. He describes two automated approaches to continuous floating roof tank monitoring—tank top monitoring and on floating roof monitoring. For tank top monitoring [hyperlinks added]: …typically three non-contacting radars such as Emerson’s Rosemount 5400 series or Rosemount 5900 series are installed, mounted at 120 degrees from each other. A reflector plate on the roof enables accurate measurements to be performed without being affected by any protruding objects on the roof surface. This installation arrangement provides continuous monitoring to detect conditions such as roof tilt, buoyancy, roof sticking and overfill conditions. For measurement devices on the floating roof itself [hyperlinks added]: …wireless and battery-powered guided wave radars (GWR), such as Emerson’s Rosemount 3308 , are installed in existing nozzles, with rigid probes penetrating through the roof and into the liquid below. The wireless devices enable installation without the need for flexible wiring that can cope with the movement of the roof. A wireless repeater mounted at the top of the tanks ensures that when the roof is at a low point the radars can still transmit uninterrupted data back to the control room despite the devices being below the upper edge of the tank shell. The advantage of the second method is [hyperlink added]: …ease of installation, configuration and communication. Installation can be done in just two hours and with the tank still in operation. The configuration of the GWR can be performed remotely via wireless on an easy-to-use configuration screen, and the roof tilt data will be available in the TankMaster software in the control room. Read the article and this flyer with more on radar-based floating roof monitoring . You can also connect and interact with other level measurement and tank gauging experts in the Level and Tank Gauging groups in the Emerson Exchange365 community. Related Posts Detecting Floating Roof Tilt Improving Safe Operations with Wireless Vibrating Fork Level Switches How to Manage Your Storage Tanks Avoiding Dangerous Conditions through Tank Floating Roof Level Monitoring Selecting Best Solids Level Measurement Technology Improving Heat Rate with Better Measurements The post Remote and Continuous Tank Floating Roof Monitoring appeared first on the Emerson Process Experts blog.
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Blog Post: Remote and Continuous Tank Floating Roof Monitoring
As oil & gas supplies continue to exceed demand and the need to store crude oil, natural gas liquids and other petroleum-based products increases, storage tanks remain critical elements in the global supply chain. In a Tank Storage magazine article, Stay Afloat Using Radar Technology , Emerson’s Ulf Johannesson describes how radar technology is used to improve safe and reliable operation on storage tanks with floating roofs. He opens the article noting that more: …than half of the world’s larger tanks used for storing common petroleum products have floating roofs, and this proportion is likely to rise due to tightening demands for reduced vapour emissions. Floating roofs have an advantage over fixed-roof tanks in cost and vapor balancing and recovery. They also come with their own set of issues: …such as sinking, tilting, leaking and sticking decks can affect the performance of floating roofs – potentially leading to costly structural damage and major environmental and safety risks. Traditionally, manual inspection of these floating roofs has been the way to try to spot these issues. Not only does this practice put operating personnel in hazardous areas, this inspection can be only performed on a periodic basis, it may also not find the issues in time before an abnormal situation develops. Tank farm operators: …are increasingly favouring a continuous and automated roof monitoring solution that offers greater efficiency and reliability, and keeps personnel out of harm’s way as much as possible. Ulf cites other problems that may occur with floating roof such as excessive water or snow buildup, tilt from strong winds and unbalanced weights, leaking pontoons or a punctured deck, and rim seals that are either too loose or too tight. He describes two automated approaches to continuous floating roof tank monitoring—tank top monitoring and on floating roof monitoring. For tank top monitoring [hyperlinks added]: …typically three non-contacting radars such as Emerson’s Rosemount 5400 series or Rosemount 5900 series are installed, mounted at 120 degrees from each other. A reflector plate on the roof enables accurate measurements to be performed without being affected by any protruding objects on the roof surface. This installation arrangement provides continuous monitoring to detect conditions such as roof tilt, buoyancy, roof sticking and overfill conditions. For measurement devices on the floating roof itself [hyperlinks added]: …wireless and battery-powered guided wave radars (GWR), such as Emerson’s Rosemount 3308 , are installed in existing nozzles, with rigid probes penetrating through the roof and into the liquid below. The wireless devices enable installation without the need for flexible wiring that can cope with the movement of the roof. A wireless repeater mounted at the top of the tanks ensures that when the roof is at a low point the radars can still transmit uninterrupted data back to the control room despite the devices being below the upper edge of the tank shell. The advantage of the second method is [hyperlink added]: …ease of installation, configuration and communication. Installation can be done in just two hours and with the tank still in operation. The configuration of the GWR can be performed remotely via wireless on an easy-to-use configuration screen, and the roof tilt data will be available in the TankMaster software in the control room. Read the article and this flyer with more on radar-based floating roof monitoring . You can also connect and interact with other level measurement and tank gauging experts in the Level and Tank Gauging groups in the Emerson Exchange365 community. Related Posts Detecting Floating Roof Tilt Improving Safe Operations with Wireless Vibrating Fork Level Switches How to Manage Your Storage Tanks Avoiding Dangerous Conditions through Tank Floating Roof Level Monitoring Selecting Best Solids Level Measurement Technology Improving Heat Rate with Better Measurements The post Remote and Continuous Tank Floating Roof Monitoring appeared first on the Emerson Process Experts blog.
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Forum Post: Continuous Historian on HMIs
We have recently hit the limit of what our continuous historian can monitor on the ProPlus; all 255 variables are being used. I spoke to a technician and was told that it is possible to have the historian available at each of the three HMIs we have on-site. Each HMI historian can monitor another 255 variables without having to pay for another historian license. After talking to the technician, he said it would cost about $1000 to come out and put the historian on the other HMIs (my facility is in rural west Texas), so naturally I turned to looking to solve the problem on my own. Does anyone have any experience they would be willing to share regarding this matter? I apologize if this has been asked before, I was unable to find the answer I was looking for. P.S. Just went out to the HMI and tried to open the Continuous Historian and was given this message: "SQL Server does not exist or access denied. ConnectionOpen (Connect()). Invalid connection string attribute Possible reasons include: the Event Chronicle is not enabled; the Data Server does not exist or can't be reached; the Dataset does not exist; or the workstation has not been assigned to the Event Chronicle license. The attempted Data Server and Dataset were: OWS2 Ejournal" OWS2 is the name of the HMI that I was working on. Anyone have any idea how to enable the Event Chronicle, reach the event chronicle, or assign the workstation to the Event Chronicle license on an HMI that is not the main ProPlus station?
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Forum Post: RE: Continuous Historian on HMIs
Hi Matthew, Each DeltaV Operator Workstation comes standard with a 250-point DeltaV Continuous Historian, so yes, you can do this. The drawback is that data would now be available in multiple places in your system, which may present some challenges depending on what you want to do with it after it is historized. For more information on the DVCH, you can take a look in the Product Datasheet: www2.emersonprocess.com/.../DV_COL_PDS_ContinuousHistorian.pdf and the FAQ document: www2.emersonprocess.com/.../DV_WP_Continuous_FAQ.pdf If you find yourself needing significantly more than 250 tags to be historized, I would suggest putting a larger DeltaV Continuous Historian on a DeltaV Application Station, where you can scale up your historian to as large as 30,000 tags (we have multiple licensing scale-ups available, so you can reasonably get it as small or large as you need it to be). If you decide to go that way, your LBP should be able to help you with selecting the right option based on your needs.
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Forum Post: RE: Continuous Historian on HMIs
Bob, Thank you for the information, the product datasheet was especially helpful. I am wondering if you know the specifics of how to set up the historian on the HMIs?
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Forum Post: RE: Continuous Historian on HMIs
DeltaV History collection is configured at the module level, but assignment to the continuous historian of a workstation is done by Plant Areas. The History collection of the plant Area is the aggregate of all the modules in that Plant Area. The History tags collected by the historian is the sum of the plant areas. To accomplish what you want, you'll have to make sure you segregate the Modules in different Plant Areas that you will then assign to different Continuous Historians on different workstations. You must keep the total number of assigned tags below the 250 limit. For Operator span, you could assign all the Plant Areas to the Alarm and Event container. This allows you define a wider span of control than the Continuous Historian. If you later decide to add a Historian to collect all history in one place, you'll simply be able to assign all these areas and not have to worry about reassigning them. As pointed out Bob, your operators will have to know which console to connect PHV to view certain history data. I've not tried this, but in v12, you can use the embedded Trend, where each can be configured to look at a history tags from a remote Continuous Historian server. A single display could show 50 values or maybe more. So rather than call up PHV and change the history server, call up the display. If you have v11 or earlier, this is not available to you. I would strongly recommend you move to an Application Historian as managing history across operator stations can be time consuming, and Operator's may get frustrated with selecting the right host for desired data.
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Forum Post: RE: Continuous Historian on HMIs
Andre, The operators do not have access to the historian, and our facility is too small (about 4 acres, most of which does not contain equipment) to warrant an Application station as we only have 3 HMIs that are all relatively close to one another. You replied as I was typing an addendum to my original post and I believe my problem could be fixed by figuring out which of the "Possible reasons" is the culprit and solving the issue. If you have any information on how to figure this out I would appreciate it.
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Blog Post: Say goodbye to wasteful strategies for chemical injection
How much does your company spend every year on chemicals? For most, chemical injection is a sunk cost of production – it can be a challenge to track how much is spent versus how much chemical is actually required. Yet without preventive chemicals, scales and waxes could plug tubing and shutting down facilities; hydrates could block production, costing up to $1M/day in shut-in production as it’s dissociated. Without corrosion inhibitors, complete loss of well or infrastructure could occur over time. With such severe consequences, producers consistently inject more than the recommended quantity of chemical. With the new Micro Motion HPC010P Ultra High-Pressure Coriolis Meter you can say goodbye to wasteful strategies for chemical injection. Paired with the TESCOM 56 Series, the new HPC010P Coriolis Meter automatically compensates for changes in inlet pressure, outlet pressure, flow demand, temperature changes and provide accurate chemical flow rate control. Other advantages of using Micro Motion HPC010P Ultra High-Pressure Coriolis Meter with TESCOM 56 Series include: Optimization of chemical usage to prevent problems associated with under-injection and the waste associated with over injection Reduced operational and maintenance costs while increasing safety by extending the service life and being easy to maintain Robust high quality components for longevity, especially in offshore applications, reduce maintenance costs and unplanned downtime Watch this 1-minute video to learn more about our new high pressure Coriolis meter and how it can optimize flow assurance and asset integrity in your upstream operations.
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Blog Post: Level Switch Diagnostics for Remote Proof Testing and Instrument Health
Many of the “things” in the Industrial Internet of Things are the sensors that measure not only operating, but also safety-, reliability- and efficiency-related parameters from a manufacturing and production facility. In a Process Industry Informer article, Enhanced Diagnostics Help To Ensure Reliable Level Monitoring , Emerson’s Marianne Williams shares how technology advancements in vibrating fork level switches help improve operational performance. Marianne highlights the importance of sensors in optimizing reliability practices: …such as increased condition monitoring and analysis-based predictive maintenance activities – drive down operating costs and improve product or batch quality, health and safety, and environmental compliance. Advanced diagnostics in these instruments are important, because if: …potential problems can be diagnosed early, before a failure occurs, then problems can be avoided and maintenance can be scheduled during a planned period of downtime, reducing costs. Level measurement is often a critical measurement for control and safety shutdown applications such as high- and low-level alarming, overfill prevention, and loss of fluid flow to downstream pump. Vibrating fork level switches can be effectively used in these applications. This technology often replaces traditional mechanical and float technologies: …because they require minimal maintenance and are very reliable as well as being compact, light in weight and easy to install. Despite being immersed in a tank or pipe and coming into contact with the liquid within, the shape of the fork ensures that a sticky or viscous liquid doesn’t attach itself to the device and drains away quickly. In addition, vibrating forks have an advantage over other level switch technologies in that they do not have moving parts that can freeze or get stuck, which increases their reliability and makes them virtually maintenance-free. Advanced diagnostics are still very important in spotting performance issues: …such as electrical failure, build-up of material between the forks, corrosion and possible damage to the forks or sensor. Rosemount 2160 Wireless Level Detector The Rosemount 2160 Wireless Level Detector and Rosemount 2140 wired HART vibrating fork level detector use: …HART communications to enable enhanced instrument health monitoring diagnostics that can detect external damage to the forks, internal damage to the sensor, corrosion and over- temperature. A unique frequency analysis function enables any media build-up, fork blockage or excessive corrosion to be detected immediately by a change in the fork sensor frequency over time. This provides operators with an indication that maintenance of the device may soon be needed and gives them the opportunity to schedule it during a period of plant downtime, to minimise process interruption and save money. When used in safety instrumented system applications, the: …remote proof-testing capability now eliminates the need for workers to climb on top of the vessel to extract the switch from the process. This greatly reduces the time required to perform the procedure, increasing process availability, worker safety and efficiency. Read the article for more on these capabilities and applications. The article concludes: Vibrating fork level switches provide plant managers with an effective means of detecting whether liquid is present or not in their tanks and pipes. More companies are turning to automated level measurement solutions, and devices are now capable of delivering more status and diagnostics information than ever before. Latest generation devices – both wired and wireless – provide advanced diagnostics that can flag up potential problems. This enables managers to resolve them during periods of planned downtime, before they can cause equipment damage or a safety incident and have a negative impact on the plant’s productivity. You can connect and interact with other level measurement experts in the Level group in the Emerson Exchange 365 community. Related Posts Diagnostics in Vibrating Fork Level Switches Chamber-based Guided Wave Radar Level Measurement Best Practices Solids Level Measurement Technology Selection Considerations Business Critical Measurement Instrumentation-Second Layer of Automation Cures for Common Tank Gauging Problems Remote and Continuous Tank Floating Roof Monitoring The post Level Switch Diagnostics for Remote Proof Testing and Instrument Health appeared first on the Emerson Process Experts blog.
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Blog Post: Flow Expert Webinar: Limiting Gas Measurement Uncertainty in the Field
Current international gas measurement standards for fiscal flowmeters focus only on the design and installation of the meters and don’t cover meter performance under field conditions. So how do you assure measurement accuracy of fiscal gas flowmeter systems in field conditions? And how much are unknown issues costing your gas measurement operation? Join us for our upcoming webinar on April 4 at 10 am CST and learn how a new risk-based assessment by DNV GL, a global technical advisor and certification body, goes a step beyond traditional metrology testing to determine if the metering technology is robust enough to operate under actual operating conditions. The operational use of a flowmeter in field applications can be distorted by many factors. Dirt buildup, liquids and other contamination within the pipe take greater toll on measurement accuracy than you may realize. Even a minor flow disturbance can increase financial risk and have a major impact on lost and unaccounted for (LAUF) product. Reserve your seat at this webinar to learn the following: How DNV GL is now qualifying gas flowmeters with greater specificity than ever before by putting meter performance claims to the test and verifying how the meters react to several real-life field distortions How daily operating conditions impact meter health and measurement accuracy How to increase measurement reliability and reduce long term measurement uncertainty How to better manage capital investments How to improve compliance and streamline maintenance practices to reduce long term operating costs For more information about the webinar presenters, click here .
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