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Measure & Analyze: Live Q &A, March 1st from 10am - 10:45am CST

 Welcome! Emerson experts below will be here LIVE on March 1st, 10:00am - 10:45am CST to help you tackle your toughest challenges...

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Best Regards,

Rachelle McWright: Business Development Manager, Dynamic Simulation: U.S. Gulf Coast

• Pressure
• Liquid Analysis
• Wireless
• Level
• Experts
• Temperature
• Flow
• flame & gas detection
• Corrosion
• Measure & Analyze
• Tank Guaging
• Analytical

Rachelle McWright

• 20 Feb 2017 2:14 PM
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51 Replies

• Lydia Miller

  

  • 1 Mar 2017 3:06 PM

  Hi Rachelle! I am here to help answer level questions.

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• Ingemar Serneby

  

  • 1 Mar 2017 3:06 PM

  In reply to Rachelle McWright:

  Hello! Ingemar here, ready to assist you with your question!

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• Jim Cahill

  

  • 1 Mar 2017 3:06 PM

  In reply to Natalie Strehlke:

  From someone in the oil & gas industry, "How can I install tank gauging on a tank with just one still-pipe? I need to use that only pipe also for sampling and manual verification."

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• Aaron Napier

  

  • 1 Mar 2017 3:09 PM

  I'm curious how people are handling the new proving requirements for oil allocation meters. (API 20.2) Specifically, how are people proving existing oil meters in the field? Meter Swap Out, adding proving connections, etc?

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• Ulf Johannesson

  

  • 1 Mar 2017 3:14 PM

  In reply to Jim Cahill:

  Hello Jim, that's a common issue, especially on older tanks. The Rosemount 5900S radar gauge for still-pipe has a special version called "array antenna with hinghed hatch" installation. This means that the gauge is installed on top of the pipe available, but when the pipe is needed for sampling or manual measurement that gauge can easily we turned away from the pipe top. When sampling is done the gauge is turned back to the normal position again. No special tools needed, no need to power off the radar and no need to do a restart.

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• Jim Cahill

  

  • 1 Mar 2017 3:14 PM

  In reply to Jim Cahill:

  Here is one I've heard asked more than once... I tend to get a lot of process noise in my pressure measurement. Is there any way I can smooth this out a bit?

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• Danny Vandeput

  

  • 1 Mar 2017 3:15 PM

  In reply to Aaron Napier:

  Hello! Danny Wireless here to help you with your Wireless(HART) questions!

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• Shane Hale

  

  • 1 Mar 2017 3:15 PM

  In reply to Ramesh Nair:

  Hi Ramesh,
  This is a very big question. CEMS standards tend to be country based as it is linked to the Environmental regulations of the Government. In the European Union the applicable regulations is EN14181 and either MCERTS or TUV are common. These certifications are for the entire system (from the probe to the analyzer). In the US, the EPA regulations are used and rely on RATA testing of the system onsite to certify and depend on the application (coal power, gas turbine, refinery, etc). Often we are asked for certification on our analyzer for EPA or European standards, but there actually isn't certification for individual analyzers.
  For Gas Chromatography, there are several standards that are used in the Gas Custody transfer application. In the US, the GPA 2261-00 analysis for Natural Gas and Similar Gaseous Mixtures by Gas Chromatography is used. In Europe, ISO 6974: Natural Gas - Determination of Composition with Defined Uncertainty by Gas Chromatography is used. There is a performance test, ISO 10723 Performance Evaluation for On-Line Analytical Systems, that is also used in Europe that involves testing the GC with 7 different gas mixtures.
  As for non-custody transfer applications or CEMS, there are not really any standards that are specific to analyzers.
  I will try to get a list together for you in the coming days. I hope this helps.
  Shane

  Shane Hale | Global Business Development Director - Rosemount Wireless | Emerson Automation Solutions

  shane.hale@emerson.com | T +1 952 204 4737 | M +1 713 447 2839

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• Karl Stappert

  

  • 1 Mar 2017 3:19 PM

  In reply to Aaron Napier:

  In‐situ proving of a meter with the actual process fluid is a best practice, but this can be difficult if fluids are not stabilized or dump cycle on the separator is very short. In many cases the meters are swapped out and proved at a central processing facility or calibration lab with a fluid similar to the production crude in the field.

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• Rachelle McWright

  

  • 1 Mar 2017 3:20 PM

  Here's a question from LinkedIn: What type of level measurement is good for saturated steam applications with high vapor pressure?

  Best Regards,

  Rachelle McWright: Business Development Manager, Dynamic Simulation: U.S. Gulf Coast

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• Ingemar Serneby

  

  • 1 Mar 2017 3:23 PM

  In reply to Rachelle McWright:

  For saturated steam applications I would recommend you to use a Rosemount 5301 with Dynamic Vapor Compensation probe. The probe is desinged with a reference in the vapor space that automatically correct for the changing dielectric property of the vapor, bringing the measurment error down to a minimum.

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• Jim Cahill

  

  • 1 Mar 2017 3:23 PM

  In reply to Shane Hale:

  With WirelessHART plant networks, could there potentially be interference with other communications networks or other sources of EMF?

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• Wally Baker

  

  • 1 Mar 2017 3:24 PM

  In reply to Jim Cahill:

  Often when measuring pressure in the field, you see the process noise.  Some pressure transmitters can measure faster than 20 times per second so you see the noise.  One way to help smooth out a bit is to add a little damping which will average out the pressure samples.    Also in addition some pressure devices you can actually use this noise to your advantage.  It can be an indication that something else is going on in the process.  For example this could be an indicator of cavitation.  Or if the noise drops, this can indicate potential plugging.  Some devices have advanced diagnostics that can detect this and issue an alert from the device so you can take action on this unexpected change. 

  http://www.emerson.com/en-us/automation/measurement-instrumentation/pressure-measurement/pressure-transmitters-and-transducers/about-rosemount-3051s-series-of-instrumentation 

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• Aaron Napier

  

  • 1 Mar 2017 3:27 PM

  In reply to Karl Stappert:

  Any general guidelines that you've seen people use for proving frequency? (i.e. throughput based, semi-annual, annual, etc)

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• Rachelle McWright

  

  • 1 Mar 2017 3:27 PM

  What is a Van Stone thermowell and what are the advantages?

  Best Regards,

  Rachelle McWright: Business Development Manager, Dynamic Simulation: U.S. Gulf Coast

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