The Monitor

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Don't Let Pipeline Corrosion Get the Best of You - Part 1

Posted by Lance Witt on 9/9/19 8:00 AM

Corrosion is one of the biggest threats to the petroleum industry and preventing it is especially critical in systems susceptible to producing corrosive environments, such as flow lines, transportation pipelines, vessels, water systems, boilers, vacuum towers, cooling systems, amine systems and crude oil systems.

In order to mitigate this devastating occurrence, accurate measurement and monitoring is crucial.

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Topics: Upstream & Midstream, Liquid & Slurry, Gas

5 Critical Steps to Prevent Pipeline Corrosion

Posted by Lance Witt on 8/5/19 8:00 AM

Corrosion monitoring and mitigation is essential for ensuring safe operation and reliable natural gas supplies. In fact, corrosion control practices could save up to $875 billion annually. And this doesn’t include the additional safety, operational and environmental benefits that come from corrosion-free equipment.

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Topics: Upstream & Midstream, Liquid & Slurry, Gas

What You Need to Know About Sampling Oil Sands

Posted by Israel Gamboa on 6/5/19 8:17 AM

Every day, the world uses about 93 million barrels of crude oil, a demand that rose by 1.3% in 2018 and is soon expected to reach 99 barrels per day or more.

Oil sands mining is one method that oil producers are using to meet this demand. Although oil sands mining represents just a small percentage of crude oil production, it’s predicted that it will produce 3.7 million barrels per day by 2021. As this production increases, so will the need for accurate and efficient sampling processes.

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Topics: Mining, Upstream & Midstream, Solids & Powder, Liquid & Slurry

Manual vs. Automatic: Which Sampling is Best for Your Hydrocarbon Plant?

Posted by Rod Lunceford on 5/20/19 8:00 AM

The United States is expected to produce more than 12 million barrels of oil per day by the end of 2019. With Russia pumping approximately 11 million barrels per day, this milestone could turn America into the world's largest crude producer.

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Topics: Hydrocarbon Processing, Upstream & Midstream, Solids & Powder, Liquid & Slurry

Cool it Down with Sample Coolers

Posted by Kevin Kirst on 3/25/19 8:00 AM

Plants and facilities of all kinds use sample coolers to cool a sample from a process stream. Cooling samples as part of your steam and water sampling system is essential to maintaining safety and the representativeness of the sample.

For example, if a sample in a power plant is too hot to handle, the operator might throttle the flow to unacceptably low levels, which means the sample is no longer representative or acceptable.

Another example comes from Hydrocarbon processing or Process Analytics. Cooling the process to handle the sample is necessary.   If you take a grab sample of a certain hydrocarbon whether it be of a liquid or a gas, the safest way is to handle the sample at below 140F.  This protects the operator when handling hot samples that need to be physically taken to the lab safely for analysis.   

In order to achieve accurate data, the Electric Power Research Institute (EPRI), ASTM and ASME recommend cooling water samples to 77°F (25°C) to ensure consistent, accurate test results. 

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Topics: Power, Hydrocarbon Processing, Upstream & Midstream, Liquid & Slurry, Steam & Water

Why Small Things Like Sample Bottle Caps Are Big Things In A Hydrocarbon Processing Plant

Posted by Derek Lindsay on 10/9/18 9:27 AM

 

Sampling in a hydrocarbon processing plant has its hazards. Tapping into a process line to extract a representative sample requires careful planning, specialized equipment and a partnership with the right sampling application experts. Commonly, however, more focus is spent on the best and safest way to extract the sample, than the method to seal the sample collection bottle. That can be just as hazardous.

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Topics: Hydrocarbon Processing, Upstream & Midstream, Liquid & Slurry

Five Things to Know When Sampling in a Hydrocarbon Processing Plant

Posted by Sentry Equipment on 8/1/18 8:35 AM

Sampling within the hydrocarbon process is essential for gaining visibility into product quality, identifying corrosion and ensuring processes are operating as expected. It occurs at multiple points across virtually every stage of hydrocarbon processing. However, are you giving sampling the attention it needs?

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Topics: Hydrocarbon Processing, Upstream & Midstream

Process Monitoring Tech Center: World-Class Expertise Right Where You Need It

Posted by Sentry Equipment on 7/19/17 2:30 PM

As Texas ramps up crude oil production and a “resilient” oil and gas industry is expected to see slow but steady growth in 2017 and beyond, it’s more critical than ever that these refining and petrochemical plants have the technologies and expertise they need to meet demand.

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Topics: Hydrocarbon Processing, Upstream & Midstream, Company News

What to Know About Drip Pots and Corrosion Monitoring

Posted by Kevin Kirst on 3/22/17 10:30 AM

Internal metal corrosion in hazardous liquid, gas transmission and gas-gathering applications is inevitable and continues to cause leaks and catastrophic failures. Due to the fact that internal corrosion is time dependent, the number of incidents could be increasing due to aging pipeline infrastructure. Such disasters can damage the environment and cause costly downtime and waste in pipeline productivity – in addition to astronomical cleanup costs.

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Topics: Hydrocarbon Processing, Upstream & Midstream

How to Effectively Sample Gas Without Surface Interactions

Posted by Marty Higgins on 2/8/17 11:00 AM

The chemical compatibility of materials used to construct analytical systems for sampling, transfer, and analysis of oil and gas must be carefully considered to maximize reliability. Specifically, virtually all natural gas samples contain sulfur compounds which need to be precisely quantified for quality purposes. In most applications, sulfur compounds like hydrogen sulfide (H2S) must be quantified at the parts-per-million (ppm) and sometimes even parts-per-billion (ppb) level.

However, the stainless steel components that typically make up a gas sampler are prone to absorbing sulfur compounds onto the surface. Though this problem may seem negligible in gas samples with a high percentage of sulfur concentrations, it is impossible to accurately quantify sulfur and other active compounds at trace levels without first treating the stainless steel flow path.

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Topics: Upstream & Midstream, Gas