ENTEGRA’s Post

Corrosion monitoring is crucial for ensuring the integrity and longevity of storage tanks. Corrosion Monitoring Locations (CML) are essential for systematically tracking the condition of tank walls over time. In this guide, we will explore how to create CML points for a tank that lacks predefined CMLs using The Mechanical Integrity Suite. Read the how to: https://lnkd.in/g8PwRP7Q #oilandgas #assetmanagement #bigdata

Industry Insights – Midstream operations are complex systems that span thousands of miles. Distance and complexity make them vulnerable to leaks, dents, and other damage mechanisms. This month, we have three articles discussing damage mechanisms that affect pipelines and amine treating units. ▪ Multi-disciplinary approach to asset management for amine treating units ▪ Level 3 finite element analysis (FEA) of the assessment of dents ▪ Comprehensive discussion of leak monitoring techniques for pipelines Link to the articles is in the comments below.👇 Brian McNeill Shane Kelliher Kevin Haley Daniel Spring Rohan Oak, P.E. Phillip Prueter, P.E.

In our most recent blog post, we dive into how our new Pressure Cycle Fatigue Analysis (PCFA) functionality enhances our ability to calculate failure pressure, analyze crack growth, and determine the remaining life of pipeline materials. This advancement employs a comprehensive suite of models and methodologies, including the Modified Mat-8, ensuring a thorough assessment of crack and crack-like flaws. This update is not just about technical enhancement; it's about aligning with the stringent requirements of the CFR Gas Mega Rule Part 1 and API RP 1176, bolstering your ability to make data-driven decisions and demonstrate compliance with industry standards. Discover how this significant improvement can transform your pipeline integrity management program, facilitating more efficient and informed decision-making processes. Don't miss out on learning more about these critical advancements in our field. Read our latest blog post now! https://hubs.ly/Q02q7M8S0 #OneBridgeSolutions #PipelineIntegrity #CrackManagement #PCFA #PipelineSafety #DataDrivenDecisions #RegulatoryCompliance

RMWS offers an incredible assortment of downhole data acquisition services to help you gather the critical well input you need to make your next crucial decision. 𝗪𝐞 𝐛𝐨𝐚𝐬𝐭 𝐬𝐨𝐦𝐞 𝐨𝐟 𝐭𝐡𝐞 𝐥𝐚𝐭𝐞𝐬𝐭 𝐭𝐞𝐜𝐡𝐧𝐨𝐥𝐨𝐠𝐲 𝐢𝐧 𝐌𝐈𝐓/𝐌𝐓𝐓 𝐰𝐞𝐥𝐥 𝐢𝐧𝐭𝐞𝐠𝐫𝐢𝐭𝐲 𝐥𝐨𝐠𝐠𝐢𝐧𝐠/𝐚𝐧𝐚𝐥𝐲𝐬𝐢𝐬 𝐭𝐨𝐨𝐥𝐬 and RMWS engineers have the knowledge needed to not only acquire the data, but also perform the well integrity data analysis required before final log presentation.⁣ ⁣ 𝗪𝐄 𝐎𝐅𝐅𝐄𝐑 𝐓𝐇𝐄 𝐅𝐎𝐋𝐋𝐎𝗪𝐈𝐍𝐆 𝐂𝐀𝐒𝐄𝐃 𝐇𝐎𝐋𝐄 𝐋𝐎𝐆𝐆𝐈𝐍𝐆 𝐒𝐄𝐑𝐕𝐈𝐂𝐄𝐒:⁣ ✅ Depth Determination⁣ ✅ Gamma Ray⁣ ✅ Noise Logging⁣ ✅ Basket Flowmeter⁣ ✅ Dual Receiver Cement Bond Logs⁣ ✅ Radial Cement Bond Logs⁣ ✅ Multifinger Imaging Logs⁣ ✅ Magnetic Thickness Logs⁣ ✅ Temperature Logs⁣ ✅ Production/reservoir Logs⁣ ✅ Capacitance, Spinner Array Logs & Resistance Array Logs Learn more: https://lnkd.in/gQxi2Dxe

We are offering another session of our first webinar of the year next week: Mechanical Damage is a top two pipeline integrity concern for both liquid and gas pipeline operators, according to the 2023 Kimberlite Report. While mechanical damage is a common enough occurrence, describing dents, gouges, or other metal loss or cold work caused by outside forces, distinguishing gouges from corrosion metal loss is quite uncommon. That’s where ENTEGRA’s True UHR System comes in. In this webinar, we pull back the curtain to explain mechanical damage, share how ENTEGRA’s True UHR System is the one ILI service able to regularly differentiate between gouges and corrosion metal loss in the context of mechanical damage, and showcase two examples of how knowing the difference could either greatly save – or cost – pipeline operators. Mechanical Damage: Gouge vs. Corrosion — Why it Matters WHEN: 1 pm UTC/8 am EST, Feb. 21 REGISTER: https://bit.ly/48sFyhG

Have you seen our Portable Pipe End Measurement System? Here's a closer look. ⚙️🎞️🍿 https://lnkd.in/gD6Tpqn9 From warped ends to uneven wall thickness, pipes aren’t always perfect. But instead of waiting on pipe-end dimensioning service providers, our independent pipe end measurement system (PEMS) lets you take charge of your own project timeline. This cost-effective tool offers major ROI at just 1/10th of the cost of third-party services.  After a quick setup, you’ll be collecting 1,300 laser-point dimensions in just 50 seconds. This lets you verify tolerances as you go and uphold quality standards from the mill to the field. 

Did you know that Big Horn Wireline provides Radioactive Tracer Surveys? Read below to learn more about our process. Big Horn Wireline provides Radioactive Tracer Surveys that satisfy state and federal logging requirements for well integrity on disposal and injection wells. Running Radioactive Tracer Surveys are the preferred method of providing injection profiles, tubing and packer integrity, leak detection, zonal isolation, cross flow, and channeling behind pipe. The tool string consists of an ejector, gamma ray detectors, casing collar locator, and a temperature probe. Temperature surveys are a necessary part of the logging process. Typically, a 24 hour shut-in temperature survey is run from surface to TD. A gamma ray & CCL is run over the perforated zones in the casing and back up into the packer and tubing. This pass records the background gamma rays and provides a way to correlate depths. Next, the process of running tracer surveys are conducted. During the logging process, small amounts of water soluble isotope with a short half-life is ejected into the flow stream, and the gamma ray detects the presence of the isotope. Finally, one-hour and two-hour shut-in temperature surveys are typically run in order to verify fluid storage. After the field data is collected, it is processed, and a detailed interpretation is provided to the client for distribution. Call us for a quote today! 307-337-8950

Have you ever wondered where we get beta numbers, which calculate the Beta ratio for orifices and why we must keep the BETA ratio in orifice calculation between two Values 0.3 and 0.7? Sometimes, client specification specifies a certain Beta ratio range as per company standards and needs to be considered when calculating. For example as per the BP GIS Specification for Field Instruments Calculated Beta ratio (d/D) for orifice plates shall be within the limits of 0,2 and 0,75 in accordance with ISO 5167-2. Where "d" equals pipe ID and D equals the pipe diameter. For example: if the pipe ID is 3 and the pipe diameter is 10, the beta ratio would be 0.3 (3 / 10 = 0.3). Here is a good explanation linked below why the beta ratio is between 0,3 and 0,7. https://lnkd.in/eT8g8E3j

Are you interested in measured crack sizes from destructive examination? Then please join me on September 24th as I share some interesting findings for work performed on a vintage EFW natural gas pipeline that involved hydrotesting, destructive examination, and burst pressure analyses of 26 EMAT ILI anomalies. Actual measured depths and lengths of seam weld flaws will be presented and compared to those reported by the ILI tool and NDE methods, as well as actual hydrotest failure pressures versus burst pressure results using various models. #Pipelines #IPC2024 #DNV

Have you seen our Portable Pipe End Measurement System? Here's a closer look. ⚙️🎞️🍿 https://lnkd.in/gD6Tpqn9 From warped ends to uneven wall thickness, pipes aren’t always perfect. But instead of waiting on pipe-end dimensioning service providers, our independent pipe end measurement system (PEMS) lets you take charge of your own project timeline. This cost-effective tool offers major ROI at just 1/10th of the cost of third-party services.  After a quick setup, you’ll be collecting 1,300 laser-point dimensions in just 50 seconds. This lets you verify tolerances as you go and uphold quality standards from the mill to the field.