OGC Energy’s Post

Measurement of partial pressure: Just had a thought while scrolling the HMB sheet where we see mostly all Mol % of different streams such as Co2, H2S, main fluids, O2, etc... Tried to interpret how to calculate the partial pressure from this mol% which is very useful to predict the pH values of streams. pH and partial pressure have a strange relationship: Inverse proportional to each other. Here the attachment gives a thought of mine how usually partial pressure can be measure for Carbon dioxide (one of the dangerous) can't ignore in the upstream or downstream process. #shell #AMPP #refinery #refineryoperations #assetintegrity #oilandgas #assetintegritymanagement #inspection #riskengineer #api571 #materialselection #assetprotection #riskmitigation #assetreliability #assetcare #corrosion #assetmanagement #inspectionmanagement #ndt #reliabilityengineer #safety #corrosionawarness #integrity #prevention #assetcare

Offshore Oil and Gas pipelines experience severe corrosion both externally (due to seawater) and internally (due to flow of corrosive hydrocarbons) reducing their operational life significantly. Cladding of steel pipes is the solution. Our review article presented at IEEE conference provides a comprehensive overview of clad pipe fabrication methods employed by the industry with a focus on selection of clad process, productivity and integrity. https://lnkd.in/df_betqz

✅ Understanding the Nelson Curve: A Key Concept related to Steels for Hydrogen Service at Elevated Temperatures and Pressures in Petroleum Refineries and Petrochemical Plants. The Nelson Curve, as outlined in API 941, is an essential tool for predicting and managing high-temperature hydrogen attack (HTHA) in pressure vessels and piping. Developed by Dr. Nelson, it provides a graphical relationship between operating temperature, hydrogen partial pressure, and susceptibility to HTHA. 💡Purpose of the Nelson Curve: The primary objective of the Nelson Curve is to help engineers determine safe operating conditions that minimize the risk of HTHA. It allows users to assess whether a material (typically carbon or low-alloy steel) will be vulnerable to HTHA at specific temperatures and pressures over time. 💡How to Use the Nelson Curve: 1. Identify the Operating Conditions: Determine the operating temperature and hydrogen partial pressure for your equipment. 2. Select Material of Construction: The Nelson Curve provides different boundaries for materials (carbon steel, Cr-Mo steels). 3. Plot the Conditions: Plot the temperature and pressure on the curve to assess risk. If the operating point lies above the curve for a specific material, the equipment is likely to be susceptible to HTHA and may require additional precautions like material upgrades or cladding. Using the Nelson Curve effectively helps ensure long-term equipment reliability and safety in hydrogen service environments. It is a critical aspect of pressure vessel design and maintenance in industries such as refining and petrochemicals. #HTHA #NelsonCurve #API941 #PressureVessels #DamageMechanism #Refining #Petrochemicals #EngineeringInsights Reference: API 941

Sizing a Gravity Flow Line

Predictive failure assessment during design stage is a powerful tool to avoid brittle fracture. ➡️ the next question is how to implement it? Not only defining MPT curves to ensure a safe & optimized startup/ shutdown but also considering the effect of a potential crack. Don’t miss this post!

🔧 Challenges in the Oil & Gas Industry: Corrosion in Harsh Environments ⛽️ The oil and gas sector constantly faces tough conditions where corrosive substances threaten equipment and operational integrity. One essential tool to combat this? The Galvanic Series—a powerful ranking system for metals based on their likelihood to corrode when in contact. Understanding the Galvanic Series helps make informed material choices, preventing costly leaks, spills, and environmental hazards 🌍. We’ll explore key insights, such as the compatibility between stainless steel and carbon steel, and how to effectively use these materials together to avoid galvanic corrosion. 🔍 Plus, stay tuned as we delve into future advancements in corrosion prevention technologies that are shaping the industry! 🚀 Like, share, and follow for more valuable insights! Why you register? To understand the knowledge of corrosion science on a deeper level that not only protect the asset in your organization but it will enhance your career growth that cannot be achieve without expertise in subject areas. Join our growing community to get certified for AMPP senior corrosion technologist Certification. Register for guidance, study materials and Question bank https://lnkd.in/dFGKznvu Join our community for updates https://lnkd.in/dQ2YVN2r follow us on Facebook https://lnkd.in/dtKPH24Q #OilAndGas #CorrosionProtection #GalvanicSeries #MaterialScience #IndustrialSafety #EngineeringInnovation #Sustainability #EnvironmentalSafety

𝐍𝐚𝐭𝐮𝐫𝐚𝐥 𝐆𝐚𝐬 𝐚𝐧𝐝 𝐂𝐨𝐫𝐫𝐨𝐬𝐢𝐨𝐧 Unlike oil wells, which may produce noncorrosive fluids for many years before corrosion becomes a problem, natural gas wells are corrosive from the beginning. This is due to the fact that all natural gases will have at least some associated water, and this water, unlike the brines associated with oil wells, is usually very pure. This pure water has no natural buffering agents, and it becomes acidic due to the presence of dissolved gases, CO2 and/or H2S. Most of the discussion on CO2 corrosion is associated with natural gas condensate in gas wells or pipelines. Table 3.3 shows typical compositions for natural gas wells and for natural gas from wells that also produce oil. Natural gas deposits also produce small amounts of mercury. Offshore gas processing systems remove the mercury before the gas enters aluminum heat exchangers used to cool the gas before sending it to shore. This is less of a problem onshore, because aluminum heat exchangers, used offshore for weight savings, are not common in onshore gas processing plants. Elemental sulfur can be present in natural gas. It can precipitate onto metal surfaces. It can also form if H2S comes into contact with oxygen, which can happen in topside piping and equipment. This sulfur is corrosive to both carbon steel and CRAs. Natural gas contains more than methane, and pipelines frequently develop corrosion problems when the small amounts of water, CO2 and/or H2S, and other acid‐forming compounds collect on the pipeline walls as temperature and pressure conditions change the farther from the compressor the pipeline progresses. Most of the discussion on CO2 corrosion is associated with natural gas condensate in gas wells or pipelines. REF.: METALLURGY AND CORROSION CONTROL IN OIL AND GAS PRODUCTION - ROBERT HEIDERSBACH Abdulkader Alshereef 🇵🇸 #Corrosion #Quality #NaturalGas #CorrosionControl #Projects #Offshore #Integrity #Piping #Steel

We have supplied Externally Pressurized Expansion Joint for Continuous Catalyst Regeneration (CCR) application of FCCU refinery. Continuous Catalyst Regeneration (CCR) is part of the catalytic reforming process in a refinery where hydrogen and naphtha feed are reacted to create desired end products. The catalyst used in the reaction is continuously flowing through the reactors and then regenerated. The Expansion Joints parameters are as follows: - Application: NHT - CCR - Reactor - Type: Externally Pressurized Expansion Joint - Flowing Media: Catalyst - Design Pressure: 9.6 kg/cm^2 (g) - Design Temperature: 540°C - Test Pressure: 48 kg/cm^2 (g) Material of Construction: - Bellows: ASME SB 443 UNS N06625 Gr. 1 For any inquiries, please contact us at sales@ratnaflex.com #ExpansionJoints #FCCBellows #FCC #FCCU #Bellows #MetallicBellows #RATNAFLEX #Engineering #Refinery #HeatExchangers #Compensators #Oil&Gas #Petrochemicals #SteelPlants #PowerPlant #AmmoniumNitrate #Chemical #Fertiliser #Fertilizer #Cryogenic #StorageTanks #Vessels #Reactors #Regenerators #EPC #PMC #Contractors #Projects

* Sulfur Presentation Spotlight at RefComm Galveston* SRU Thermal Reactor Refractory Workshop – Optimizing Reliability  Presented by Andy Piper and Heeth Orr of Thorpe Specialty Services Corporation ▶ Register: www.refcomm.com   The thermal reactor is not the premier operating unit in a refinery and is unlike any other unit in a refinery.  However, problems in the sulfur plant are expensive to repair and can result in reduced throughput to the entire refinery.  It is also the most complex and severe service piece of fired equipment in a refinery in both operating conditions and in refractory lining details.  This 80-minute workshop will focus on the Modified Claus process thermal reactor in refinery use discussing the multiple aspects that can and do affect refractory performance.   Some aspects we will discuss are outside a refractory designer’s control but can significantly impact the ability of any refractory system to perform reliably, especially a subpar designed/installed lining system.  The course will discuss these factors and will provide highlights of the newly published API 565 Standard for Thermal Reactors.  After a short Refractory 101 introduction, we will discuss some of the engineering features required to properly design a new refractory lining or to troubleshoot an existing problem unit.   To provide special focus to real life operating problems, we encourage owner operators to come prepared with questions, or even a flash drive with overviews of the problem, that can be discussed during the workshop.  As a reminder, no notes or records are kept of these discussions. ▶ Who Should Attend:  New and experienced refinery staff personnel including operators, maintenance staff, reliability engineers, inspectors, management, etc. who want to learn more about refractory in thermal reactors and are looking to add a new thermal reactor or to optimize their existing unit’s refractory reliability and/or decrease long term maintenance needs of their lining. ▶ What will you learn:  • How the Claus process operating conditions alone can destroy refractory materials.  • How mechanical design/configurations can impact refractory performance.  • How burner performance affects refractory performance.  • Most existing refractory linings are not optimally designed.  • A high-level introduction to the API 565 Standard; the first industry consensus standard for Thermal Reactors  • An introduction to some of the refractory engineering considerations required to optimize the refractory lining “system.”  • Addressing high temperature and low temperature corrosion under today’s operating conditions.  #refcomm #oil #oilandgas #sulfur #sulfurrecovery #safety #training Sulfur Unit