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The construction sector is one of the most dynamic areas, with risks and threats constantly changing. It is like juggling ever-changing factors, where one small mistake can have serious consequences. One frequent source of accidents at work is the faulty technical condition of the tools and construction machinery used. And this is where prevention comes in. On nuclear power plant construction projects, such as the DABAA Egypt project or the BARAKAH project in the United Arab Emirates, we used a simple but effective system: 'COLOR CODING'. This system visualises the professional control performed and the safe equipment when applied effectively. How does it work? After inspection, if in satisfactory condition, each machine, equipment, or tool will receive a colour marking (e.g. January – March 🔷 Blue, April - June 🔶 Orange, etc.) as a visual sign that the inspection has been carried out and the equipment is compliant. The validity of this marking can be one month in some cases, but it is usually three months. I would like to inform you that the inspection and its scope are conducted following a pre-prepared control checklist and always by a professional inspector in this field. Simultaneously, it is an inspection carried out beyond the scope of legislative requirements. Correctly using this simple tool benefits all workers, safety technicians, and construction supervisors. It provides an immediate overview that the device has been professionally inspected. What remains during this validity period is only a daily routine visual inspection before use that can reveal any external mechanical damage. Could you consider implementing a similar system to ensure the safety of your construction projects? Simple visual alerts can genuinely save lives. Together, we can create safer workplaces for everyone. I am grateful to my colleagues from #DabbaNuclearProject and #HassanAllam for the illustrative pictures I used for this article.

Pipeline Integrity Pipelines are essential for the transportation of oil, gas, and other liquid and gaseous substances over long distances. They are the backbone of the energy industry and play a vital role in meeting the world’s growing energy needs. However, pipelines are subject to various threats that can compromise their integrity and lead to catastrophic consequences. Pipeline integrity management is a crucial process that ensures the safe and reliable operation of pipelines. It involves a comprehensive approach to identifying, assessing, and managing risks associated with pipeline operations. The pipeline integrity management process includes various activities such as risk assessment, inspection, maintenance, repair, and monitoring.  The importance of pipeline integrity management has been highlighted by high-profile pipeline accidents. Just like: Sissonville pipeline explosion, the explosion occurred Sissonville in a 20-inch transmission line owned by Columbia Gas. According to Columbia Gas Transmission Corporation, the maximum allowable operating pressure of the pipeline was 69 bar, gauge, and the operating pressure at the time of the rupture was about 64 bar, gauge. Columbia Gas Transmission Corporation records, the 20-inch-diameter pipeline segment had a nominal wall thickness of 7,2 mm and a longitudinal electric resistance weld seam. Corrosion protection was provided by a factory-applied polymer coating and impressed current cathodic protection. The ruptured pipe was oriented with the longitudinal seam weld near the top of the pipe. The fracture was located in the base metal at the bottom of the pipe along the longitudinal direction. The outside pipe surface was heavily corroded near the midpoint of the rupture and along the longitudinal fracture. The corroded area was about 1.8 mt in the longitudinal direction and 60 cm wide in the circumferential direction. The smallest measured wall thickness was 1,98 mm (more than 70 percent wall loss). Probable Cause The National Transportation Safety Board determines that the probable cause of the pipeline rupture was  1- External corrosion of the pipe wall due to deteriorated coating and ineffective cathodic protection 2- The failure to detect the corrosion because the pipeline was not inspected or tested after 1988. Contributing to the poor condition of the corrosion protection systems was the rocky backfill used around the buried pipe.  Contributing to the delay in the controller’s recognition of the rupture was Columbia Gas Transmission Corporation management’s inadequate configuration of the alerts in the supervisory control and data acquisition system. Contributing to the delay in isolating the rupture was the lack of automatic shutoff or remote control valves. #pipeline #integrity #safety #process #corrosion #montiroing #test #inspection #emergency #piping #maintenance #fire #firesafety #engineering #gas #LPG #LNG #naturalgas #hazards #mechanical

𝗣𝗿𝗲𝘀𝘀𝘂𝗿𝗲 𝗦𝗮𝗳𝗲𝘁𝘆 𝗩𝗮𝗹𝘃𝗲𝘀 (𝗣𝗦𝗩𝘀) 𝗣𝗿𝗲𝘀𝘀𝘂𝗿𝗲 𝗥𝗲𝗹𝗶𝗲𝗳 𝗩𝗮𝗹𝘃𝗲𝘀 (𝗣𝗥𝗩𝘀) Pressure Safety Valves (PSVs) and Pressure Relief Valves (PRVs) are critical safety devices in the oil and gas industry, designed to protect equipment, pipelines, and personnel from overpressure conditions. While their functions are similar, there are key differences in their application and operation: 𝗣𝗿𝗲𝘀𝘀𝘂𝗿𝗲 𝗦𝗮𝗳𝗲𝘁𝘆 𝗩𝗮𝗹𝘃𝗲 (𝗣𝗦𝗩) Application: Used in systems where sudden overpressure could lead to catastrophic failures. Commonly installed on vessels, reactors, and high-pressure storage tanks. Often applied in compressible fluid systems like gas and steam. Opens rapidly (pop action) when the set pressure is exceeded. Typically used for emergency situations where immediate pressure relief is needed. Designed to protect equipment by venting to the atmosphere or a flare system. 𝗣𝗿𝗲𝘀𝘀𝘂𝗿𝗲 𝗥𝗲𝗹𝗶𝗲𝗳 𝗩𝗮𝗹𝘃𝗲 (𝗣𝗥𝗩) Application: Used in systems with less drastic pressure buildup. Commonly installed in liquid pipelines and pump systems to protect from thermal expansion or gradual overpressure. More suited for incompressible fluids like liquids. Opens proportionally to the pressure increase (modulating action). Provides more controlled pressure relief over time. Can be connected to a return line to recycle fluid back into the system. 𝗗𝗶𝗳𝗳𝗲𝗿𝗲𝗻𝗰𝗲𝘀 𝗕𝗲𝘁𝘄𝗲𝗲𝗻 𝗣𝗦𝗩 𝗮𝗻𝗱 𝗣𝗥𝗩 The choice between a PSV and PRV depends on: Nature of the fluid: Compressible (PSV) vs. incompressible (PRV). Pressure behavior: Sudden spikes (PSV) vs. gradual increases (PRV). System design requirements: Emergency pressure relief vs. steady control. Both devices play crucial roles in ensuring system safety and operational efficiency, and their proper selection and maintenance are vital for preventing accidents in the oil and gas industry. #OPEC #IEA #BP #Shell #ExxonMobil #Chevron #TotalEnergies #Halliburton #Schlumberger #BakerHughes7 #talent #process #jobs #employ #passionate #management #maintenance #xfactor #refinery #chemicalengineer #work #abroad #employee #volunteering #opportunities #psv #prv

𝗣𝗿𝗲𝘀𝘀𝘂𝗿𝗲 𝗦𝗮𝗳𝗲𝘁𝘆 𝗩𝗮𝗹𝘃𝗲𝘀 (𝗣𝗦𝗩𝘀) 𝗣𝗿𝗲𝘀𝘀𝘂𝗿𝗲 𝗥𝗲𝗹𝗶𝗲𝗳 𝗩𝗮𝗹𝘃𝗲𝘀 (𝗣𝗥𝗩𝘀) Pressure Safety Valves (PSVs) and Pressure Relief Valves (PRVs) are critical safety devices in the oil and gas industry, designed to protect equipment, pipelines, and personnel from overpressure conditions. While their functions are similar, there are key differences in their application and operation: 𝗣𝗿𝗲𝘀𝘀𝘂𝗿𝗲 𝗦𝗮𝗳𝗲𝘁𝘆 𝗩𝗮𝗹𝘃𝗲 (𝗣𝗦𝗩) Application: Used in systems where sudden overpressure could lead to catastrophic failures. Commonly installed on vessels, reactors, and high-pressure storage tanks. Often applied in compressible fluid systems like gas and steam. Opens rapidly (pop action) when the set pressure is exceeded. Typically used for emergency situations where immediate pressure relief is needed. Designed to protect equipment by venting to the atmosphere or a flare system. 𝗣𝗿𝗲𝘀𝘀𝘂𝗿𝗲 𝗥𝗲𝗹𝗶𝗲𝗳 𝗩𝗮𝗹𝘃𝗲 (𝗣𝗥𝗩) Application: Used in systems with less drastic pressure buildup. Commonly installed in liquid pipelines and pump systems to protect from thermal expansion or gradual overpressure. More suited for incompressible fluids like liquids. Opens proportionally to the pressure increase (modulating action). Provides more controlled pressure relief over time. Can be connected to a return line to recycle fluid back into the system. 𝗗𝗶𝗳𝗳𝗲𝗿𝗲𝗻𝗰𝗲𝘀 𝗕𝗲𝘁𝘄𝗲𝗲𝗻 𝗣𝗦𝗩 𝗮𝗻𝗱 𝗣𝗥𝗩 The choice between a PSV and PRV depends on: Nature of the fluid: Compressible (PSV) vs. incompressible (PRV). Pressure behavior: Sudden spikes (PSV) vs. gradual increases (PRV). System design requirements: Emergency pressure relief vs. steady control. Both devices play crucial roles in ensuring system safety and operational efficiency, and their proper selection and maintenance are vital for preventing accidents in the oil and gas industry. #OPEC #IEA #BP #Shell #ExxonMobil #Chevron #TotalEnergies #Halliburton #Schlumberger #BakerHughes7 #talent #process #jobs #employ #passionate #management #maintenance #xfactor #refinery #chemicalengineer #work #abroad #employee #volunteering #opportunities #psv #prv

Lifting Engineer

This post by Saeed Khanlari on pressure relief and safety valves is a must-read for anyone involved in the processing industry. It highlights the importance of these valves in preventing catastrophic equipment failures. What are your thoughts on the critical role of these valves in ensuring plant safety? Share your insights below!

Field Operations Engineer 🖤💀⚙️ 🔥 Wells reconditioning and rehabilitation works are carried out to solve "problems" in wells for example: - Low permeability: This can be a regional or local characteristic (well or area) of A site. When it has been determined that one of the causes of low productivity is low permeability, it must be considered, always along with other possible causes of low productivity. The basic characteristic of a low permeability site It is that there is a rapid decline of production. If there is not enough petrophysical information to define low productivity, production and pressure tests can be used to differentiate between low permeability or training damage, as a cause of low productivity. - Low Pressure: The pressure level of the deposit is closely related to the production mechanisms present in it. Therefore, good control of the pressure measurements that allow to define its behavior in time, which would help define the dominant mechanisms of production in time. When the cause of low pressure on the site has been defined, a solution that allows it to restore it must be sought, the most common way of performing this work is through improved recovery, specifically, by fluid injection. - Skin of Formation: The Skin damage can be described as a decrease in the productivity or injectivity of a well, due to restrictions on the neighborhood, in the drilling, in the deposit or in the communication of fractures with the well. When there is some type of damage in a well, it must be determined, as well as its degree or magnitude, to give a solution that corrects its effects. The Skin damage is indicated by: production tests, restoration tests and/or pressure decline, and comparison with the production behavior of the well or neighboring wells. For this, previous complexes, repair work and service operations that have been carried out should be considered. What other problems do you know? 🔥 #oilgas #wellservices #professionalexperiences #engineering #ecuador #petroleumengineer #wellintervention #engineer #work #moments #worksafe #workhard #IADC #IWCF #PetroleumServices

Following up on my recent posts, the daily routine work of a Cathodic Protection Engineer in the operation and maintenance sector involves various crucial tasks. This includes monitoring remote systems, analyzing reports, executing planned tasks, assigning responsibilities based on team skills, and handling emergency work. Before executing any plans, it is vital to conduct Cathodic Protection surveys to evaluate the system's condition. Surveys play a pivotal role in CP operation and maintenance. Here are some key survey types that I will delve into in upcoming posts: - Close Interval Potential Surveys (CIPS) - Direct Current Voltage Gradient (DCVG) - Pipeline Current Mapping (PCM) - Pearson Surveys - Potential Surveys - Stray Current Surveys #CathodicProtection #Engineering #Operations #Maintenance #Surveys

#HAZOPStudy : #LNGBullets HAZOP Study Steps: 1. #Preparation #Phase: #Methodology: (Collect the details about LNG Bullets,Dispersion model (ALOHA : is used to forecast the influence of LNG's toxicity on distance), Making P&I Diagram, Node Seperation and Control measures etc. - #Team #Formation: Include a multidisciplinary team including process engineers, safety specialists, cryogenics experts, and operators familiar with LNG operations. #Documentation: Gather relevant documentation including tank designs, P&IDs, safety procedures (Loading / unloading, operation),emergency response plans and BLEVE Thermal Radiation etc. 2. #Node-by-#Node Examination: #Guide #Words: Apply guide words systematically to evaluate each process node within the LNG bullet system. - #Example #Nodes: - #Tank #Design and #Construction: Consider deviations related to #tank #integrity, #insulationfailure, and #structuralintegrity, #Pressure, Sensors, fire suppression, Flow level sensor in the pipeline is step #Safety #Systems: Evaluate deviations in safety systems such as #pressure #relie #valves, #emergency #shutdown #systems, and #fire #protection, #Leakage #detection and #protection system, #Operational #Procedures: Analyze deviations in filling, venting,Operation & maintenance procedures 3. #Identification of #Hazards and #Consequences: #Leakage: Potential leaks due to tank failure, valve malfunctions, or external damage. #Over-#Pressurization: Risks associated with overfilling or malfunctioning pressure relief systems. #Cryogenic #Burns: Personnel risks during maintenance or inspection activities involving exposure to extremely low temperatures. #Consequences: Assess potential consequences such as fire, explosion, asphyxiation, environmental damage, and harm to personnel. 4. #Risk #Assessment and #Mitigation: - #Severity and #Likelihood: Evaluate identified hazards based on their severity and likelihood of occurrence. #Risk #Reduction #Measures: Enhanced monitoring of tank conditions and #integrity using advanced inspection techniques (e.g., ultrasound, thermal imaging). #Implementation of redundant safety systems (Fire Hydrant, Monitors, Sprinklers, Flame proof installation, Foam, DCP, Clean Agent type FEs, Static discharge device, Earthing and grounding,Barricading, Leakage monitoring devices etc. and emergency response protocols). #Training #programs for personnel involved in LNG handling to ensure proper safety practices and emergency procedures. 5.#HAZOPReport and #FollowUp: - Documentation: Compile findings into a comprehensive HAZOP report detailing identified hazards, causes, consequences, and recommended actions. - #Action #Plan: Develop a structured action plan with clear responsibilities and timelines for implementing recommendations. #Followup : Should be reviewed action plan by Management. #Regulatory #Government #Body : take the LNG storage license from #PESO. (Only for Safety Awerness Purpose)