AWS D1.1 2020 Changed notes

Below is a summary of the material changes made to the 2020 edition of AWS D1.1. Format changes – moving to 11 clauses from 9. This change was made to improve clarity and it includes the addition of reference tables, formatting to mimic the normal progression of welding procedure qualification, as well as other updates to improve ease of use. Additional requirements are added when using shielding gases for use with prequalified welding procedures. Revision of the requirements for the qualification of WPSs using waveform technology (Heat input, auto-calculation, and record.) Revisions made to the qualification requirements for inspection personnel … Continue reading AWS D1.1 2020 Changed notes

Elbow corrosion in the piping system

When we find that Erosion or Erosion-Corrosion Occurs in our piping system. Elbow area is one of the points where Flow hits and causes Erosion / Erosion-Corrosion. The simple way of looking at the wear (Eroded) or the thickness of the Elbow lost (Local-Thin Area) is the Grid UTM (Ultrasonic Thickness Measurement). This method will. This allows us to obtain both the profile of the remaining Elbow thickness and the ability to find the lowest thickness in the area by looking at the Thickness Profile obtained.   In another example of the Grid UTM area Outside radius of Elbow before the … Continue reading Elbow corrosion in the piping system

API 650 / 653 – Tank Critical Zone

API 650 Storage Tank – Critical Zone in the Bottom;  API 653 Storage Tank Inspection, Repair, Alteration, and Reconstruction Code requires the tank bottom to be within 3 inches from the tank shell to be a critical zone because the area must support the weight of the tank shell that is placed near the welding line. Shell-to-Bottom makes Tank-Bottom in this area highly stressed. Critical Zone will have special requirements for inspections, repairs or reconstruction. Continue reading API 650 / 653 – Tank Critical Zone

API 650 – Storage tank Nameplate requirements

API 650 Storage Tank – Nameplates;  The Nameplate of the API 650 Aboveground Atmospheric Storage Tank as per Standard (para.10.1) specifies that the letters and numbers on the Nameplate must be at least 4 mm tall and the Nameplate must be welded or welded to the Tank Shell at the position near the Manhole or attached to the Reinforcing Plate of the Manhole. On the Nameplate, the Storage Tank must be specified as in the picture.   Continue reading API 650 – Storage tank Nameplate requirements

API 510 Mechanical Clamp for Temporary Repair

Repair of Pressure Vessel – Mechanical Clamp;  Mechanical Clamp can be used to repair leaks Pressure Vessel temporary (Temporary repair) by using the Patch Plate Holder with Bolts / Nuts tightly and Inject substance Sealant to prevent Fluid leaks out along the edge of the Patch Plate. In an example of the Mechanical Clamp and Pressure Vessel (deaerator) with Steam leak as below: Continue reading API 510 Mechanical Clamp for Temporary Repair

Slip-on Flange ASME B31.3 limitation

Slip-on Flanges Limits per ASME B31.3;  In the ASME B31.3 Piping Code, restrictions on slip-on flanges are specified as follows:  Use welding Double-Welded for  Service that causes Severe erosion, Crevice corrosion, and Cyclic loading  Service that is combustible, toxic and harmful to people  Service at temperatures below -101 C 2. Do not Slip-on Flanges with Service with high pressure than ASME B16.5 Flange Class 2500. 3. Avoid  Slip-on Flanges with  Service that changes the temperature up – downtime (, Many the Large Temperature Contact of Cycle), especially with  Flanges are not covered  Insulation, which will cause a change in the temperature of the  Flange and.  Pipe quickly and may lead to thermal fatigue cracking … Continue reading Slip-on Flange ASME B31.3 limitation

Corrosion Rate calculation for pressure vessel and piping (API 510, 570)

Corrosion Rate for New Vessel and Service Change per API 510;  According to API 510, “Corrosion Rate” for Pressure Vessel to be reinstalled or Pressure Vessel is changed. Service Conditions can be obtained. Use the Corrosion Rate of the Vessel that has the same or similar Service Condition The Corrosion Specialist is the person who estimates Or estimates the value from the published data such as API 581. Use the double thickness measurement to calculate the corrosion rate by the first time after the Vessel service for 3-6 months and the second time according to the appropriate period so that the value can be estimated Corrosion Rate.     Corrosion Rate for New Piping and Service Change … Continue reading Corrosion Rate calculation for pressure vessel and piping (API 510, 570)

Typical location of Corrosion on Heat Exchanger

There are 4 main reasons that cause corrosion in heat exchangers to need to be concerned during the inspection: Water impingement, Temperature, Vibration, Velocity. Refer to: Corrosion in Heat Exchanger Likely Location of Corrosion – Heat Exchanger Tubes at Baffle;  Heat Exchanger Tubes in the Baffle Plates area are highly prone to corrosion. Due to the possibility of vibration of the Tubes causing friction with the Baffle (Vibration fretting) or Erosion from Fluid flow in Heat Exchanger For smaller tubes, The corrosion of the Tubes on the Baffle can be checked using a hammer. If the Tubes in the Baffle area is thin … Continue reading Typical location of Corrosion on Heat Exchanger