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DVWE, beat me to it, great, I just had to make sure there wasnt any specific code equation. Thanks you two!

metengr, I have the original nominal thickness, the current thickness readings (N,W,E,S, using lowest amount), and the age of the vessel. I basically used an equation, dividing the difference of thicknesses to the amount of years its been in service. Is this be correct?

Hello All, I am conduction a vessel analysis in which I am no sure on something. Is there a formula/equation for the rate of corrosion (per year). My study is regarding a 53 year old tank in which I am trying to estimate a life expectancy before the material corrodes to the minimum required...

The displacements arent showing any vertical movement.

Temp 130F and press of 275. The discharge lines are both 36" with 10 feet of pipe exiting then turning down, approximately 10 feet into the ground. Its tight and theres no room for pipe expansion on the exit nozzle direction. I really dont want to bring up expansion joints, but at this point...

Yes, but do these allowables have a factor that the nozzles cannot exceed? For horizontal pumps, the factor is 2. Plus, the vertical inline are evuluated on principal stress. There is nothing on Vertical Turbine Pumps.

Then there are two cases...if the pipe does not exceed the material's elasticity, then it would cool down to AMB at it's original state....THEN, try to compress as the temperature drops below AMB, therefore, 2 cases. How is the material acting otherwise? Basically if the material cools down to...

Hello everyone, I am having a tough time figuring out the correct allowable load factor and/or nozzle calcs to use for my piping analsys off the discharge of a 36" and 42" nozzle. The stress program doesnt allow for vertic shafts and size of the nozzles are larger than 16" which will not work...

I have made an excel sheet with some equations. I have one with a vertical in-line and one horizontal centrifugal pumps. I assume to use the centrif pump equations but with a greater factor than 2. Is there a direction that I should take to be correct?

Hello Everyone, I've been assigned to check the nozzle loads for a Vertical Can Turbine pump. Suction is a non-nozzled 48 inch connection and the discharge is a nozzled 36 inch connection. I am confused and would like some guidence on how to run this sort of analysis. The suction and...

Thank you ApC2Kp, The pipe is 20" and it coming out of a tank, which has a valve connecting to the nozzle. The pipe turns and then loops around before entering the ground. I have two hangers, and well, the program sizes one can farthest from the tank and other is changed to a rigid support...

Its easy to choose a hanger, (two in my case) and bam! I pass with only 54% allowable, but I know its important to stay within 25% variation. I am using the PTP Spring Selection tool, but I need to know if I have the correct hot load. I have read everything from the internet.

Do I use a Y support or let it hang and run the analysis to take the load of the pipe from there (prior to selecting a spring can)?

In other words, how can I properly determine the hot load and movement?

I am practicing how to design a spring can with Caesar II. I know that I can ask the program to select a can using the free code, but for some reason it is forcing me to use a "rod hanger". Well since I am using an example from an old project, I find that there is something wrong. The input is...

Does Autopipe run API 650 Calcs for the tank nozzles, or do I have to do them by hand (bummer). I know Caesar II can but I'm knew to this program. Thanks, Richard.

I would think if a pipe cooled down from hot to cold, ambient in between, that the stress calcs would have to cases for thermal expansion, not one...if anyone can show me an example, that would help tremendously? Thanks

The link only shows one change in temperature, what about anything on the difference of two different delta T's, once in tension to a compressed state of elasticity?

So I was reading a client guideline and noticed something that wasnt correct from my studies, but perhaps it can be true. If anyone can share some light, it would be a big help. If a piece of pipe installed at ambient temperature and noted that at times the pipe can cool from a higher than...

Can anyone tell me how to explain or understand what the maximum allowable moments and forces would be on pipe supports, when after doing a stress analysis, only gives a 23% of the stress allowable? I'm getting a +10ksi moments and from my experience, wouldnt give a client anything more than...