ASME PCC-2 is written a little more clearly for the design of pressure sleeves. Refer to Figure 206-3.5-2.
I would do your pressure containment calculations as you have for example 1. Note that that if your fitting has a long seam weld, your weld efficiency of that seam will be based on your...
@GD2 What am I missing?
Try running the numbers here.
If we assume this is a B31.8 pipeline, the maximum design pressure is ~875 psig, assuming the highest allowable design factor of 0.8. That results in a hydrotest pressure of 1094 psig, which is about half of the proposed test pressure here...
Am I missing something? That hydrotest pressure on that grade of low yield pipe results in hoop stress almost double the yield strength. This looks like a bomb to me.
What is the design pressure? What is the basis for the test pressure?
Those main line and kicker line sizes are in the range that I've typically seen. I've seen operators' specifications limit the kicker to no less than 1/4 of the main line diameter (so DN 50 for your DN 200 main line), and many installations are larger than that. You'll need to check fluid...
I'm guessing you are looking at an old version of B16.20 and a newer version of B16.5. The reference only works if you refer to B16.5 from around the same time as the version of B16.20 you are using.
Consider using a current version. Both standards have been significantly revised.
I interpret condition 3 to require action to prevent impact loading, if you are going to take credit for that reduction. That may mean removing small bore valves from the system or taking administrative action (like car seals) to prevent impact loading at cold temperatures, as well as guarding...
Could you elaborate on your pipeline?
Pipeline details like size, wall thickness, material grade, design code, design pressure, environmental conditions, and fluid properties would all be helpful to understand your request, as well as corrosion rates observed, corrosion inhibition, details of...
Those limits exist because pipe exceeding those limits has material and manufacturing difficulties that are not necessarily addressed by the requirements of the standard.
That is seriously thick pipe. Literal "gun barrel". Can you meet all the API 5L requirements except the specified wall...
Segmentable bends are bends with additional ovality controls so that they can be field trimmed to the necessary angle. I'm used to seeing B16.49 bends with supplementary requirement SR15.3 specified (maximum 1% ovality through the bend). These are more costly, due to added complexity during...
Depends on your industry and specialty.
In Oil & Gas, API certifications can be useful (e.g., API 570). There are also nondestructive testing (NDT) certifications through ASNT or credentials like Certified Welding Inspector (CWI) from AWS.
Getting your PE license is always a good idea...
I've seen supplementary CVNs specified on A350 LF2 and A333 Gr 6 down to -80°F, but getting plate material of similar metallurgy that will pass is likely to be a tall order.
The code does differentiate between who completes the weld. It assumes pipe is supplied with associated NDE completed. No additional NDE is required if the designer utilizes the joint quality factor associated with the pipe. Additional NDE may be completed to provide a higher joint quality...
This is a strange no-man's-land of the codes, but flanges per A694 and A707 in this size and pressure class are common and have a long service history in my region, and are specified by multiple major operators' pipe specs. In short, the dimensions of the flanges meet B16.5 and the pressure...
L7's are alloy. A320 covers some stainless grades as well.
https://www.portlandbolt.com/technical/specifications/astm-a320/
You could be getting galvanic corrosion if this flange/bolting is exposed to the elements. Isolation kits would disrupt the galvanic circuit, or you could try a more...
You've got this backwards. A high stress ratio gives a lower Tr. Look at Figure 3.7. Case 2 has a higher stress and lower Tr, so it has a higher MAT than Case 1.
I don't fully understand your question, but below the Rts threshold from Figure 3.7, we are confident in the behavior of the steel...
1. Yes, Charpy impact tests are common for line pipe.
2. Any of the methods in Annex G or 841.1.2(c) are acceptable. The values given in G.7 are commonly used because they already did the math for you (assuming you meet the limitations in G.7.1).
3. No. You will typically design at the highest...
