I am involved in an oil field proccessing project.the pipeline discipline has asked me before to calculate the surge pressure which may be happened during operation to acount it as an alternative design condition to select the appropriate class for pipeline.the pipeline material is GRP.Since the...
To model subsea pipeline on seabed, I use restrain type +Y with given friction coefficient (Mu) (to model pipe and soil friction) and static soil stiffness (Stif) (to model pipe settlement in the seabed.) Any comment on this type of modeling is welcomed.
However, to near the model to reality for...
i have designed a shell and tube heat exchanger (AES type).I have choosed the secondary head type of heat exchanger based on a tempeature defference criateria.the source (reference) of this criteria is unknown for me.so i want to know if there is an applicable criteria such this or not?
I think we shall assemble the vessel and hydrotest it on the workshop. Then we shall disassemble it and transfer it in separate sections to site (it is not possible to transfer the whole vessel) and then reassemble it there. I think it is not needed to perform the hydrotest in site again. Am I...
I have recently designed some vessels with body flanges. In fact, each vessel can be divided into some parts. The question is that “Is it allowed to perform hydrotest on each section separately (using blind flanges) and then assemble the whole system or the whole system shall be tested at once?“
According to ASME sec 8 div 2 paragraph 7.4.2.2.b.1, an examination group shall be applied for all welds within a section. Now, with reference to table 7.2 it is seen that some examinations are N/A for some welds (for example circumferential joint on a nozzle with weld type 2 or 3, d>150 & t>16...
It depends on where they act. If you are going to use WRC 107 or 297 methods in order to find the final stresses, you should transfer the loads/moments to the shell and head junction. But, If you are going to use FEA based on asme div 2 part 5 (2007 edition), as seems it is the case, the load...
With regards, I quote the following statements from DNV-OS-F101 (2007) Sec 6D500:
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Pipeline systems connected to other offshore installations shall have compatible CP systems unless an electrically insulating joint is to be installed
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Without insulating joints, some...
Thanks SJones, yes DNV calls for evaluation of IJ requirement at landfall.
Regarding offshore system connections I make the question as follows (ref F101 6D500):
Is IJ required between subsea pipeline riser and topside platform piping (in atmospheric air)?, and is there any difference in case...
APDL: what is the command to define line with individual number between 2 key points. In other words, I know the commend (LSTR,P1,P2) to define line between 2 key points (P1,P2), but in this command I do not have control on the created line number, and hence I need a command which defines a line...
I want to perform free span detail fatigue analysis in line with DNV-RP-F105 (Feb 2006) (all the below sec references are made to F105). I understand that for each wave state (Hs,Tp, Teta) the design life should be calculated for Response Model and Force Model. To apply current scatter for each...
Thanks SJones, just for clarity as per DNV-OS-F101(Oct 2007) 6D504, I understand current drain for compatible anode protection systems is not required provided that both have adequate anode protection system, but for various anode protection system insulation for current drain is required.
For...
DNV-OS-F101, Oct 2007 sec 10 calls for As-Laid survey during pipelaying and As-Built survey after all the works and final test (however before operation phase).
During subsea pipeline engineering design, bottom roughness analysis for various phases (i.e. as laid, flooding, hydrotest, opeartion)...
