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I would not use that in process piping. It looks like it is more for plumbing and HVAC piping. The attachment you posted provides a link to a document which provides allowable loads in all three directions. For 3" it lists F vertical = 800#, F axial and F lateral = 125#. However, I don't see...

The flow of 4.5 m/sec across the top of the stack will not "entrain" air and cause it to flow through the stack. What it will do is cause a lower pressure than atmospheric at the stack exit due to the velocity relative to still air. Air at 4.5 m/sec produces a lower air pressure of 0.05 in...

Yes I would like to see your results. The B31.1 calculations is a cookbook method that takes the real method using the ideal gas equation and puts into a cookbook formula. I will show you the real equations using the ideal gas equations and how the B31.1 calculations are derived from these...

...with elbow. The vendor has calculated 7.12 bar drop across the plates therefore I assume is correct so the pressure upstream of the plates is 7.12*14.5 + 0.63 = 104 psig. There is a little more pressure loss in the 12"x20" increaser with will raise the pressure slightly but there is an...

I believe that you have accurately modeled the deflection of the bolt as a guided cantilever beam. So I believe the equation you set up is accurate. However for the typical size of bolts and nuts versus centrifugal forces I don't think you would overcome the friction force (due to bolt tension...

I think the issue when there is no H2S in gas phase but only in the liquid phase is that you have to calculate an effective equivalent partial pressure that existed in the gas phase to get that concentration in the liquid phase, since NACE only quantifies sour service by partial pressure in gas...

Here is another compressor project specification to API 11P and an issued for purchase Rev 1 of one of the specs I had previously attached so it has most up-to-date information. If you think you might want to go with API 618 I may have a go-by spec for that too.

Here is a good little discussion on reciprocating compressors from Dresser Rand

Here are two old Enron Specs for reciprocating gas compressors - one for non-separable integral engine/compressors - and one for packaged mounted separable engine-compressor units. I'm not that familiar with differences in API 618 versus API 11P (we typically used API 11P for upstream pipeline...

Here is specs for 4 -2200 hp compressor packages for a natural gas pipeline station. This project was after the previous spec project so it was copied from that one and modified which is why it looks very similar. Also attached is scope of work for installations and SDODR which provides a list...

Here is specifications and sequence of operation for 4450 HP packaged high speed reciprocating gas pipeline compressor which was installed in an old Enron pipeline compressor station in St. Rose La just north of NOLA. In regards to your question of API 618 versus 11P, I believe the difference...

I was lead mech for project to install 4450 Bhp natural gas compressors with natural gas recip engine about 25 years ago in Larose La, and another project to install a row of four 2200 HP natural gas pipeline compressors and pipeline station near gulf in southern la. a couple of years later. I...

I think I see what the quotation of the Original Poster is trying to say. I assume this is a direct quote from the source that he found the layout diagram in. That the piping configuration shown is the most efficient as it is all basically fitting-to-fitting so it reduces the piping length and...

I think that is a good arrangement for hot piping. The vertical down pipe will absorb thermal expansion difference between the hot and cold pumps more than if the common header was on the same elevation of the pumps and no vertical drops. The elbow supports would be free sliding. A piping...

Yeah looking at the head loss tables for 6", 8" and 10" 5 ft/100 feet loss is about 10 ft/sec, 13 ft/sec and 14 ft/sec, which is kind of high. I usually just stick to close to 7 ft/sec or 9 ft/sec maximum.

I think he means head loss per 100 feet of pipe like 5 ft per100 ft friction loss. That sounds about a reasonable friction loss resulting in a velocity of 7 to 10 ft/sec. I myself never used that rule of thumb but just try to maintain a velocity of 7 to 10 ft/sec. It is my understanding that...

Here is a very old Exxon spec for multiphase twin rotor PD pumps which has a little information on materials and other info that may be helpful.

5% of what? What kind of water pipe systems you are talking about?

Here is another reference on corrosion in Oil and Gas Industry.

Looks like you just have H2S in the liquid phase in 18 PPM concentrations. NACE will give recommendations on materials for different H2S concentrations. CO2 is extremely corrosive due to formation of carbonic acid in water. 10% CO2 of gas phase is an extreme amount and I believe you would not...