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We are planning on utilizing a few pneumatic diaphragm pumps which will be discharging into a pressurized drain system. We currently have swing type check valves in the discharge of the pumps (as all lines entering the pressurized drain system have check valves). Is there any good reason why...

Hi, I have noticed that a number of companies will utilize SCH 80 minimum wall thickness for 2" piping regardless of what the minimum wall thickness indicates per the calculations, even for 150# or 300# systems. I understand that threaded piping would potentially require SCH 80, but this is...

I am reviewing a facility that plans on using a pneumatic only ESD system. It is planned to keep the ESD pilot around 125 PSIG. I have read that it is not practical to actuate the (large) station ESD valves off of the ESD pilot loop, and instead to have a power gas supply that can be cut in...

Please help me demystify the reason why sometimes multiple, smaller level gauges will be used instead of one larger gauge for bridles on oilfield vessels. I am aware of the need for multiple gauges if two liquid phases are present, but this is not what I am talking about. Is there a standard...

I have encountered what I think is a problem that has been encountered many times before, which is WHEN and IF it is necessary to go the extra mile and get the extra wall thickness offered by API 600/602 as opposed to B16.34. I can of course understand the corrosion aspect of carbon steel, but...

Ok Ladies and Gentleman, We are all aware that B31.3 specifies PWHT as being required when ANY PLANE of the weld is 2X the thickness of materials requiring PWHT (ie any plane measures more than 1.5"). By using the dimensions recommends by BF, which can be found here...

I am reviewing the valve specifications of several companies and have found a strange anomaly. Even with the general CS body/bonnet material specified as A105 or 216-WCB, 13-CR with HR seat (api trim 8), and graphite packing per api 600/602 the companies are limiting the max operating pressure...

I apologize, I am referring to API 520 Part 1

Does anyone have any experience with purchasing relief valves with real-gas isentropic flow equations vs ideal flow (cp/cv)? Do vendors (like pentair and farris) support the new methods outlined by API?

I have an idea to strip H2S out of crude by bubbling sweet gas through spargers that are placed every 5 ft in a very long vessel. The H2S must be reduced from around 75 ppm to 10 ppm. Ideally we would like to not use any sort of H2S stripping column as it may be overkill.. Has anyone ever...

Just putting this out there, but I am wondering if it is possible to strip H2S out of crude by sparging a small amount of sweet gas through a vessel. The vessel is about 40 ft long, so sparging lances could be put every 5 ft or so to achieve good contacting. The H2S PPM needs to be reduced...

So what is the bottom line for safety when it comes to blanketing large crude storage tanks with natural gas? I understand the concept of UFL/LFL, no conceptual explanation needed here. What I am interested in is what it actually takes to safely and practically implement this practice on real...

All transfer (heat, mass, momentum) is proportional to turbulence.

We are considering using 4" WOL fittings to branch off a buried 16" pipeline. The branch will extend 4" piping above ground for future tie-ins from gas/oil fields and will terminate with a blinded valve. The 4" above ground branch will be anchored by concrete. We have specified all the...

Hi all, I was wondering if anyone could weigh in on the subject of "when do hydrates REALLY become a problem". I need real world experience with gas production to balance what ProMax is predicting for hydrate formation. I am currently studying a gas pipeline which will be transporting about 5...

That is pretty much what I was looking for, thanks!

There is some API specification or RP on crude oil sampling that does detail the amount of mixing that can be expected in piping given the fluid velocity. It also goes into things like how many elbows can be placed in the line to supplement not having a static mixer.

Hello all, Why is the fluid category (D, M, N, etc per B31.3) on some Line Lists? Why is the fluid phase on some Line List? Why is the fluid density on some Line List? When are these fields used during the design and construction? Does anyone know? Thanks

Hello all, I am wondering if there are any CODE or STANDARD requirements for the minimum clearance between the storage fingers of a harp type slug catcher. We are using B31.8 for the piping with a flanged-bolt up assembly. so I assume you would want a few feet of clearance for installation...