I've been reading through ISO 15156-2. There's two options for choosing corrosion-resistant materials in ISO:
1) Selecting from Annex A.2's Table A.2, which includes A106
2) More detailed selection guide based on the pH vs. H2S partial pressure plot
Since I'm interested in A106 already, it...
I'm planning to install 4x 500 BBLD oil storage tanks with API12F standards. It will be 12'(diamter) x 25' (height) storage tanks. My colleague tells me that there's a rule of thumb of maintaining 75' from the fire tube of a heater treater to storage tanks.
Three questions
1) Where's the 75'...
All of the atmospheric tanks I've seen at wellsite are rated at 16oz = 1 psig. Usually they have one safety valve and a thief hatch. PSV opens at 8~12oz. Enardo950 PRV is the most common that I've seen. This valve has both over-pressure and vacuum safety features. The tanks also have a thief...
@georgeverghese
I checked the hydrate temperature, it seems to be well above the hydrate temp (-34F) at 30 psig. Two follow up questions:
(Most likely I don't need pre-heating but still would like to learn for future applications.)
1) Are you suggesting to preheat before I drop pressure due to...
@georgeverghese
The HP source is the discharge side of a 3-stage recip. Also I mentioned 30 psig for the stripping gas, but this may be misleading. I'm just choosing to first reduce from +1000 psig HP pressure to 30 psig with one big regulator (may be two), and have an option to use that 30 psig...
I'm trying to design a small (1.2 MMSCFD) glycol dehydration unit for an upstream facility. My client wants me to run the worst case scenario, which is 130F gas inlet with 2% water. I ran extensive simulations, and concluded that I must have a stripping gas going into the reboiler to achieve 7...
@1503-44
wow you are awesome, literally saved 4~6 hrs of struggle that I would've had if I were to look these up on my own with no experience on regulations. Very informative, thank you!
@1503-44
Thanks for the very detailed answer. I've always heard that such regulations exist, but this is my first time actually checking the details.
On the other hand, is there any website or publications that list the detailed upstream wellsite regulations when it comes to venting and...
@LittleInch
Not sure where exactly its coming from but it's a gas supply (not air). There's a pressure reducing regulator set at 110 psig for the supply gas line so I'm assuming the supply gas for the pump is coming from a pressurized source operating higher than that.
It's 1" gas lines and 3"...
@georgeverghese
"A large gas cloud will appear around the tank relief valves"
Kind of late reply to this, but I've found a P&ID of of a pretty advanced upstream facility that has horizontal atmospheric separator rated at 100psig @200F, with operating condition @8oz. This atm separator has...
Hi, I'm seeing two kinds of P&IDs for primary separators from wellhead:
1) PSV venting to air
----> Safer, because it's always guaranteed to work (almost always). But its "dirtier"
2) PSV relieving to flare line
----> Cleaner, but if something goes wrong with flare line, HP shutdown will have...
@all
The tanks are probably API650 tanks rated at 2.5 psig. The upstream operators usually try to maintain 16oz or below pressure on atm tanks. Thief hatches are usually set at 10~14 oz, and PRVs slightly lower than thief hatch. I understand that there isn't much operating margin to ensure...
@georgeverghese
Can you explain more? By compression power you mean fuel gas or electricity consumption to run engine & motors?
The problem with having multiple compressors is the additional rental cost for operators that don't own compressors.
Hi, I have a simple upstream wellsite facility design, shown in the below image.
Liquid comes from an HP separator (not shown) into the heater operating at 50 psig, 120F. The pressure on the heater is maintained by the back pressure valve set at 50 psig. The separated oil from the heater goes...
@georgeverghese
I think you are confusing refinery RV-flare connection vs. wellsite field storage tanks.... For field applications, the tanks' RVs always vent to air (at least what I've seen). I've seen some refinery P&ID's that connect the RV discharge side to flare, but that's not how it works...
@1503-44
In the uploaded PFD, the vapor pressure is low because I operate the heater at 150F, providing sufficient heat to flash off most gases in the liquid stream. If I turn off the heater and operate at 80F, the liquid in the tank reports 20 psia, which is above 14.7 and therefore boiling as...
@1503-44
There will be no lost vapors vented & flared from the atmospheric tanks because the VRU will be running. Doesn't matter if the crude is high API or not, because all the flash & working & breathing vapors will flow into the suction of the VRU, which operates at 4~8oz, which is below a...
@georgeverghese
Still doesn't make sense to me. I'm assuming the emergency blowby from the upstream separator, you mean a high pressure stream that can potentially dmg the low-pressure rated tanks. But can't this be handled by simply pressure regulators to ensure the stream coming into the...
I never understood the purposes of using VRTs. The VRTs operate around 3~5 psig and gravity-feeds the separated liquid into the tank using VRT's own height. The VRTs are usually hooked up to a VRU, so if you can separate as much gas as possible from the VRT before atmospheric tanks, you can...
@shvet
I have access to a commercial sizing software, so those are not what I'm looking for. I'm more interested in how ppl predict flash volume & liquid volume given only those limited data that I listed. Equipment sizing must have flowrate predictions, rn I'm not too sure how to do that
