One other question (I think you can explain better than before), what effect does working at high altitudes (6000-9000feet) in the rockies have on formation volume factors, if instead of standard 15.025 psia in Wyoming I use the actual 11.0-11.8 psia that atmosphere is my Bg (gas expansion...
Thank you very much Zdas04, that was exactly the physical interpretation I needed to see this.
So I can just take the final Mcf standard when I see it and x (14.73/ P(flowing actual)) and I will get the volume at the Pactual.
One other question, when I am looking at the orifice equation and I...
So you are saying "what you are looking at is the pressure at the delivery pressure, so you have selected to set your standard to 11.87 psia. The volume required to release the same exact energy will increase, and the BTU per volume will decrease." is that the BTU/Mcf will go down so if you sold...
Because there are different pressure bases for every state (mid continent typically around 14.7 psia and the Rockies around 15.025 psia) due to contractual agreements. They do this I assume to guarantee all gas is truly on a standardized basis. They do these calculations at the wellhead and...
Can someone explain what is meant by the "the flow measurement was converted to a base pressure of 14.7 psia?" (when the outlet pressure was in fact much higher than 14.7 psia)
Does this mean that if the inlet pressure is 200 psia and the outlet is 50 psia and you covert to base pressure of...
I was trying to calculate BTU value for gas sales. I understand the in our state we use 15.025 for contracts, but is that just a made up value, a legal agreement to standardize everything, (we are at much higher elevation and therefore like you said you will get 20% less energy when your at the...
If a natural gas well is drilled in the rockies at 6000 feet should the calculation for heat content take into account the reduced atmospheric pressure (11.87 psia instead of 14.73 psia) eventhough the gas won't see the atmospheric pressure until the burner tip. The gas I am dealing with has a...
Ok i'm on the right track finally I think. So utilizing the sonic flow equation it looks like if you take out the constants that aren't a function of choke size.... as you change orifice diameter=(Rate/Wellhead Pressure)^1/2 as shown below:
q=878 x C x A x Pupstream * (big constant in square...
Just because it's critical doesn't mean you can't get different pressures, just means you can't increase the rate as a result of lowering the downstream pressure, right? You can still increase the rate by opening the choke which will change the wellhead pressure as a result.
Keep the replies...
First, thank you for your help!
To answer your question, I will be changing the orifice and will hold the downstream pressure constant, the wellhead pressure will change and that is where I have been trying to go with this thread but haven't asked very well. Different gas wells have different...
I have googled it and I have spreadsheets with all the calculations (from Petroleum Production Engineering, A Computer-Assisted Approach), but all I can do with what I have (pressure inlet and outlet and orifice size) is calculate the maximum rate for the 12/64ths choke. What I wanna know is if...
I apologize already if this is a dumb question. I am reservoir engineer and I am trying to learn some production engineering basics but don't have a good mentor to ask questions too. I have a well that was just perf and frac and is producing 3 MMcf/d on a 12/64 choke. There is 5000 psi...
