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What are some classic applications where u would use a X opposed to an XN and vice versa?

What is the difference between an 'X' , 'XN', & 'PSN' Nipples and what are the differences in applications?

But does that affect drawdown across the perfs or does the tubing hanger control that?

dcasto, Sorry my knowledge is still limited on the functionality of the wellhead; You question why would you choke the well back? If a well is not choked then what is controlling the backpressure on the perfs? Too much drawdown is not gonna be good for the reservoir.

Let me clarify/simplify. If you need to draw down pressure to pipeline pressures, where would this be done? Just at the choke? Possible to bring down pressure flowing at 2mmcf/d from 750 pounds to 300 pounds without the worry of waering away the pipeline?

Help. I need some info on wellhead and surface flow systems. I hear terms of 'tubing flow valve' and 'backpressure valve' thrown around. First off would those be the same thing. Are they standard on most gas wells? What kind of configuration should you have if you need to bleed down a well to...

When running a horner plot run could apparent formation damage from the plot actually be a limited res or perfs partially covered by sand. How could I find this out (theoretically) b4 I go down in the hole.

Background: Shallow Gas well testing at 120 mcf/d & pulling a lot of water with it; 120 bbl/d. I am playing with the idea of downhole seperation and dumping the water in a lower zone (possibly a hydroclone) and see if it is economically viable. Questions: Has anyone had experience with...

We have a well that we believe is capable of better production than is currently evident. Is is highly possible that wax buildup would happen around the perfs (1800m) and not be evident at surface. Anyone know of any good references to assess this possible problem? Thanks, JR

How does one go about determing the effective stroke length of a pumpjack? What info does one need (i.e. surface stroke length, etc.) Thanks, John

What sort of things do you look for from logs, production data, and pressure data to determine whether or not a gas reservoir is a water drive mechanism?

Can anyone tell me is there a difference between reserve tanks and floc tanks? If anyone has a link of a detailed description of a mud system on a rig I would greatly appreciate it. Where does the clean fluid go after the floc tank? (possibly the reserve pit?) Thanks,

Generally, using the same choke size. How should flow up casing differ from flow up tubing? I would think up the tubing could lift more fluid and clean up the wellbore and evenutally flow at a higher rate due to less fluid cloumn pressure. Is there any rule of thumbs? Thanks,

What kinds of factors should be addressed when choosing casing & tubing sizes. It seems that they are chosen on rules of thumb (i.e. casing sizes based on depth) but what details should I consider. How is tubing size determined (amount of fluid to lift in the case of gas?)? Thanks,

What is the relationship between pressure and velocity in a pipeline if any? Is the only reason for high pressures in gas pipelines to compensate for pressure drops? Thanks,

Hello, I am a new grad and I have the petrifying task of being the only engineer for my small company. We use a third party eng. firm for some but I am trying to get a ballpark view on the entire process of o&g from prosepect to online production. Here's how I think it goes: (I am in Alberta...