Does more associated gas usually increase the outflow of condensates and NGL's?

This question is for a condensate well without much oil.

The calculated gas final open flow is 1161 Mcf/day.  The well is located in the "super-rich" Upper Devonian Shale per RRC.  Therefore, estimate about 30% condensates with a 45% NGL gas stream.

1161 Mcf/day open flow for gas seems to be on the low side.  Is there a way to determine the daily volume of NGL's and condensate from this gas flow?

In addition, does the calculated final open flow of gas include the NGL's in the gas stream or are they only calculating methane for this measurement?  It is a Chesapeake well.

Thanks!

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Permalink Reply by Brian Powers on February 2, 2013 at 4:34pm

Todd-

 

The raw gas would have to be sampled and analyzed to determine the estimated liquid yield and the relative proportion of condensate and NGL's included in the sampled volume. Even if drilled and completed in the perceived "super-rich" region, a rate alone without an accompanying  chromatographic analysis is meaningless, irrespective of the well pad operator.

 

Brian

Permalink Reply by Todd on February 2, 2013 at 5:27pm

Hi Brian,

Thanks for your information.

What about this question:

Do you believe the calculated final open flow of gas includes the NGL's in the gas stream or are they only calculating methane for this measurement? 

FYI: I came up with the estimate of 40 to 45% NGL's in the gas stream from McClendon and 30% of the NGL's to be condensate from the RRC Investor Presentation.

Permalink Reply by Todd on February 9, 2013 at 7:40am

Brian and Fang,

I've been studying condensate well flow characteristics.   In sum, condensate wells (aka gas condensate wells) behave very differently than dry gas and wet gas wells.

It is quite complex but I've been able to summarize it as there being 3 regions within a gas condensate well:

Region 3: Outer region = increased pressure - only gas flows in this region

Region 2: Region of net accumulation of condensate

Region 1: Inner region near the wellbore = decreased pressure where condensate saturation is greater than the critical condensate saturation - condensate and gas both flow in this region.

Results:

The overall composition near the wellbore becomes richer in heavy components.

The composition of the liquid will change locally due to the difference in the mobilities of the gas and condensate phase.

Condensate Blocking: condensate builds up around the wellbore and leads to decreased dry gas productivity of the well.

Reference: http://www.netl.doe.gov/technologies/oil-gas/publications/EPact/071...

Hence, gas condensate wells yield less associated dry gas compared to wet gas wells. 

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