Replies to This Discussion

Permalink Reply by Chuck Fritts on May 18, 2009 at 8:34

Thanks Jay.

Denver Chuck

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Permalink Reply by alleyboy on May 19, 2009 at 2:41

Jay,
I read all of your posts and think you are probably the most knowledgeable on this site IMHO.
Could you explain to me the full meaning of choke, If a well is listed as 5mmcf on a 18/64 choke, wahat would it produce on full open choke. Thanks veryn much.

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Permalink Reply by Les Bamburg on May 19, 2009 at 18:50

Alleyboy, normally operators will not flow a well with a full open choke during the early stages of production as it could damage the well or the reservoir and would be an unstable operation. As the flowing pressure and flow rate declines the operator can progressively open the choke over time. In the North Sea they use remotely operated chokes to control well flow rates from shore based control rooms.

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Permalink Reply by king john on May 19, 2009 at 19:11

Les B
i thought the well had to be shut down for some period of time to re-do the choke ?
at least in the H-shale..
kj

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Permalink Reply by Les Bamburg on May 19, 2009 at 3:09

Jay, I think there is still some downstream pipeline capacity available for the remainder of 2009 and into early 2010. Getting gathering lines installed to the well locations may be the critical path dependent upon the area involved.

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Permalink Reply by Les Bamburg on May 19, 2009 at 3:05

Chuck, is your question related to Haynesville Shale production? If yes, the wells that are completed and connected are essentially producing at their expected flow rates. Only Chesapeake has indicated they may restrict the flow rates of newly completed wells.

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Permalink Reply by king john on May 19, 2009 at 4:31

les & GeoJay
what effect would the pipeline being full have on flowing pressure and down hole pressure?
and in turn what effect would that have on flow rate?
please and thank you
kj

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Permalink Reply by Les Bamburg on May 19, 2009 at 6:19

KJ, most gas transmission pipelines have operating pressures in the 800 to 1200 psi range dependent upon the location between pipeline compressor stations. This pressure should have little impact on the initial flow rates of Haynesville Shale wells due to their very high flowing wellhead pressure (> 5000 psi). After 2-3 years the flowing wellhead pressure will decline to a level approaching the pipeline pressure and that will begin to have more impact on flow rates. Normally at this point the operator will require field compression to maintain production rates at a reasonable level.

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Permalink Reply by king john on May 19, 2009 at 7:24

Les
i have been watching some wells in east texas that seem to be having a quicker than normal decline. these wells in their 5-7 month in production seem to be declining at a rate of about 50% month to month. i was looking for explanations other than the natural decline to attribute for these more than normal declines.
kj

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Permalink Reply by Les Bamburg on May 19, 2009 at 9:17

KJ, were those wells Haynesville/Bossier Shale or some other formation?

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Permalink Reply by king john on May 19, 2009 at 10:36

dont know for sure just they are deep verts. around 12500 ft .
kj

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Permalink Reply by Les Bamburg on May 19, 2009 at 11:33

KJ, some of those wells have very limited reserves (drainage radius and/or thickness) and can fall off in rate fairly quickly. Some of those may have to be switched to a low pressure gathering system (100 - 300 psi) within a few months of the initial production. Performance is likely more a factor of the reservoir permeability and/or well reserves.

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