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Permalink Reply by Les Bamburg on November 9, 2009 at 6:32

Marc, there is no specific data but generally the sourthern portion of the Haynesville Shale play has marginally higher levels of CO2 & H2S. Dependent upon the gas sales pipeline some treating may be required but this would not necessarily add significant costs.

Only the northern edge of the play has shown any condensate production but this is actually a benefit since it generates additional value.

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Permalink Reply by Marc Schulz on November 10, 2009 at 6:19

Equipment at wellhead can be pricier and scavenging costs can range up to 50 cents/mcf. These costs have to be incorporated as the H2S specifically cannot be vented.

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Permalink Reply by Les Bamburg on November 10, 2009 at 9:56

Marc, no need to scavenge the H2S as most would flare w/ the CO2.

H2S levels are not necessarily at levels to dictate a lot of special metallurgy like Norphlet or Edwards Trend gas production.

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Permalink Reply by Mac Davis on November 10, 2009 at 7:49

Does anyone know typical percentages of H2S, CO2, water, condensate, etc. run?

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Permalink Reply by Les Bamburg on November 10, 2009 at 9:59

Mac,

Condensate - ~ 0 Bbls/MMcf (Except Northern Edge)
CO2 - +/- 2-3% level
H2S - +/- 4 PPM
Water Content - Saturated

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Permalink Reply by Marc Schulz on November 10, 2009 at 10:43

I understand CO2 over 5% and H2S at >200 ppm
CO2 is too high to sell and H2S is too high to vent

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Permalink Reply by Les Bamburg on November 10, 2009 at 12:48

Marc, that is not consistent available data and operator comments. Much of the production in the northern portion of the play complies with pipeline limits of 2% CO2 and 4 ppm H2S. As you move south then gas produced falls in the 2-3% CO2 and just above the 4 ppm H2S.

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Permalink Reply by Marc Schulz on November 10, 2009 at 13:01

Thanks Lee
My information must be errant
If you hear of any sour wells let me know

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