Chesapeake Long Lateral Flow Test and EUR
This well is located in the Stonewall area:
In July 2016, Chesapeake placed the CA 12&13-15-15 1H horizontal well on production, targeting the Haynesville Shale in Caddo Parish, Louisiana. This well's results provide further confirmation that the company's current completion optimization techniques, along with extended laterals, are having a significant impact on higher sustained flow rates and the increased potential for higher rates of return in all areas of the Haynesville. With reducing cluster spacing and increased proppant loading, this 10,000-foot lateral well reached a maximum production rate of approximately 38.0 million cubic feet of gas (mmcf) per day with a flowing tubing pressure of 7,400 psi. The company's current estimate of the ultimate recovery from this well is approximately 22 to 24 bcf with an estimated completed well cost of approximately $9.8 million.
Jay
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Replies to This Discussion
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Permalink Reply by Skip Peel - Mineral Consultant on
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That is impressive, Jay. We are finally beginning to see the level of improvement in performance by the newer 3.0 Haynesville well designs. I would like to know the cost/mcf from these wells.
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Permalink Reply by Mark on
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Frac data shows 639,929 bbls of fluid used to frac the well. That is the most I've seen for a Louisiana well.
XTO used 877,391 bbls on 2015 Texas well. No where near the Chesapeake well production rate though.
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Permalink Reply by Skip Peel - Mineral Consultant on
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The 3000#/ft. proppant load was a significant increase and from what I hear the perf cluster spacing has also been reduced.
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Permalink Reply by dbob on
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That sand rate sounds more like a sand pack than a frac, Seriously, think 1 cubic yard per linear foot, or one truck load for every 15' of well.
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Permalink Reply by Skip Peel - Mineral Consultant on
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I think that is why there has been an associated increase in the volume of water pumped.
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Permalink Reply by olddog573 on
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CHK has now said they are looking to unload some Haynesville property, any idea where this would be?
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Permalink Reply by Skip Peel - Mineral Consultant on
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I haven't read anything specific about the acreage CHK looks to sell. We probably won't know for sure until it sells. If I had to guess I'd say Sabine and SW DeSoto. I think they will hold on to their S Caddo, N DeSoto, S Bossier and N Red River acreage. I wouldn't be surprised if there were multiple buyers for specific areas.
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Permalink Reply by Skip Peel - Mineral Consultant on
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All acreage outside the heavy black line in the second map, "Full Field Transformation"?
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Looks like I maybe in the core then...while CHK has it's problems you won't hear me bad mouthing them, seems to be one of the few companies willing to make HS work. For that I'm glad, because Lord knows I can't drill a 9.8 MM $ well.
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Permalink Reply by Steve P on -
well, i am clearly not an operator hater - i even bought stock in CHK back in the day (lost a bit on that investment) but for the past 5 or 6 years i have been getting royalty payments from 4 different operators from HA wells, and my payments per mmbtu from CHK have consistently been 15 - 25% less than the others, year after year. my best acreage is held by CHK. i will deem it my good fortune if they sold my leases to another company, especially before they drill another well in the unit.
Old Dog is correct that CHK is active, but being paid 80 cents on the $ is a big price to pay.
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You must not have any wells with Samson? I'm now being paid 55-60 cents on the dollar and they are not active. While CHK doesn't show me their deductions like Samson does, the CHK payments are usually the same percentage on deductions check to check, no matter what the volume is, which is not the case with Samson. I'll have a Vine well within the next year so I'll have another operator to compare, but as previously said, I've been fairly happy with CHK.
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