That Barnett shale is wonderful. I worked in Barnett before they even knew how to stimulate it. It produced pretty good in vertical wells then with horizontal it really opened up. I was surprised how fast operators scrammed out of ftw and headed for Permian. They just blew out of Barnett and went straight to wtx
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Will do! This is not really my neck of the woods but have been keeping tabs on it since I saw some of the first Barnett wells come online. I think it will be something to watch. Makes for interesting landwork. The pugh clauses tied to most modern Permian leases have made for a bit of an Easter Egg hunt! I have not seen how this plays out on the legal side as far as interpretation of conflicting terms in multi-undivided interest units. âRolling Pugh Clausesâ in the more sophisticated leases require releases on deep rights on a proration basis. In other circumstances, the deepest perforation on a lease well may hold multi-section leases especially in conjunction w/ a retained acreage clause. A decade+ ago- operators had the insight to utilize the 3000â ft of âconsolidatedâ Sprayberry field rules to perforate the Penn-Miss-Dev rocks and commingle it w/ Wolfcamp/SB perfs. As these vertical wells age out and get P&Aâd, many pooled horizontal and allocation schematics have kept the leases intact. Depending on lease language, this could be forcing releases of deep rights that were covered by vertical proration units but not by Horz wells. If you are signing a new lease in either basin- pay close attention to the horizontal pugh language. The difference between âbase of deepest producing formationâ or âdeepest perfâ or â100 ft. below the base of deepest formationâ can make all the difference. IE: you allow an operator â100 ft. below the base of deepest formationâ and they perf the Atoka⌠that 100 ft could bleed into the pay zone of the Barnett. Semantics and grey area but definitely need to define your pugh clause clearly and tie it to a nearby well for ref if possible.
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This is great information. I just recently bought land in Ward and Reeves county Tx. All of this feedback is very informative and helps me to understand whatâs happening in my areas. I appreciate everyones contribution on this thread. Thanks
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It also depends on the interpretations of the law. Some people like to try to redefine the laws which ties things up in court. I know u can get it in a bind when u lease up a bunch of minerals and the bottom falls out. Like now. Clock is running. Drill it or lose it. Ouch.
China National Petroleum claims success drilling ultra-deep wells in Tarim Basin, 193 wells five miles deep, including one 26,000â deep. Not saying I believe Chinese boasts.
I wouldnât believe China based on how things are between the US and China relations at this point.
Is anyone getting asked for leases at these depths yet?
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Sweet spot is wet has w condensate. They are usually last areas to slow down. Many service and supply companies locate in wet gas areas intentionally
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Can you comment on Continental Resourcesâ âBullsnakeâ lease Woodford well on the Central Basin Platform in NE Winkler county? How does its first months of production compare with wells you have highlighted that are in Delaware and Midland basins? Is CRâs nearby Barnett(?) formation âJackrabbitâ lease well going to be plugged or ?
Most of the sweet spot on this play is under University Lands or the Sealy Ranch. Not too many owners will see large checks spread around as big as the wolfcamp footprint.
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Enverus is not giving me any completion info on Bullsnake. The offset JackRabbit well was not good. Certainly not economic. TXRRC gives usually lumps lease production together, but the JackRabbit is only producing 20 or so bbl a day. Enverus has a hit or miss allocation formula for individual wellbores⌠but I donât see any lease production that would explain the numbers you are showing. If correct, much better well than the JackRabbit. JR depth registers as Barnett. Maybe the Bullsnake was a deeper Woodford test. It is important to note that TVD for these wells is roughly 10.3K-10.7K. Generally speaking, that is a sweet spot for cost/pressure. Not really that easy to condense into a one size fits all but- that is usually around normal pressure (.9 gradient). The Jack Rabbit well had very little associated gas and a monster water cut. That may indicate a local geologic issue which may have inspired a second effort to the west. Time will tell. Appears the Delaware (below Wolfcamp) side has some complex geology and the better wells have worked at deeper depths. In general, the Delaware is more complex than Midland Basin, The Bone Springs/WC is no different. More carbonates. Operators tend to like that as it can create frac barriers and prevent vertical communication between benches. Remains to be seen how vertical drainage affects these Basinâs overtime. Gas expansion and lack of homogeneity in bench production on the Midland side suggests that this will be a problem in the future. The Miss aged rocks are tighter- more akin to something like the EF where repeatability should be viable.
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University leasing costs and terms are so high itâs almost undrillable. Not everything is deductible
Continental got it for 500 an acre at 1/5th under a CDC. Obviously did something right.
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Endowment Great for everyone
If continental keeps on with these big wins it will be continental-Devon tower.
Thank you for the very in-depth analysis. The production numbers I shared are from the Texas Comptrollerâs Crude Oil and Natural Gas website. [For more information, click on the magnifying glass icon at the top right hand corner of this page and enter âCONGâ in the drop down menuâseveral threads with the subject matter will populate. The Hentz Family well immediately above the Jackrabbit lease well seems to have a very unusual decline curve.
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Look at that eagle mountain 1 in ft worth they barely got it completed under control and itâs still blowing. Bingoâ
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I could not find an Eagle Mountain 1 well on the RRCâs PDQ webpage.
We leased open minerals in section 34 block 34 H&TC, Ward County about one year ago to Pioneer. Was told at the time they were looking at Woodford and Barnett. Our tract at one time had an Ellenburger well which was in the Block 16 Ellenburger field. Continental recently completed a Woodford well just north of this field. Would a highly fractured anticline be a good candidate for production from these zones? We were told that Exxon had retained their interest within the Block 16 field.
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It looks like bkv may have bought it. Itâs on rev Kenneth copelands lake property and itâs a whopper
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