This gas processing plant in the Permian Basin cost several million dollars to build and make operable. That happened on borrowed capital, and I can just about assure you that nobody involved invested a dollar in this little project. Nada. Zero, Zilch.

Someday very soon it will have no product running thru it and it will go idle. Sit for years and rust. Leak. Vent. Ooze.

Eventually it will need to be decommissioned and rigged down, all of its components destroyed. THAT will cost many hundreds of thousands of dollars to rig down, and the initial millions of dollars spent to build it, wasted.

Do you care?

I doubt it. All that wasteland in the background is not in your back yard and why should you? It wasn't your money, you didn't guarantee the loan to build it, why should you give a shit?

This is the first chance I've had to see Enno Peter's new work.

As one might expect, its simple, easy to read, concise and fast. No filtering to dark thirty to see what you want. This I recall was the mindset from the beginning of shaleprofile.com a decade or more ago...let the data do the speaking... think for yourself. No artificial intelligence necessary. I like that because I don't like children who've never owned working interest, paid an LOE or an AFE telling me what stuff means. If you don't know which end of a workover rig to walk to, you are no analyst. Period.

Here we see a type curve for oil rate vs. cumulative oil production for 60,000-some-odd wells in the Permian, per year. 2010-2015 is cashed, thank you very much. Projected decline I suspect is spot on.

We know that Permian HZ wells decline sort on a…

This from Novi. It says exactly what you would expect it to say. The Midland Basin has peaked, well productivity is falling on all relative metrics (over-drilling= well interference =degradation =pressure depletion), but not to worry because Tier 1 level locations are only 55% taken and there is lots of running room.

Economics are half-cycle = breakeven @ $50 WTI, even discounted 25%. Spacing used in this analysis must be <500 feet on every bench, D&C costs remain the same forever and produced water disposal is not a problem. Pressure depletion never gets worse, in spite of more wells in the cores, etc. etc. Everything is good. Naturally.

Let's get updated on the Barnett, because everybody is hanging their hard hats on that to save the world.

I included Andrews, Ector and Crane Counties in this mix. As I've suggested before these wells are deep, require multiple strings of pipe,…

There is so much stupid stuff being said by internet "experts," on the Marcellus and the Appalachian Basin, in general, it requires clarification. These experts have no access to realized data so they are hoping to bull shit you with self-promoting data from any source they can find that confirms their belief system.

Cum prods., regardless of what these experts say, are less than 7 BCF. The data sources I have access to suggest 24-36 month well productivity in the APP Basin is falling, most certainly from interference and ensuing pressure depletion.

These dry gas wells struggle to make money at <$1.50 per MMBTU, after all royalty, full cycle corporate costs, OPEX and transportation/processing, rental, compression, dehydration, etc. etc. costs are deducted.

Please don't buy the dung heap; multiplying daily production by NYMEX Henry Hub prices or converting dry gas to BOE equivalents to suggest gas is equal to MMBO...that…

and win a cheeseburger with fries from the Dairy Queen in Flatonia, that just had its bathrooms repainted.

No, it's not the burned remnants of R2-D2.

Novi and Enverus will have different well counts for the Permian, it's all about... definitions, what to include and what not to. We want to focus on HZ laterals in primary and secondary unconventional benches in both sub-basins.

There are 65,118 HZ wells in these two sub-basins (welldatabase.com). These are active producing wells, temporarily abandoned wells, abandoned wells awaiting P&A, DUCs, wells awaiting permit approval, wells with approved permits awaiting spudding and wells in progress. These wells currently take up space in limited remaining reservoir rock, or will when permitted wells are spud. We want to know what to expect from the remaining empty spaces; from a recovery standpoint, costs and related well economics.

The time frame for this HZ development begins 1 January 2010 and ends 1 July 2026. History is vague as to when the first HZ lateral was drilled to a source bed in the Permian but…

Condensate yield in barrels per million cubic feet is the vertical axis and condensate production is the horizontal axis. Condensate yield is down 29% from its peak. Either drier fields are being brought online or there is retrograde condensation of liquids in the reservoir as the pressure drops. It is more likely the latter. Condensate production is down 20% from its peak. The peak is in for District 8.

Gas production peaked a year ago.