Is the 'ol BAND getting back together? Is the EagleFord planning a Farewell or a Reunion Tour?

Well, numbers don't lie, they also don't tell the truth, they are all just subject to your interpretation.

(See following  table.)

  • Both US and Texas total active rig counts have increase roughly 50% year over year, but Eagleford's count has almost doubled.
  • As of March 11th 2022, almost half of all active rigs in the US are drilling in Texas. 
  • Interestingly the Eagleford has about 18% of the Texas total and 9% of the US total
  • Finally Karnes County has 25% of Eagleford, a little over 4% of Texas, and amazingly over 2% of the total US active well count.

Where is it all going? Only Time, Politics, and the Current World Situation will tell, but I bet there are a lot of folks on this site that have meaningful information and insightful opinions. 

Let share what we know and what we think, is it Farewell or Reunion Tour?

Aggie '75

Select Rig Counts as a % of …
Texas as a % of US Total 48.27%
Eagle ford as a % of  US Total 8.45%
Texas Total 17.50%
Karnes County as a % of  US Total 2.11%
Texas Total 4.38%
Eagle Ford Total 25.00%
BAKER HUGHES
https://rigcount.bakerhughes.com/na-rig-count
Rotary Rig Count 3/11/2022
               
      This Week  +/- Last Week  +/- Year Ago
  United States Total   663 13 650 261 402
               
  Major State Total                
  Texas     320 12 308 117 203
  Texas RRC             
  DISTRICT 1    22        
  DISTRICT 2   24        
  DISTRICT 3   6        
  DISTRICT 4   15        
  DISTRICT 5   2        
  DISTRICT 6    24        
  DISTRICT 7B   6        
  DISTRICT 7C   26        
  DISTRICT 8   177        
  DISTRICT 8A   13        
  DISTRICT 9   0        
  DISTRICT 10   3        
  Major Basin Total            
  Eagle Ford    56 2 54 27 29
               
  Top  3 of 19 Eagleford Counties            
  Karnes   14        
  Webb   11        
  La Salle   7        
Eagle Ford Shale Rig Count
(as of 03/14/2022)
https://www.shaleexperts.com/plays/eagle-ford-shale/drilling_activi...
Showing Top  3 of 19 Eagleford Counties
Eagle Ford Shale Active Rigs Oil Gas Oil & Gas Horizontal Vertical Footage Share
Karnes 14  12  ---  13  189,500  21.54%
Webb 11  ---  129,400  16.92%
La Salle ---  ---  65,250  10.77%
Total 32  18 7 3 28   384,150 49%

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Interesting set of numbers and data - thanks for pulling this together.

My take on this uptick in activity is:

Many of the original operators that "founded" the EF have moved on via selling their assets to third parties who paid big money for the undrilled EF locations. Combine that with the fact that the original Gen 1 EF wells are now reaching the end of their productive lives, these new operators are starting to cash in on their investments. This uptick started several months ago - it may only grow more with the recent (and predictably short lived) triple digit oil price.

These new operators drilling new wells are benefiting from the latest in frac approaches. A good example is Ensign (who purchased Pioneer's EF assets). Ensign is mostly ex Murphy people - they know the EF trend. Latest frac approach has allowed them to make much better EF wells than the original Pioneer wells in the same area. e.g. production on this new laterals in the first 8-9 months is more that the original Pioneer wells made in 3-5 years. Fast payout and cash flow = better economics.

You are also getting some operators in the EF trend who are "old" EF players. Validus is headed by ex CHK people who worked the EF in S Tx in the early days of the play. Recoil is headed by ex Petrohawk people. Old players taking new technology to exploit the EF.

My info shows 14 rigs working in Karnes County, and another 4 to 6 close by in Atascosa, Wilson, Gonzales Counties. You think these are all Gen 2  EF folks?

EOG is still active but using Gen 5 frac approach. I would estimate over 75% of rigs are Gen 2 or 3 companies. Highly economic area for EOG

So it may be a blessing to those of us whom EOG has HBP but has not yet done infill. Any time now will be okay too.

Morning Ed,

Have you seen any EOG drilling in your area?.

They completed "fill in" on my relatives property north of Pawelkville a little over a year ago, but haven't done any fill-in yet on their units southwest of Falls City along Wilson - Karnes Line. Granted those HBP wells on those later units in the south have had only about  75% of the per well production those units in the north,

Aggie '75

Hi Aggie '75.

Yes, EOG is drilling on leases very close. Hopefully they can hit the bull's eye soon on ours. I am glad that improvements have been made since Gen 1 and feel blessed to have weathered through the tough times with only HBP.

Hey, Mark,

I am unschooled in the various Gen's of fracking that you cite.

Possible for you to list 3-4 characteristics that distinguish Gen 5 from Gen 2, please?  Would be most appreciated.  Thanks.

Tried to reply to this last week on phone - that didn't work!

Without diving deep into years of frac approaches, it is impossible to point to "specific" characteristics that separate Gen 1-2 fracs from most recent Gen 5+ frac designs.

  • Aside from longer laterals, improved lateral placement in optimum landing zones and improved casing cementing techniques (all of which are very important as to well results), more modern fracs can be categorized by some of the following characteristics:
  • Shorter frac stages (as short as 100-150' vs older 300+' stages)
  • Perf cluster spacing differences
  • Proppant types, mixes and concentrations (e.g. 100 mesh tail in proppant as well as using 3-4 different sizes of proppant)
  • Proppant volumes (up to and over 3000# per foot proppant loading)
  • Fluid volumes (much higher volumes per foot of zone frac'd)
  • Use of diverters
  • Specific frac'ing based on section penetrated (using logs and data from laterals to select zones to frac / plus avoid other zones that are not worth frac'ing)

Seeing this info is difficult since everything is now filed in Frac Focus - one needs to have a graduate degree in frac'ing to understand all the additives. Plus generate an algorithm to covert the percentages of different items to pounds and gallons of each item.

Clear as mud - but the proof is in the results: better IP's and larger EUR's

Wow!  Thanks.  Great info.

It is truly amazing the sophistication of such a gross "macro" undertaking as fracking, a couple of miles deep in the ground, invisible.  Not to mention the precision of steering of the drill bit. 

But, you're right:  The proof of the pudding is the production volumes and rates.

Anyone know anything about Pillar EFS, LLC?  A Dallas-based E&P company backed by some energy private equity.  I am unfamiliar with the professional backgrounds of the officers of Pillar.

Pillar has just permitted 2 wells in Atascosa, pretty far up-dip.  The pad site is about 5.5 mi SW of the Wilson-Atascosa county line, and, if you drew the extension of the Wilson-Karnes line SW into Atascosa County, it is about 5 miles NW of that line.

I know this management team very well. Ex Brigham and then Cinco O&G / EnCap backed.

Also know the Old Ironsides PE group that is presently backing them.

Their management team is as good as it gets and understand the unconventional approach with the best of them.

I believe that they were in this same area while working as Cinco O&G.

Looked at this Pillar permit area - interesting

EF section around 8500-8700'. Only about 70' thick with about 50' of the sweet spot EF section. But also underlies a lower AC section that may be very interesting.

This is area where EOG was drilling their "wildlife" wells in 2013-2014 - Ocelot, Grouse, etc. 

Short laterals (5000') - limited as to how far to go north due to faulting. Decent fracs for that time frame (around 1300-1500# per foot proppant loads).

Wells were notorious for lower IP rates (300 BOPD range). GOR decent with a bit lower oil gravity (low 30's).

My prediction - Pillar EFS is looking to frac bigger and improve stimulated rock volumes in the EF section as well as mechanically co-mingling upward into the lower AC section. Expect to see 2500+ pounds per foot proppant loading.

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Longer vs shorter laterals

Posted by Chaz on May 3, 2019 at 1:30pm 0 Comments

This may have been discussed at length at some point on this forum so please forgive me if I'm repeating a question that may have been answered.

Six years ago CHK drilled wells with 5000ft laterals; recently they have come back and…

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