Frac jobs disclosed to FracFocus · activity through September 7, 2026 · published September 8, 2026
Last week this newsletter made a prediction. It did not come true, and that is the lead.
We reported that EOG had broken a 244-day filing blackout and said to expect its settled pace to jump
this issue as the new jobs aged into the window. EOG filed nothing at all this week — zero new
disclosures. Its 19 disclosures with 2026 job ends are the identical set we saw last week, its newest job end
is still 2026-08-24 (now 15 days back, up from 8), and its settled pace is still
1.7/28 d. The blackout break was one batch, not a resumed cadence. Full detail in the card below.
Second, and just as important to read correctly: this was a thin filing week. Against last week's
extract, 65 new disclosures landed and 5 disappeared. That, and not a slowdown on the ground, is why
the headline tile and the settled pace both fell. This issue's 28-day tile reads 109 jobs and the
settled pace 308.0 per 28 days; recompute last issue's own 28-day window on this morning's
filings and its published 112-job tile is already 150 jobs, while its 322.3 settled pace recomputes to
325.7 (+3.4). Read this week's 109 as a floor, not a count.
And read the last columns of every chart with a grain of salt. The week ending September 7 shows
0 jobs on file against a settled pace nearer 77 a week — the newest job end anywhere in
this extract is 2026-08-26, so the week has simply not been filed yet. The same zero appears on the
drilling-versus-completions chart, where the September 4 point is 0 frac jobs against 268 rigs. That is filing
lag, not a shutdown.
Frac jobs, last 28 days
109
Aug 11 – Sep 7, 2026 · filings still arriving
New Mexico / Texas split
35 / 74
32.1% of jobs in NM — against last issue's window recomputed at 34.7% (52 of 150), not the 40.2% it printed on the day
Settled pace
≈308 jobs/28d
jobs ended 42–126 days back ÷ 3 — the fully-reported baseline
Median water per job
506,721 bbl
median, n = 109 jobs reporting (the mean is 541,000)
Median proppant per job
23,335,956 lbs
median, n = 84 jobs reporting (the mean is lower, at 22,500,000)
Produced / recycled water
82.9%
volume-weighted share of disclosed base water — a genuine jump from last issue's window recomputed at 71.3% on this morning's filings (it printed 71.0% on the day) · by jobs it is 78.1% (57 of 73 reporting a source) · 73 of 109 jobs report source · record-level 73.1% (57 of 78 rows). The tile leads on the volume-weighted figure this issue; last issue's two readings happened to coincide at 71%, this issue's do not
The EOG call did not come true — here is what actually happened
FracFocus disclosures filed by EOG Resources with a 2026 job end, read against the New Mexico
regulator's permit and DUC counts (OCD, queried Sep 8). A newsletter that prints a prediction has to print
the outcome.
What we said last week. EOG had been dark for 244 days. It filed fifteen disclosures with 2026 job
ends in one go, went from the darkest large filer in the basin to current in a single step, and we wrote
that its settled pace of 1.7 per 28 days was a timing artifact that would "jump next issue" as those
July and August jobs aged into the 42–126 day window.
What happened. Nothing. EOG filed zero new disclosures this week. Its
19 disclosures with 2026 job ends are the identical set we read last week — not one added, not one
revised. Its newest job end is still 2026-08-24, which has aged from 8 days back to 15. Its settled
pace is still 1.7/28 d, unchanged to the decimal. Its filed-last-28 count fell from 10 to 5, and that
fall is pure arithmetic. It is worth being exact about which jobs moved: the 28-day window rolled forward off
the Aug 4, 5 and 10 jobs, 5 of them. No July job was ever in that window — last issue's ran
Aug 4 to Aug 31 and held only the ten August jobs. The Jul 16 batch is the one sitting in the
settled window, and it is what produces the 1.7/28 d. The blackout break was one batch,
not a resumed cadence, and last week's call was wrong to read it as the second thing. The jump is deferred,
not cancelled, but it is slower than "next issue": Aug 4 enters the settled window at the Sep 15 anchor, Aug 5 and 10 at Sep 22, and Aug 20, 21, 23 and 24 not until the Oct 6 issue.
EOG remains flagged current on the filing table at 15 days, because the flag measures the age of the newest
filing and nothing else.
New Mexico says the opposite, and it says it louder than last week. EOG's
unspudded permit bank fell 28 to 971 — a third consecutive fall and by far the biggest yet
(1,012 → 1,009 → 999 → 971) — while its New Mexico DUC stack rose 37 to 852. It is
converting permits into drilled wells faster than it is adding permits, and then not completing them. EOG alone
is 32% of the basin's entire DUC build this week; EOG and Mewbourne together are 51%. Drilling, yes.
Completing and filing, no. Every pace, fleet and spend figure in this issue still understates EOG.
Special: a decade of sand per foot — the basin found its number
Midland Basin, nine core counties · FracFocus proppant mass joined to RRC W-2
perforated intervals · 20,479 joined wells surviving the sanity filters, 2016 – Sep 2026 ·
median lb of sand per perforated foot by frac year · *2026 is preliminary (n = 313).
This week the series genuinely moved, and it is worth saying so plainly after three issues of reporting that it
did not. The Sep 5 RRC wellbore file took the joined-well count 20,437 → 20,479;
2026 fell 2,007 → 1,996 lb/ft on a sample that grew 287 → 313, and
2025 rose 2,038 → 2,040 on n 2,033 → 2,049.
The other 9 years — 2016 through 2024 — reproduce to the pound. This is a real move on new joins, not a reprint
and not a method change.
1,474
2016
1,795
2017
1,855
2018
1,852
2019
1,898
2020
1,998
2021
2,002
2022
2,021
2023
2,029
2024
2,040
2025
1,996
2026*
Everyone remembers the loading race. From 2016 to 2018 the median Midland Basin well went from
1,474 to 1,855 lb per perforated foot — a 26% jump in two years, the era when every investor
deck had a "bigger fracs" slide. Then the race just… stopped. Since 2018 the median has crept from
1,855 to 2,040 lb/ft — about 10% in seven years, and the preliminary 2026 column sits at
1,996 lb/ft, statistically indistinguishable from 2025 and, if anything, a shade below it. Call it
~2,000 lb/ft: the design equilibrium the basin settled on once the cost-per-barrel math
stopped rewarding more sand.
The movement this week is small and it is honest arithmetic, not news. Two joins have to
land for a column to shift — a perforated interval from the RRC and a proppant mass from FracFocus — and the Sep 5
file added 42 joined wells overall, of which 26 landed in 2026 and
16 in 2025. Eleven pounds off the 2026 median on a 9% larger sample and two pounds onto 2025 is
what a filling-in preliminary year looks like. The equilibrium holds; the 2026 column is simply becoming a real
number rather than an early one.
The sand bill still doubled — but sideways. Median perforated interval went
from 7,642 ft (2016) to 10,508 ft (2025), and median sand per well from 11.8M to
24.6M lb. The growth was laterals, not loading. The 2026 wells joined so far run a median
10,927 ft at the same loading, which is the whole thesis in one line.
Design still isn't monolithic: among 2025–26 completions, Pioneer's
median well takes 30.7M lb (n = 745) against Diamondback's 20.7M (n = 827) — same basin, same benches,
a ten-million-pound difference in what shows up on the pad. That line is computed sand-only, with no perf join.
Method: proppant = disclosed mass of
crystalline silica (CAS 14808-60-7) summed per disclosure; perforated interval = RRC W-2/G-1 perf
span joined by API (2,000–20,000 ft sanity); medians throughout; filings over 100M lb excluded as data errors; a perf span
from a recompletion can differ from the original lateral — a small minority of joins. The joined-well
count is taken after the sand and lateral filters. 2026 reflects wells both frac'd and filed with the
RRC — it will keep drifting as the year fills in, and this week is the first issue in which that drift is
visible.
Weekly frac job count — trailing 13 weeks
By job end date. Faded columns are recent weeks still filling in — operators have up to ~30 days
to file, so the newest weeks always start low and grow. The newest column, the week ending Sep 7, is ZERO, and
that is filing lag rather than a shutdown. The newest job end anywhere in this week's extract is
2026-08-26, so no job ending in the week to Sep 7 has been filed yet by anyone. The bar will fill in over the
next month exactly as the week ending Aug 31 has: it printed 9 this morning against the 1 job that last issue's
newest column showed. Fade rule, stated plainly: a column is faded when any day inside it is less than 42 days
back, i.e. when it is not yet fully inside the settled window. That fades 5 of the 13 columns, the same rule and the
same count as last issue.
113
6/15
82
6/22
91
6/29
54
7/6
93
7/13
63
7/20
68
7/27
66
8/3
41
8/10
61
8/17
39
8/24
9
8/31
0
9/7
TexasNew Mexicostill filing
Permian rig count — 268 +1 wk/wk
Active drilling rigs in the Permian, weekly · latest 2026-09-04 · the basin peaked at
318 rigs in Apr 2024 and has now added one to 268, ending two flat weeks at 267, still
up 30 from the February low of 238 and the highest print since late June 2025, when the count was 270.
Note the wording is unchanged from last week even though the number rose: the rule is tie-inclusive, so 268 does not
set a new anchor — the anchor only moves at 271 · Source: Baker Hughes
Drilling vs completions pace — trailing 30 weeks
Rigs drill the wells; frac crews complete them. Orange is Permian rigs; blue is frac jobs
ended each week from FracFocus. Read the right-hand end of the blue line as unfiled, not idle. The
newest point, 2026-09-04, is 0 frac jobs against 268 rigs — that is not a basin that stopped
completing wells, it is a week nobody has filed for yet (newest job end in the extract: 2026-08-26). The
five newest points are all unsettled — the same 42-day rule that fades 5 of the 13 bars on the
weekly chart above. Judge the blue line from the middle of the series. The gap between the two
lines is the DUC build showing up in real time, and New Mexico's regulator now counts 4,630 drilled-and-waiting
wells, up 117 this week — the largest build we have recorded. The national frac-spread series remains unsourced
this issue. · Sources: Baker Hughes; FracFocus
Permian rigsFrac jobs/week (FracFocus)
Most active operators
Bar & big number = settled pace (wells/28d from jobs ended 42–126 days back);
gray number = jobs filed in the last 28 days. Diamondback holds the top slot at 31.7, but it
sheds ground doing it: that is 6.3 below the 38.0 that last issue's own window recomputes to on this
week's filings, and 5.0 below the 36.7 it printed on the day. Devon is the only large gainer
at 22.7 (+2.7), and the only other riser is COG (ConocoPhillips) at 18.3 (+1.3); the remaining eight are flat or down, which is what a
65-disclosure filing week looks like from the operator side. Four of the top ten filed nothing at all in
the last 28 days — Occidental, Cimarex, Chevron and Apache — and a fifth, Pioneer (ExxonMobil), filed just 2. That is filing lag rather
than idleness; every one of them still holds its settled place. Method note:
operators are shown as filed on the disclosure — no ownership roll-ups — so Pioneer and XTO (both
ExxonMobil), and Cimarex (Coterra, now Devon) appear separately. Operators marked · / ·· file
moderately / slowly, so recent filings alone understate them. EOG is still absent — it filed nothing
this week, so it still reads 1.7/28d and still does not qualify. See the lead story.
Diamondback
31.7
22
XTO (ExxonMobil)
24.0
17
Occidental ·
23.7
0
Devon
22.7
12
COG (ConocoPhillips)
18.3
10
Permian Resources
17.7
5
Pioneer (ExxonMobil)
16.7
2
Cimarex (Coterra/Devon) ·
15.0
0
Chevron ·
11.7
0
Apache
11.0
0
Mewbourne Oil
10.7
0
Matador
10.3
7
Blackbeard Operating ·
8.7
0
Civitas (SM Energy)
8.0
0
Avant Operating II ·
5.7
0
Activity by county
Jobs ended in last 28 days (sums to 109). Martin takes the lead at 24,
up from 8 last issue — the biggest single-county move on the board — and Lea drops to second at 23
from 29. New Mexico takes 32.1% of the basin's filed jobs against
34.7% when last issue's own 28-day window is recomputed on this morning's filings
(52 New Mexico jobs of 150). Last issue printed 40.2% on the day; that gap is filing lag, not a
swing in activity, so the recompute is the comparator to use — as last issue's own correction established.
Midland is still 2, exactly where it was last issue, and has not recovered: the county that led this table
through most of the summer has now printed two jobs twice running. Read that as filing lag as much as activity —
the Midland-basin filers are the slower ones this cycle — but two issues at two is worth watching.
Martin, TX
24
Lea, NM
23
Upton, TX
16
Eddy, NM
11
Glasscock, TX
6
Howard, TX
6
Reeves, TX
6
Crane, TX
5
Andrews, TX
3
Loving, TX
2
Midland, TX
2
Winkler, TX
2
Chaves, NM
1
Ector, TX
1
Kent, TX
1
Completion pipeline — New Mexico (work coming to a pad near you)
From NM OCD well records (queried Sep 8), horizontal wells in Lea / Eddy / Chaves / Roosevelt:
8,489 approved permits not yet spudded (the drilling backlog — includes stale, unexercised permits of
all vintages) and 4,630 wells spudded 2024–2026 still carried as "New" — drilled or drilling with no
completion on record, the OCD's closest thing to a DUC list.
This week the two series break trend in opposite directions, and both breaks are firsts. The permit bank
fell 49 to 8,489 — the first decline in the series we have recorded (the three prior weeks ran
+93, +62, +72). The DUC proxy built 117 to 4,630, the largest weekly build we have recorded (prior weeks
+21, +34, +44), and it is almost all 2026 spuds (999, +62).
Permits are being converted into drilled wells faster than new permits arrive, and the drilled wells are not being
completed. EOG is 32% of that build on its own; EOG and Mewbourne together are 51%.
EOG's unspudded stack fell a third straight week and by the widest margin yet, down 28 to 971, while its
DUC stack rose +37 to 852 — and it filed no completions at all (see the lead story).
Devon's mirror image has softened: it still built, 1,326 → 1,338 on its own filer name (1,442 once WPX Energy Permian rolls in, as the table below does), but at half last
week's pace (+24 → +12), and its DUC stack is no longer flat (408 → 414, +6, on that same filer name;
453 rolled up). Read that second column as the table prints it and Devon is still fifth, behind
Permian Resources at 471 — the +6 does not change its rank. Every well in that second column needs a frac crew and a
drillout. Operators are grouped into display families as in previous issues — Devon includes WPX Energy Permian,
Permian Resources includes Earthstone and Admiral, XTO includes both XTO entities, Occidental the three Oxy
entities, and COG includes ConocoPhillips Company; Marathon Oil Permian is shown on its own line. Otherwise as
filed with the OCD; parentheses note current owners.
Operator
Permits (unspudded)
Spudded '24–'26, awaiting completion
Top county
Devon
1,442
453
Lea
EOG Resources
971
852
Lea
Permian Resources
742
471
Eddy
Mewbourne Oil
577
582
Eddy
Matador
668
349
Lea
Coterra (Cimarex)
681
262
Lea
XTO (ExxonMobil)
306
603
Eddy
Occidental
486
228
Eddy
COG (ConocoPhillips)
550
29
Lea
Chevron
266
276
Eddy
Marathon Oil (ConocoPhillips)
239
26
Lea
Spur Energy Partners
139
115
Eddy
Riley Permian
196
20
Eddy
Civitas (SM Energy)
114
60
Lea
Completion pipeline — Texas permit backlog
The Texas permit numbers in this issue are frozen, and this is the FIFTH issue in a row
that they are. Read nothing at all into their stability. daf804 is a monthly file; the RRC's file list was
re-checked live this morning and still shows exactly one file, last modified 8 Aug 2026, with permits issued
through Aug 7. So this chart, both permit tables below, and the permit columns of the momentum table are
all identical to the Aug 10, Aug 17, Aug 24 and Aug 31 issues by construction — not because permitting
stopped, and not because anything was measured. A permit arrow anywhere in this issue is now a month old and
getting older, and no comparison drawn from these tables is a comparison with this week.
It also has a compounding second-order effect: the county map book runs on a trailing-365-day window, and because
that window advances weekly against a static file, the map point count has now fallen for four straight issues,
3,961 → 3,891 → 3,831 → 3,775 — 56 permits aged out this week and none arrived. That shrinkage is an artifact of the frozen
file, not a collapse in Texas permitting, and it will keep happening every week until the file moves.
4,782 permits issued Aug 2025 – Aug 7, 2026
in the Permian counties, 4,097 of them horizontal (85.7%). July is a complete month at 396 permits;
August is partial — the file runs only through Aug 7, so the last column is a stub, not a cliff.
Permits lead the frac by six to twelve months.
308
8/25
371
9/25
475
10/25
236
11/25
305
12/25
491
1/26
327
2/26
422
3/26
473
4/26
468
5/26
408
6/26
396
7/26
102
8/26
Permit holders — trailing 12 months
Permits issued Aug 2025 – Aug 7, 2026 by operator, resolved from the P-5 number by API join
to FracFocus filings (93.62% coverage, 4,477 of 4,782; the remaining 305 are small P-5 numbers with no
FracFocus history and are shown as "Unknown"). Anadarko-numbered permits are counted under Occidental.
Same Aug 8 file as the last four issues, so every count below is unchanged — the operator-name vote was
re-run against this week's fresher FracFocus and moved twenty-two P-5 numbers, only two of which carry any
in-window permit at all (two permits each: RK → Beach, and Canan Mowrey → Three Summits). No row of the
underlying top-40 table moves; the unresolved bucket shrinks from 309 to 305 as the fresher vote names four more.
Operator
Permits
Pioneer (ExxonMobil)
588
Occidental
508
Diamondback
480
Unknown
305
COG (ConocoPhillips)
198
Permian Resources
164
Ovintiv
157
Apache
148
Continental Resources
127
Double Eagle (DE Central)
127
Blackbeard Operating
124
Kinder Morgan
100
Permit counties — trailing 12 months
Same window and the same Aug 8 file, so these are last issue's counts to the
permit — and the three issues before that. Midland still leads, but the Delaware side
(Loving, Reeves) carries as many permits between two counties as the Midland Basin core does. Nothing here has
been measured since Aug 7.
County
Permits
Midland
626
Loving
485
Upton
482
Reeves
459
Martin
441
Glasscock
267
Reagan
253
Andrews
229
Crane
177
Ector
177
Gaines
175
Howard
151
Smaller operators to watch
Everyone outside the top-10 settled list with 3+ completions since March 29 —
the private and mid-cap programs that buy sand, water, and services every month without making headlines.
The window is the anchor date minus 163 days, which is the same offset the last four issues used.
Large independents (Mewbourne, Civitas, Matador, Ovintiv, Continental) are excluded regardless of count, and so
is EOG, which would otherwise walk into this table as a "smaller operator" on a settled pace of 1.7 —
which it plainly is not.
Green dates = a job ended inside the last ~30 days,
i.e. a crew was just there. Service co. from supplier records where identifiable.
Operator
Jobs (5 mo)
Top counties
Service co. (ID'd)
Median water (bbl)
Newest job
Blackbeard Operating
29
Crane TX
—
119,000
2026-07-23
FireBird Energy II
27
Upton TX, Ector TX
—
485,000
2026-08-24
VTX Energy
21
Reeves TX
NexTier (Patterson-UTI)
637,000
2026-08-26
Spur Energy Partners
20
Eddy NM, Lea NM
Halliburton
281,000
2026-08-04
Fasken Oil and Ranch
20
Andrews TX, Midland TX
—
507,000
2026-08-12
HighPeak Energy
20
Howard TX, Borden TX
Liberty, ProFrac
480,000
2026-07-03
Triple Crown Resources
19
Irion TX, Upton TX
—
576,000
2026-08-25
BPX
19
Reeves TX, Loving TX
Halliburton, NexTier (Patterson-UTI)
497,000
2026-05-30
Surge Energy
18
Howard TX, Borden TX
NexTier (Patterson-UTI)
416,000
2026-08-11
Avant Operating II
17
Lea NM
Liberty
341,000
2026-07-17
TRP Operating
15
Loving TX
—
542,000
2026-07-09
BTA Oil Producers
13
Crane TX, Lea NM
FTS International
716,000
2026-08-12
Summit Petroleum
12
Upton TX
FTS International
786,000
2026-05-25
Basin Oil and Gas
12
Winkler TX, Ector TX
—
4,000
2026-08-17
Blue Arrow
12
Reeves TX, Pecos TX
—
631,000
2026-07-13
Double Eagle (DE Central)
12
Glasscock TX, Reagan TX
Halliburton, NexTier (Patterson-UTI)
559,000
2026-05-07
Read the Basin Oil and Gas row with suspicion.
Its median disclosed water is 4,064 bbl across 12 jobs; every other row in this table runs between
about 119,000 and 786,000 bbl, and the two rows immediately either side of it are 786,000 and 631,000. That is two
orders of magnitude below anything that could be a modern Permian frac, and on the order
of a fraction of a barrel per lateral foot. These disclosures are almost certainly not describing full stimulation
jobs (a recompletion, a partial filing, or a units error are all likelier than a 4,000-bbl frac). The row is left in
rather than quietly dropped, but it should not be read as a completions programme. The same operator supplies the
top of the fleets-on-location table below, which carries the same caveat.
Completion intensity by operator
Median job design over each operator's trailing 12 months · operators with
≥8 jobs and a disclosure inside the last 6 months, sorted by median sand · sand in millions of lbs, water in thousands of bbl ·
the lateral and lb/ft columns stay blank again this issue. The join was re-checked against the fresh
Sep 5 RRC dbf900 and it is still too thin and too biased to print: median perforated-interval coverage across the
18 rows below is 36.1% (43.7% job-weighted), 3 rows sit under 25%, and among the basin's
biggest programmes XTO joins on 1.3% of its jobs (4 of 309). The wells that do join are the ones whose
operators file promptly, and they skew high: the values that would have printed run 2,070–2,986 lb/ft. That range is
not like-for-like with the 1,996 lb/ft in the sand-per-foot special above — 1,996 is the 2026-to-date,
preliminary, nine-county Midland-Basin median from that card, while these are trailing-12-month, basin-wide,
per-operator medians. Printing them would say more about paperwork than about design. They are retained in the
build data if anyone wants to argue the point. The basin-wide perf join is shown properly in the sand-per-foot
special above, where the history is deep enough to be honest.
One calibration warning about the top of this table. The rows are sorted by median sand, so the least
calibrated rows come first: Petroplex Energy leads on 20 jobs, and without the suppressed per-foot column there is
nothing on the page to say whether a big median sand number is a big frac or simply a long lateral — or, at the
top of the table, a small sample. Treat the first few rows as small-n and uncalibrated until the lb/ft column
can be printed.
Operator
Jobs
Median sand (M lbs)
Median water (k bbl)
Median lateral (ft)
Sand (lbs/ft)
Petroplex Energy
20
38.9
744
—
—
SM Energy
16
36.0
871
—
—
Discovery Natural Resources
15
35.1
1206
—
—
Black Swan
11
34.1
786
—
—
RP Operating
10
33.7
1042
—
—
PBEX Operations
14
31.3
696
—
—
Continental Resources
40
30.5
763
—
—
HighPeak Energy
43
29.8
502
—
—
Pioneer (ExxonMobil)
415
29.6
647
—
—
BTA Oil Producers
39
29.1
618
—
—
Summit Petroleum
31
28.7
547
—
—
Sabalo II Operating
11
28.1
514
—
—
XTO (ExxonMobil)
309
27.2
531
—
—
Blue Arrow
24
27.1
631
—
—
Tap Rock
18
27.1
602
—
—
Double Eagle (DE Central)
67
26.2
587
—
—
VTX Energy
31
25.5
638
—
—
Occidental
403
25.3
467
—
—
Water & sand by well depth (TVD)
Trailing 12 months, both states, by disclosed true vertical depth. The shallow band is a
different business — a third of the sand and just over half the water of every deeper band. Below that line the
design is remarkably flat: from 7,000 ft to past 12,000 ft the median job barely moves, which is the
lateral-length story again rather than a depth story. Four of the five bands move by 16 jobs or fewer as
the 12-month window rolls; the exception is 10,500 - 12,000, which is down 32 (866 → 834).
And the New Mexico share of the deep bands is not moving in one direction, so this issue does not claim it is:
9,000 - 10,500 34.06% → 34.09%; 10,500 - 12,000 49.54% → 49.64%; over 12,000 ft 62.85% → 62.19% — two of the three up by 0.03 and 0.10 of a percentage point, the deepest band down 0.66. That is noise at this
sample size, not a trend. The Lea/Eddy concentration the county table shows is real; this table is not where you
can watch it move.
TVD band
Jobs
Median water (bbl)
Median proppant (lbs)
of which NM
under 7,000 ft
365
284,000
7,694,000
83
7,000 - 9,000
1,610
516,000
23,468,000
329
9,000 - 10,500
1,640
532,000
25,211,000
559
10,500 - 12,000
834
512,000
24,546,000
414
over 12,000 ft
320
532,000
24,696,000
199
Water & sand by target formation — Texas
Texas jobs ended in the trailing 12 months (3,185), formation from the RRC wellbore join —
1,933 named (60.7%).
One method change this issue, and it is honest to report that it did nothing. A non-empty-name gate
was added to the RRC formation join: the join takes the deepest filed bench record on the wellbore, and the
wellbore file contains 266 roots whose deepest record carries a blank formation name, 184 of them with a positive
filed depth — which means they would clear the existing depth gate and be counted as "named" while bucketing to
nothing at all. The gate is correct and it ships. Its effect on this table is exactly zero: none of the
3,185 trailing-12-month Texas jobs lands on one of those roots, and every row below is identical with and
without it. All the row movement this week is data — the window rolling and the fresh Sep 5 wellbore file — not
method. The depth > 0 gate introduced last issue still applies (127 of the 2,193 joinable jobs are excluded
by it), as do last issue's San Angelo and Delaware Mtn bucket changes.
Rows with fewer than 10 named jobs are dropped, which this cycle removes Grayburg (8), Strawn (7), Barnett (4), Penn (4).
Strawn and Penn still cannot be reproduced at their historic values. The Aug 17 issue printed a Strawn row of
38 and the Aug 24 issue a Penn row of 20; this window contains 7 disclosures whose deepest RRC bench string
contains "STRAWN" — 7 with the depth gate lifted, i.e. unchanged — and 4 Pennsylvanian-aged strings
(5 before the depth gate). Both fall to the
under-10 rule again, and those earlier figures should be read as artifacts of those builds.
The 12-month window is the honest unit for this join: the RRC completion filing trails the frac by months, so a
28-day window could name only 6 of 51 jobs when it was tried. New Mexico is excluded (the OCD pool join was not
refreshed this cycle). lb/ft is the median of per-well sand ÷ perf span with a 2,000–20,000 ft gate, and
prints "—" where fewer than 10 wells in the row carry a perf record. Because the RRC filing trails the frac,
the named rows still skew toward operators that file promptly.
Formation
Jobs
Median water (bbl)
Median proppant (lbs)
Sand (lbs/ft)
Spraberry
772
549,000
24,625,000
2,001
Wolfcamp
629
560,000
24,352,000
2,258
Bone Spring
224
496,000
24,733,000
2,492
Dean
114
589,000
26,981,000
2,182
Clear Fork
100
491,000
17,632,000
1,694
Delaware Mtn
38
652,000
24,487,000
2,404
San Andres
23
507,000
23,132,000
2,245
Queen
10
695,000
29,339,000
—
Current conditions — fleets likely on location (inferred)
The rule, in full, because it matters more than the number: a pad is an operator plus a
surface location rounded to two decimal places of latitude and longitude (about a 1 km grid); a pad counts as
"likely on location" when its latest job end is within 1.5× that pad's own median gap between job end
dates. There is no minimum-days floor, and the count is not rounded to any floor either.
On that rule 75 pads pass this issue, against the 76 last issue published; recompute last issue's
window on this week's fuller data and the same rule still returns 76, so the fall to 75 is one real pad, not a
rule change and not late filing.
Now the honest part, and read it before you read the table. 36 of those 75 pads have a median
inter-job gap of more than a year, so on a strict reading of the rule they "pass" on a job-end date that is
itself months old. The freshest of them this week is a COG pad in Eddy County whose own median gap is
1,462 days. The table below is therefore drawn from the safer list — the 39 pads whose median gap is
under a year — while the 75 headline above refers to the full no-floor list. Those are two different lists and
the difference is 36 pads; read the "pad gap" column before you read the status either way.
Several large operators batch-date a whole pad's wells to one end date, which zeroes their measured gap and
drops them out of the green list entirely — so this view skews toward smaller, steadier programs. Disclosures lag
the frac by up to 30 days; treat this as a floor and a lead list, not a map. The "recently released" rows are the
freshest pads whose own cadence says the crew has moved on — and the EOG pad in Lea County, 25 wells, last job end
Aug 24, is still sitting there a week later with nothing new filed behind it.
Status
Operator
Service co.
County
Wells so far
Pad gap (d)
Last job end
🟢 Likely on location
Basin Oil and Gas
—
Winkler, TX
7
156
Aug 17
🟢 Likely on location
Basin Oil and Gas
—
Winkler, TX
5
189
Aug 13
🟢 Likely on location
Ring Energy
—
Ector, TX
4
30
Aug 11
🟢 Likely on location
Surge Energy
NexTier (Patterson-UTI)
Howard, TX
6
155
Aug 11
🟢 Likely on location
Basin Oil and Gas
—
Winkler, TX
8
89
Aug 10
🟢 Likely on location
Surge Energy
NexTier (Patterson-UTI)
Howard, TX
8
92
Jul 31
🟢 Likely on location
Burnett Oil
—
Eddy, NM
15
77
Jul 25
🟢 Likely on location
Blackbeard Operating
—
Crane, TX
6
105
Jul 23
🟢 Likely on location
Burnett Oil
—
Eddy, NM
6
204
Jul 22
🟢 Likely on location
Strata
—
Eddy, NM
2
165
Jul 18
⚪ Recently released
VTX Energy
—
Reeves, TX
5
0
Aug 26
⚪ Recently released
Pioneer (ExxonMobil)
Halliburton, NexTier (Patterson-UTI)
Midland, TX
26
0
Aug 25
⚪ Recently released
Triple Crown Resources
—
Upton, TX
4
0
Aug 25
⚪ Recently released
EOG
—
Lea, NM
25
1
Aug 24
⚪ Recently released
FireBird Energy II
—
Upton, TX
6
0
Aug 24
And read the top of the green list with the same
suspicion as the smaller-operators table above. The first two rows, and a third just below them, are all
Basin Oil and Gas pads in Winkler County, and Basin's disclosures carry a median water volume of about
4,000 bbl per job — two orders of magnitude below a Permian frac. Whatever those filings describe, it is probably
not a frac crew on location. The rows are shown rather than dropped, because the rule put them there and hiding
them would hide the weakness; but the head of this list is the least trustworthy part of it, and the rule keys on
filing cadence, not on job size.
Frac service companies — who's pumping for whom
Pressure pumper identified on 61.1% of the last 12 months' jobs
(2,916 of 4,769) —
from FracFocus supplier records directly, plus same-pad propagation (a labeled sibling well within the pad
names the crew, matched on a 3-decimal-place pad grid over the full disclosure history). Coverage is
flat like-for-like against last issue's 61.0%: the name list did not change this week, so the
movement is jobs rolling through the 12-month window, not method. ProFrac and FTS International are shown
separately, as published — the raw matcher folds FTSI and the old U.S. Well Services spelling into ProFrac,
and splitting them back out gives ProFrac 277 and FTS International 81.
KLX is deliberately excluded: it is coil and wireline work, not a frac fleet. The rows below sum to
3,022 against 2,916 identified jobs, because 106 jobs name more than one pumper and are counted
under each — the same disclosure the last four issues carried.
"Not identified" jobs are genuinely unlabeled in public data — largely self-sourcing operators and ProPetro's
current work — so shares are a floor, not a census.
Service co.
Jobs (12 mo)
Halliburton
1,291
NexTier (Patterson-UTI)
706
Liberty
589
ProFrac
277
FTS International
81
BJ Energy Solutions
43
SLB
35
Not identified
1,853
Implied frac fleets & drillout demand
Transparent math, two assumptions: a frac fleet turns ~5.6 wells per 28 days
(the basin-average throughput calibrated in the July issue: 398 wells ↔ 71 fleet-equivalents), and a
coil/workover unit drills out ~6 wells per month. Fleet-equivalents = settled wells/28d ÷ 5.6;
drillout units = wells/28d ÷ 6. Method note: too many operators batch-date pad filings for per-pad
cadence to be reliable, so a single basin-average throughput is used — simul-frac heavy operators'
true crew counts run lower than shown, and slower programs' higher. Basin total on this basis:
308.0 wells/28d ≈ 55 fleet-equivalents and ≈ 51 drillout units kept busy, down from
58 / 54 last issue. The pace eased 14.3 against the 322.3 we printed then
(down 4.4%), and 17.7 against the 325.7 that the same window recomputes to on this
week's filings — and this week that easing is mostly a thin filing week, not a thinner basin. Every figure
here understates EOG, which is not on the settled list at all.
Operator
Wells / 28d (settled)
Implied fleet-equiv.
Implied drillout units
Diamondback
31.7
5.7
5.3
XTO (ExxonMobil)
24.0
4.3
4.0
Occidental
23.7
4.2
3.9
Devon
22.7
4.1
3.8
COG (ConocoPhillips)
18.3
3.3
3.1
Permian Resources
17.7
3.2
2.9
Pioneer (ExxonMobil)
16.7
3.0
2.8
Cimarex (Coterra/Devon)
15.0
2.7
2.5
Chevron
11.7
2.1
1.9
Apache
11.0
2.0
1.8
Mewbourne Oil
10.7
1.9
1.8
Matador
10.3
1.8
1.7
Blackbeard Operating
8.7
1.6
1.4
Civitas (SM Energy)
8.0
1.4
1.3
Avant Operating II
5.7
1.0
1.0
Estimated completion spend — run-rate per 28 days
A rebuilt, per-lateral-foot model of what a Permian completion costs and what the basin
spends at its current pace. Four foot-priced service lines, proppant and water passed through at disclosed
volumes, three flat per-well lines. It runs on the settled window — jobs whose end date is 42–126
days back, 924 of them (329 New Mexico / 595 Texas) between 2026-05-06 and 2026-07-28 —
not the 28-day tile at the top of the issue. The settled window is the only population on which a per-28-day
total is comparable week to week; the tile is a floor that grows for a month after publication.
Per median settled well
$4,227,113
median settled job: 24,688,616 lb sand (n = 792), 519,455 bbl water, 79.5% produced/recycled by volume
Per completed lateral foot
$407.59
on a median lateral of 10,371 ft · completion only, no drilling
Basin, per 28 days
$1.302B
= the per-well figure × the settled pace of 308.0 jobs/28d
Line
Basis
Rate
$ on the median well
% of well
Pumping spread & stimulation service
$ / lateral ft
$125
$1,296,375
30.7%
Wireline, plugs & pumpdown
$ / lateral ft
$50
$518,550
12.3%
Chemicals & additives
$ / lateral ft
$20
$207,420
4.9%
Site, rentals, supervision, fuel & other
$ / lateral ft
$30
$311,130
7.4%
Proppant delivered
$ / lb
$0.016
$395,018
9.3%
Produced / recycled water
$ / bbl × 79.5% of the barrels
$0.50
$206,483
4.9%
Fresh water
$ / bbl × the remaining 20.5%
$1.10
$117,137
2.8%
Drillout — coil or workover rig
$ / well
$350,000
$350,000
8.3%
Flowback & early production
$ / well
$225,000
$225,000
5.3%
Tubing, wellhead & surface facilities
$ / well
$600,000
$600,000
14.2%
The lateral distribution is bimodal, so the median understates the
basin. On the 4,091-well 2025–early-2026 perf cohort, 38% of laterals land in the 10,000–11,000 ft
two-mile band and 14% in the 15,000–16,000 ft three-mile band — so pricing "the median well" prices
neither of the two things the basin actually drills, and roughly one job in seven is a three-miler the
median hides. Those three shape figures are the only numbers in this card not re-derived this week: they come
from the Texas perf cohort measured for this model's Sep 2 build — job ends Jan 2025 – Feb 2026,
read off the Sep 1 FracFocus extract and the Aug 29 RRC wellbore file — and they are carried unchanged because the shape of the distribution moves far more
slowly than the window does.
The band below is the honest read: the same rate card run at the 25th, 50th and 75th percentile lateral. Note
that $/ft falls as the lateral grows, because $1,175,000 of the well is flat per-well cost that does not
scale with length.
Case
Lateral (ft)
Cost per well
$ per lateral ft
p25 - short 2-mile
10,046
$4,153,988
$413.50
p50 - median
10,371
$4,227,113
$407.59
p75 - 3-mile
13,621
$4,958,363
$364.02
Where the lateral comes from, stated honestly, because it is the
largest weakness in the number. There is no direct lateral for a job in the settled window: the RRC perf
records that carry it land four to eight months after the frac, and only 0.6% of settled-window jobs join
one at all. The model therefore uses a lagged cohort — Texas jobs whose end date is 365 to 180 days before
the issue date (2025-09-07 to 2026-03-11), where the perf join reaches 76.2% of Texas jobs and
n = 1,451. Two consequences, both real: the lateral is Texas-only (dbf900 is an RRC file and New
Mexico never joins it, while New Mexico is a third of every window), and it describes wells completed six to
twelve months earlier than the ones being priced. It is a stable, slow-moving distribution, which is why it is
usable at all — but it is not this quarter's laterals.
Sanity check, and it is a standing rule here. Divide any well
cost by its lateral and compare it to what operators guide to. This model is $408/ft for the completion
alone; add roughly $300/ft of drilling and it implies ≈$708/ft all-in, against
public Permian D&C guidance of $675–$1,035/ft (Permian Resources $675–$685, Civitas Midland $685,
Matador $835–$855, Civitas Delaware $880, Delaware peer range $775–$1,035). It sits at the bottom of
that band, which is where a completion-only number rebuilt from first principles should sit. A completion-only
figure that exceeds an all-in figure is the tell that something is wrong — that is exactly what caught the
previous version of this model, which read about $980/ft for the completion alone.
⚠ Three of the ten rates are proposals, not
operator-supplied numbers, and they are the three flat lines.Drillout — coil or workover rig
($350,000/well), flowback & early production ($225,000/well) and tubing, wellhead & surface
facilities ($600,000/well) together are $1,175,000, or 27.8% of the modelled well. They came from this
newsletter, not from an operator or a service company. The drillout figure is practitioner-endorsed — it is our
own discipline — but flowback and facilities remain open, and facilities may be a scope question rather than a
rate question: Civitas quotes drilling, completion and facilities per foot, while Permian Resources books
facilities and infrastructure outside D&C entirely. Take facilities out of scope and the well is $3.63M at
$350/ft; take flowback out too and it is $3.40M at $328/ft. The six volume-priced lines are better grounded and
are benchmarked against the guidance band above, but they are proposals as well. Every figure in this card moves
when those rates do. Estimates for market intelligence, not invoices.
What the wells actually made — IP90 after the frac
Nothing in this section moved, and this issue can say exactly
why. The whole pipeline was rebuilt from scratch again rather than carried forward, and it reproduced every
published number exactly: all 3,357 Texas wells and all 2,843 New Mexico wells came back with identical oil and
gas volumes — zero missing, zero extra, zero mismatched. Two things had to be true for that to happen and both
are: the Texas production file is frozen, so there are no new production months for any well, and the
two new Texas cohort wells the fresh FracFocus added both sit on multi-well leases and are excluded by the
single-well-lease rule. A no-change result is the expected outcome here, not a suspicious one.
Both production vintages are stale, one is past our own refresh
rule for a second week, and this week we could not even confirm its vintage. The Texas side runs on the RRC
Production Data Query dump of Jul 26 — 44 days, 6.3 weeks old, past the five-week rule this newsletter set
itself, for the second consecutive issue. Worse than last week: the RRC file-transfer server
aborts the TLS handshake outright from our host — it returns zero bytes and no certificate — so the PDQ
vintage could not be listed, let alone downloaded, and MFT is the only channel the RRC publishes it through.
(The RRC's GIS and web servers answered normally throughout, so this is that one server or an address-level
block, not an outage.) The New Mexico side runs on OCD C-115 well-level volumes scraped on Aug 5 — now 34
days stale, because the OCD production route sits behind a Cloudflare human-verification gate; re-probed this
morning, and the cookie jar comes back empty, so no retry strategy can clear it. Treat every figure below as a
July-vintage read.
Wells frac'd July 2024 – Feb 2026, 6,200 with a clean 90-day production window
(2,843 New Mexico + 3,357 Texas). New Mexico: true well-level oil volumes from OCD C-115 filings. Texas:
oil + condensate from RRC lease-level filings, restricted to single-well leases — leases carrying exactly one
wellbore on the proration schedule, so lease volumes are well volumes with no pad allocation; that keeps 3,357 of
6,703 TX cohort wells (50%; the rest sit on multi-well leases). Where a well touches more than one single-well
lease, the lease with the largest windowed oil volume is used. All three months of a well's window must carry
a filed row; wells with production predating the frac (refracs, legacy leases) are excluded.
IP90 = oil over the first three reported production months ÷ 90 days. Median across all 6,200
wells: 692 bopd (NM 762, TX 638); median gas 1,250 mcfd.
Formation
Wells
Median IP90 (bopd/well)
bopd per 1,000 ft
Wolfcamp
2390
690
65
Bone Spring
2053
768
63
Spraberry
1209
639
52
Dean
175
726
55
Clear Fork
137
561
50
Barnett
73
602
62
Delaware Mtn
35
576
—
Yeso
35
225
—
San Andres
25
170
21
Penn
17
298
—
Strawn
12
536
51
Queen
11
438
42
Other / unreported
28
374
26
Operator
Wells
Median IP90 (bopd/well)
ExxonMobil (Pioneer/XTO)
1191
700
Devon (incl. Coterra)
622
895
EOG Resources
542
857
Mewbourne Oil
509
625
Occidental
413
997
Permian Resources
364
672
Diamondback
339
745
Chevron
301
611
ConocoPhillips (COG)
258
759
Matador Production
236
622
Per-1,000-ft columns are Texas-weighted: laterals come
from the RRC perf join (3,255 TX wells) and from OCD completion reports for only 62 NM wells, so a dash
means the lateral sample was under 10. These laterals are deliberately held at the Aug 15 wellbore file, not
the fresh Sep 5 one. Refreshing the perf half alone would be clean — it fills 42 blanks and moves exactly one
printed cell — but the formation half would not be: 125 of the 1,911 Spraberry (Trend Area) wells would flip
bucket on the new file, and the published mapping is not reproducible one-to-one against it. Refreshing one half
and not the other would mix bases, so both are held until that rule is pinned down.
Operator rows here use ownership roll-ups (unlike the rest of the issue)
because the production files are keyed to current operatorship. Note that EOG sits third on this table at 542
wells and 857 bopd — its production filings never went dark even while its FracFocus paperwork did, and its
paperwork has gone quiet again this week.
Who's ramping, who's easing off
Three signals per operator: settled pace (wells/28d, jobs ended 42–126 days back)
against its own prior three-month window (126–210 days back); TX permits issued in the
trailing 8 weeks (Jun 13 – Aug 7) against the prior 8 weeks (intent — leads the frac 6–12 months; arrows
at ±20%); and jobs filed in the last 28 days as a share of settled pace (a filing-freshness read,
not a slowdown detector — slow filers run low here every issue). The universe is every operator on the
settled-pace list above, i.e. 5.5 wells/28d or better.
⚠ The permit column is frozen for a fifth issue and is not comparable to anything. The RRC permit
file is monthly and still ends Aug 7, so every permit arrow in this table is now a month old and is identical to
the arrow printed in the Aug 10, Aug 17, Aug 24 and Aug 31 issues. It is not a measurement of this week.
Read movement in the first column only — and read it against a filing week in which only 65 new
disclosures arrived. Hover a row for the figures.
The "Reads as" rule is unchanged from last issue (a filer is current only when its filing-currency flag
reads current AND its filed share is at least 40% of settled pace), so this column is row-comparable to
last issue but still not to the Aug 24 issue and earlier, which used a filed-share threshold alone.
Operator
Settled pace /28d
TX permits
Filed last 28d
Reads as
Diamondback
▼ 31.7vs 43.7 prior 3 mo
▼ 288 wk to Aug 7 · vs 79 prior 8 wk
22 (69%)
genuinely easing — filings are current, so the drop is real
XTO (ExxonMobil)
· 24.0vs 29.3 prior 3 mo
—no TX permits in either window
17 (71%)
holding pace, and filings are current
Occidental
▼ 23.7vs 41.7 prior 3 mo
▼ 428 wk to Aug 7 · vs 102 prior 8 wk
0 (0%)
off on paper, and filing slowly — likely lag as much as a real slowdown
Devon
▲ 22.7vs 17.7 prior 3 mo
—no TX permits in either window
12 (53%)
pace up on settled filings; permit intake not following yet
COG (ConocoPhillips)
· 18.3vs 20.3 prior 3 mo
▲ 518 wk to Aug 7 · vs 29 prior 8 wk
10 (55%)
holding pace, and filings are current
Permian Resources
▼ 17.7vs 23.3 prior 3 mo
▼ 168 wk to Aug 7 · vs 44 prior 8 wk
5 (28%)
off on paper, and filing slowly — likely lag as much as a real slowdown
Pioneer (ExxonMobil)
▼ 16.7vs 34.3 prior 3 mo
· 1088 wk to Aug 7 · vs 112 prior 8 wk
2 (12%)
off on paper, and filing slowly — likely lag as much as a real slowdown
Cimarex (Coterra/Devon)
· 15.0vs 16.7 prior 3 mo
▼ 08 wk to Aug 7 · vs 22 prior 8 wk
0 (0%)
holding pace; a slow filer, so recent weeks understate it
Chevron
· 11.7vs 11.3 prior 3 mo
▲ 188 wk to Aug 7 · vs 4 prior 8 wk
0 (0%)
holding pace; a slow filer, so recent weeks understate it
Apache
▼ 11.0vs 16.0 prior 3 mo
▼ 188 wk to Aug 7 · vs 33 prior 8 wk
0 (0%)
off on paper, and filing slowly — likely lag as much as a real slowdown
Mewbourne Oil
▼ 10.7vs 20.3 prior 3 mo
▲ 188 wk to Aug 7 · vs 7 prior 8 wk
0 (0%)
off on paper, and filing slowly — likely lag as much as a real slowdown
Matador
· 10.3vs 9.3 prior 3 mo
—no TX permits in either window
7 (68%)
holding pace, and filings are current
Blackbeard Operating
▲ 8.7vs 2.7 prior 3 mo
▼ 118 wk to Aug 7 · vs 36 prior 8 wk
0 (0%)
pace up on settled filings; permit intake not following yet
Civitas (SM Energy)
▼ 8.0vs 11.7 prior 3 mo
▼ 58 wk to Aug 7 · vs 9 prior 8 wk
0 (0%)
off on paper, and filing slowly — likely lag as much as a real slowdown
Avant Operating II
▲ 5.7vs 0.0 prior 3 mo
—no TX permits in either window
0 (0%)
pace up on settled filings; permit intake not following yet
How current is each operator's paperwork?
Every operator with 8+ Permian disclosures in the trailing 18 months, sorted
worst-first by how old its newest job-end date is. FracFocus has no enforced filing deadline, so this
is a paperwork-currency table, not an activity table — a dark filer can be busy and a current filer can be
idle. Late batches arrive constantly and revise settled pace upward afterward, which is why the lead
recomputes last issue's window every week.
Red = newest job over 120 days old (dark);
amber = 42–120 days (slow);
green = inside 42 days (current).
Split this issue: 22 dark / 22 slow / 25 current across 69 rows, against
last issue's 19 / 22 / 26 across 67. That drift is the calendar, not a filing collapse. Two operators
(Hilcorp Energy and Circle-S Energy) newly cleared the 8-disclosure bar, and three — Double Eagle (DE Central),
Ovintiv and Discovery — crossed the 120-day line simply because the anchor advanced seven days and they filed
nothing. Blackbeard, Burnett and Occidental drifted the other way, green to amber, for the same reason. Only
Triple Crown genuinely moved on filings, 70 days to 14. No operator went from filing to not filing.
Operator
Newest job on file
Filed last 28d
Settled pace /28d
Disclosures, 18 mo
OxyRock
2025-08-28 (376d)
0
0.0
89
Rockport Energy Solutions
2025-10-10 (333d)
0
0.0
9
Fourpoint Energy
2025-11-19 (293d)
0
0.0
13
Iron Orchard
2025-12-09 (273d)
0
0.0
8
Upcurve Energy
2025-12-26 (256d)
0
0.0
17
Vital Energy
2026-01-16 (235d)
0
0.0
20
IKE
2026-01-16 (235d)
0
0.0
21
Unitex
2026-02-05 (215d)
0
0.0
8
Hannathon
2026-02-16 (204d)
0
0.0
18
Paloma Permian Assetco
2026-02-25 (195d)
0
0.0
22
Hibernia Resources IV
2026-03-02 (190d)
0
0.0
26
Petro Hunt L L C
2026-03-25 (167d)
0
0.0
56
Marathon
2026-04-04 (157d)
0
0.0
11
Dallas
2026-04-08 (153d)
0
0.0
9
SM Energy
2026-04-12 (149d)
0
0.0
61
Manti Tarka Permian
2026-04-22 (139d)
0
0.0
14
Petroplex Energy
2026-04-26 (135d)
0
0.0
20
Black Swan
2026-04-27 (134d)
0
0.0
27
Kaiser-Francis
2026-05-01 (130d)
0
0.0
15
Double Eagle (DE Central)
2026-05-07 (124d)
0
2.0
116
Ovintiv
2026-05-08 (123d)
0
1.0
89
Discovery Natural Resources
2026-05-09 (122d)
0
1.3
33
PBEX Operations
2026-05-12 (119d)
0
1.0
14
Summit Petroleum
2026-05-25 (106d)
0
1.0
58
Tap Rock
2026-05-30 (101d)
0
0.7
24
BPX
2026-05-30 (101d)
0
3.0
90
Sabalo II Operating
2026-06-15 (85d)
0
2.3
23
3R
2026-06-21 (79d)
0
1.7
24
Crescent Energy
2026-06-22 (78d)
0
1.3
13
Jetta
2026-06-25 (75d)
0
2.3
9
Permian Deep Rock
2026-06-27 (73d)
0
1.7
25
HighPeak Energy
2026-07-03 (67d)
0
5.0
70
TRP Operating
2026-07-09 (61d)
0
3.0
28
RP Operating
2026-07-10 (60d)
0
1.3
10
Cimarex (Coterra/Devon)
2026-07-11 (59d)
0
15.0
301
Chevron
2026-07-13 (57d)
0
11.7
295
Blue Arrow
2026-07-13 (57d)
0
2.7
28
Avant Operating II
2026-07-17 (53d)
0
5.7
17
Strata
2026-07-18 (52d)
0
2.3
23
Greenlake Energy
2026-07-19 (51d)
0
0.3
30
Blackbeard Operating
2026-07-23 (47d)
0
8.7
144
Hilcorp Energy
2026-07-23 (47d)
0
2.3
9
Burnett Oil
2026-07-25 (45d)
0
0.7
13
Occidental
2026-07-26 (44d)
0
23.7
578
Apache
2026-07-31 (39d)
0
11.0
236
Civitas (SM Energy)
2026-07-31 (39d)
0
8.0
161
Continental Resources
2026-08-01 (38d)
0
0.0
89
Spur Energy Partners
2026-08-04 (35d)
0
5.3
54
Mewbourne Oil
2026-08-05 (34d)
0
10.7
394
SEM
2026-08-07 (32d)
0
1.3
21
Surge Energy
2026-08-11 (28d)
2
1.7
79
Circle-s Energy
2026-08-11 (28d)
2
0.0
9
BTA Oil Producers
2026-08-12 (27d)
2
2.3
55
Fasken Oil and Ranch
2026-08-12 (27d)
2
4.7
81
Devon
2026-08-14 (25d)
12
22.7
328
Basin Oil and Gas
2026-08-17 (22d)
2
2.0
54
COG (ConocoPhillips)
2026-08-18 (21d)
10
18.3
406
Permian Resources
2026-08-18 (21d)
5
17.7
388
Mack
2026-08-18 (21d)
1
1.3
9
Diamondback
2026-08-22 (17d)
22
31.7
763
Ring Energy
2026-08-22 (17d)
5
1.7
24
Bayswater
2026-08-22 (17d)
4
0.0
34
XTO (ExxonMobil)
2026-08-24 (15d)
17
24.0
476
EOG
2026-08-24 (15d)
5
1.7
322
FireBird Energy II
2026-08-24 (15d)
2
3.0
99
Pioneer (ExxonMobil)
2026-08-25 (14d)
2
16.7
714
Matador
2026-08-25 (14d)
7
10.3
203
Triple Crown Resources
2026-08-25 (14d)
3
2.7
66
VTX Energy
2026-08-26 (13d)
3
2.7
42
The EOG line, one week on. Last issue this table
reported EOG moving from the red band to the green one in a single step and said its settled pace would follow.
It has not. EOG filed zero disclosures this week; its newest job end is still 2026-08-24, which has
simply aged to 15 days; its settled pace is still 1.7; and its filed-last-28 count fell from 10 to
5 only because the 28-day window rolled forward off its Aug 4, 5 and 10 jobs — no July job was ever
inside it. It is still flagged current, because that flag
measures the age of the newest filing and nothing else — which is precisely the limitation this table has always
carried, now demonstrated on the largest filer in the basin. Five of the names are still worse than 250 days —
OxyRock at 376, Rockport Energy Solutions at 333, Fourpoint Energy at 293, Iron Orchard at 273 and Upcurve Energy at 256 — and they are the ones to watch next.
Biggest jobs of the period
Jobs ended in the last 90 days (759 of them), ranked by total base water volume — a wider
window than the 28 days this table used until four issues ago, because at this filing vintage a 28-day window
holds too few settled monsters to rank honestly. Pad siblings dominate the top of any such list: a four- or
six-well pad filed on one end date will fill several rows with near-identical numbers, which is a batch
completion, not six record jobs. The BUTTERS 5-series in Midland County still owns the book — Pioneer's
5E–5H remain the sand leaders and XTO's 5A–5L take the water slots (several disclose no proppant
mass, hence the dashes), and both operators are ExxonMobil. Behind the Butters pad, the biggest jobs are
FireBird Energy II's Beverly 4726 wells in Upton — FireBird is a Diamondback
subsidiary, shown as filed under this issue's no-roll-ups convention. Note the whole table is now at least
two months old at the newest — the freshest row on it ended Jul 2, 67 days back: the June 10 Butters jobs have
simply not been displaced, because almost nothing filed this week.
Operator
Well
County
Water (bbl)
Proppant (lbs)
Job end
XTO (ExxonMobil)
BUTTERS 5A 201H
Midland, TX
1,497,000
74,539,000
Jul 2
XTO (ExxonMobil)
BUTTERS 5C 203H
Midland, TX
1,482,000
74,648,000
Jul 2
XTO (ExxonMobil)
BUTTERS 5D 204H
Midland, TX
1,470,000
74,609,000
Jul 2
XTO (ExxonMobil)
BUTTERS 5B 202H
Midland, TX
1,467,000
74,658,000
Jul 2
XTO (ExxonMobil)
BUTTERS 5J 210H
Midland, TX
1,456,000
—
Jun 13
XTO (ExxonMobil)
BUTTERS 5L 212H
Midland, TX
1,438,000
—
Jun 14
XTO (ExxonMobil)
BUTTERS 5K 211H
Midland, TX
1,431,000
—
Jun 14
XTO (ExxonMobil)
BUTTERS 5I 209H
Midland, TX
1,428,000
—
Jun 14
Pioneer (ExxonMobil)
BUTTERS 5E 205H
Midland, TX
1,408,000
83,714,000
Jun 10
Pioneer (ExxonMobil)
BUTTERS 5H 208H
Midland, TX
1,400,000
81,452,000
Jun 10
Pioneer (ExxonMobil)
BUTTERS 5G 207H
Midland, TX
1,399,000
81,906,000
Jun 10
Pioneer (ExxonMobil)
BUTTERS 5F 206H
Midland, TX
1,311,000
77,926,000
Jun 10
Where the permits are — the county map book
Every Texas horizontal drilling permit issued in the trailing 365 days that carries a
surface location — 3,775 permits across 25 counties, one page each, biggest county first. Each permit is
drawn as a line from its surface location toward the permitted bottomhole, so the map shows lateral
direction and length, not just a dot; 3,764 of them, 99.71%, resolve to a line (11 fall back to a gray dot where the RRC
GIS has no wellbore geometry yet — a targeted re-query found no drilled wellbore for any of them for the fourth
week running, so a dot is the correct rendering). Median drawn lateral this issue: 11,225 ft
(5th percentile 1,969 ft, 95th 20,602 ft, longest 23,737 ft). Lines are coloured by
the county's top-eight permit holders, everyone else gray. Tan lines underneath are Interstate, US and
state highways from TxDOT — locational context only, no county boundaries are drawn; all 25 pages carry highway geometry — up from 22 last issue — and 110 route shields are labelled. That change is a source refresh and a correction; see the note below.
Permits lead the frac by six to twelve months, so this is a map of where crews will be, not where they are.
⚠ Correction: last issue's highway statement was wrong, and this issue's highway
layer is a source refresh. The Aug 31 issue printed that "22 of the 25 pages carry highway geometry" and that
"Kent, Sterling and Terry genuinely have no IH/US/SH mainlane inside their frames". That was false.
It was an artifact of an incomplete TxDOT publication: the TxDOT Roadways service answered count: 0 to
every query on Sep 1, mid-republish, and the geometry we held for those counties was simply missing. The service
republished on Sep 1 (2026-09-01 (dataLastEditDate 2026-09-01 15:00:34Z)) and was verified healthy again this morning. Kent in fact carries US 380, US 84, SH 70 and
SH 208 in the TxDOT file; Terry carries US 62, US 82, US 380, US 385, SH 137 and SH 214; Sterling carries US 87
and SH 163. What each page draws is the mileage that falls inside its rendered frame, which is not always
the whole list: Kent's
page shows US 380, SH 208 and SH 70, Terry's US 82, US 385, US 62, US 380, SH 214 and SH 137, and Sterling's
SH 163 on its own — Kent's US 84 and Sterling's US 87 fall in the 0.05° fetch pad outside the
frame and are fetched but not drawn.
All 25 counties were refetched onto the one 2026-09-01 vintage rather than mixing old and new geometry, which
took the stored feature count from 230 to 371. No route was lost — every prefix/number pair we held
before is still present — and 54 county-route pairs are new. All 25 map pages now carry highways, up from 22.
Gaines went from 4 stored features to 14, Mitchell 1 to 9 and Scurry 3 to 14.
⚠ And the permit file behind this book is frozen for a fifth issue. daf804 still ends
Aug 7, so the trailing-365-day window is advancing against a static file and the point count has now fallen four
weeks running, 3,961 → 3,891 → 3,831 → 3,775 — 56 permits aged out this week and none arrived. That shrinkage is an artifact of
the stale file, not a collapse in Texas permitting, and it will repeat every week until the September cut
lands. One further currency note on the geometry: the permit surface coordinates are a Sep 1 query of the
RRC GIS surface-location layer, reused because this week's permit set is a strict subset of last week's and
every API resolved out of cache; the bottomhole lines were queried fresh on Sep 8.