Permian Basin · Texas & New Mexico

Permian Completions Weekly

Frac jobs disclosed to FracFocus · activity through August 3, 2026 · published August 4, 2026

Read the last columns with a grain of salt. The week ending August 3 shows 0 jobs on file and the week before it just 27, against a settled pace nearer 79 a week — that is filing lag, not a shutdown. Operators have up to about 30 days to disclose a job to FracFocus, so the newest weeks are only ever a fraction of themselves on publication day and grow for a month afterward. The faded columns are still arriving; judge the trend from the solid ones. On the jobs that are settled, the basin is running at about 315 frac jobs per 28 days.

Frac jobs, last 28 days

114

Jul 6 – Aug 3, 2026 · filings still arriving

New Mexico / Texas split

27 / 87

24% of jobs in NM

Settled pace

≈315 jobs/28d

jobs ended 42–126 days back ÷ 3 — the fully-reported baseline

Avg water per job

570,000 bbl

n = 114 jobs reporting

Avg proppant per job

24,610,000 lbs

n = 105 jobs reporting

Produced / recycled water

92%

of water-source records (81 of 88) · 85 of 114 jobs report source · volume-weighted 95%

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 · 26,508 joined wells, 2016 – Aug 2026 · median lb of sand per perforated foot by frac year · *2026 is preliminary (n = 114)

1,512

2016

1,802

2017

1,854

2018

1,855

2019

1,901

2020

1,998

2021

2,003

2022

2,020

2023

2,031

2024

2,036

2025

2,103

2026*

Everyone remembers the loading race. From 2016 to 2018 the median Midland Basin well went from 1,512 to 1,854 lb per perforated foot — a 23% 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 1,854 to 2,036 lb/ft — about 10% in seven years — and the 2026 wells joined so far sit at 2,103. Call it ~2,000 lb/ft: the design equilibrium the basin settled on once the cost-per-barrel math stopped rewarding more sand.

The sand bill still doubled — but sideways. Median perforated interval went from 7,653 ft (2016) to 10,432 ft (2025), and median sand per well from 11.2M to 24.3M lb. The growth was laterals, not loading. Per-well demand kept sand mines busy while the recipe barely moved.

Design still isn't monolithic: among 2025–26 completions, Pioneer's median well takes 30.7M lb against Diamondback's 20.6M — same basin, same benches, a 10-million-pound difference in what shows up on the pad.

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; 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. 2026 reflects wells both frac'd and filed with the RRC — it will drift as the year fills in.

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 week ending Aug 3 has nothing on file yet; that is normal at publication, not a stoppage.

5/11

5/18

5/25

6/1

6/8

6/15

6/22

6/29

7/6

7/13

7/20

7/27

8/3

Texas New Mexico Reporting still filling in

Permian rig count — 260 +2 wk/wk

Active drilling rigs in the Permian, weekly · latest 2026-07-31 · the basin peaked at 311 rigs in Jan 2024 and has held a 256–261 band through July · 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 — the blue line's newest weeks are unfiled, not idle (judge it from the middle of the series). The national frac-spread series returns next issue — not sourced this week. · Sources: Baker Hughes; FracFocus

Permian rigs Frac 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. Method note: operators are shown as filed on the disclosure this issue — no ownership roll-ups — so Pioneer and XTO (both ExxonMobil), and Cimarex (Coterra, now Devon) appear separately; the July issue grouped them. Operators marked · / ·· file moderately / slowly, so recent filings alone understate them. EOG is absent entirely — nothing disclosed since Dec 2025.

Diamondback

36.0

Occidental ··

31.3

Devon

22.3

Pioneer (ExxonMobil) ··

18.0

Apache ··

18.0

XTO (ExxonMobil) ··

16.7

Cimarex (Coterra/Devon) ·

16.3

COG (ConocoPhillips)

15.0

Permian Resources ·

14.0

Chevron

13.7

Mewbourne Oil ·

12.0

Civitas (SM Energy) ·

10.7

Matador

10.7

Ovintiv ··

8.0

Activity by county

Jobs ended in last 28 days (sums to 114)

Lea, NM

Midland, TX

Martin, TX

Glasscock, TX

Ector, TX

Loving, TX

Reeves, TX

Howard, TX

Eddy, NM

Irion, TX

Crane, TX

Upton, TX

Completion pipeline — New Mexico (work coming to a pad near you)

From NM OCD well records (queried Aug 3), horizontal wells in Lea / Eddy / Chaves / Roosevelt: 8,251 approved permits not yet spudded (the drilling backlog — includes stale, unexercised permits of all vintages) and 4,369 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. Every well in that second column needs a frac crew and a drillout. Operators as filed with the OCD; parentheses note current owners.

Operator	Permits (unspudded)	Spudded '24–'26, awaiting completion	Top county
Devon	1,270	405	Lea
EOG Resources	909	794	Lea
ConocoPhillips	771	53	Lea
Coterra (Devon)	692	247	Lea
Matador	649	334	Lea
Permian Resources	639	408	Eddy
Mewbourne Oil	623	516	Eddy
Occidental	496	205	Eddy
XTO (ExxonMobil)	264	579	Eddy
Chevron	245	271	Eddy
Riley Permian	186	16	Eddy
BTA Oil Producers	156	32	Lea
Spur Energy	139	111	Eddy
Civitas (SM)	129	43	Lea
Novo Oil & Gas	109	46	Eddy
WPX (Devon)	104	35	Eddy

Top of the DUC-proxy column basin-wide: EOG 794, XTO 579, Mewbourne 516, Permian Resources 408, Devon 405. The 2026-spud subset is the freshest work headed to frac schedules: EOG 130, XTO 97, Permian Resources 88, Mewbourne 84, Matador 79.

Completion pipeline — Texas permit backlog

RRC drilling permit master, Jul 8 vintage: 4,379 permits issued Aug 2025 – Jul 6, 2026 in the Permian counties, 86% horizontal. July is partial — the file runs only through Jul 6, 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

476

10/25

236

11/25

305

12/25

491

1/26

327

2/26

422

3/26

473

4/26

470

5/26

409

6/26

7/26

TX Permian permits/month July partial (through Jul 6)

Permit holders — trailing 12 months

Operator	Permits (12 mo)	Top county
Pioneer (ExxonMobil)	528	Midland
Occidental	483	Gaines
Diamondback	465	Midland
Operator name unresolved (small P-5 numbers)	284	Loving
COG (ConocoPhillips)	164	Loving
Ovintiv	143	Martin
Apache	141	Upton
Blackbeard	120	Crane
Double Eagle (DE Central)	107	Reagan
Cimarex (Coterra/Devon)	99	Culberson
Continental Resources	98	Pecos
Permian Resources	94	Reeves
Kinder Morgan	89	Pecos
Civitas (SM Energy)	85	Upton
Chevron	82	Midland
XTO (ExxonMobil)	75	Midland

Smaller operators to watch

Everyone outside the top-10 settled list with 3+ completions since March 1 — the private and mid-cap programs that buy sand, water, and services every month without making headlines. Large independents (Mewbourne, Civitas, Matador, Ovintiv, SM, Continental) are excluded regardless of count. 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 Mar–Aug	Top counties	Service co. (ID'd)	Median water (bbl)	Newest job
BPX	30	Reeves, TX, Loving, TX	Halliburton	402,000	2026-05-30
VTX Energy	28	Reeves, TX	NexTier/P-UTI	628,000	2026-07-27
FireBird Energy II	25	Upton, TX, Ector, TX	—	491,000	2026-06-10
Spur Energy Partners	21	Eddy, NM	Halliburton	286,000	2026-07-05
Blue Arrow	18	Reeves, TX, Pecos, TX	—	633,000	2026-07-13
Admiral Resources	18	Loving, TX, Eddy, NM	—	478,000	2026-06-21
Summit Petroleum	15	Upton, TX	FTS Intl	657,000	2026-05-25
BTA Oil Producers	14	Crane, TX, Lea, NM	FTS Intl	645,000	2026-05-25
Double Eagle (DE Central)	13	Glasscock, TX, Reagan, TX	NexTier/P-UTI	532,000	2026-05-07
Fasken Oil and Ranch	12	Andrews, TX, Midland, TX	—	511,000	2026-05-22
Petroplex Energy	11	Borden, TX	—	1,040,000	2026-04-26
Kaiser-Francis Oil	11	Lea, NM	Liberty	459,000	2026-05-01
Strata Production	11	Eddy, NM, Lea, NM	—	51,000	2026-07-18
Surge	10	Borden, TX	NexTier/P-UTI	420,000	2026-04-29
Petro Hunt	10	Loving, TX	Liberty	358,000	2026-03-25
PBEX Operations	8	Ward, TX, Dawson, TX	—	529,000	2026-05-12
Bayswater E&P	8	Mitchell, TX	—	426,000	2026-04-24
3R Operating	7	Lea, NM, Eddy, NM	Liberty	378,000	2026-06-21
Sabalo II	7	Andrews, TX	ProFrac	496,000	2026-06-15
Basin Oil and Gas	6	Winkler, TX, Terry, TX	—	4,000	2026-04-21
TRP	6	Loving, TX	—	514,000	2026-04-28
Manti Tarka	5	Ward, TX	—	367,000	2026-04-22
Discovery Natural Resources	5	Reagan, TX	Liberty	1,315,000	2026-05-09
Ring Energy	5	Crane, TX, Andrews, TX	—	260,000	2026-07-12
Black Swan	4	Glasscock, TX	—	449,000	2026-04-27
Mack Energy	4	Eddy, NM, Chaves, NM	—	95,000	2026-07-24

Completion intensity by operator

Median job design over each operator's own most recent 90 reported days · operators with ≥8 jobs and a disclosure inside the last 6 months · sand in millions of lbs, water in thousands of bbl · lateral and lb/ft come from the RRC perf-interval join, which trails the frac by 3–6 months — for most operators the newest wells have no perf record yet, so those columns are blank ("—") rather than guessed. "n/d" = proppant mass not disclosed.

Operator	Jobs	Median sand (M lbs)	Median water (k bbl)	Median lateral (ft)	Sand (lbs/ft)
Diamondback	117	24.5	631	—	—
Occidental	113	25.6	500	—	—
Devon	66	24.9	484	—	—
Apache	63	20.9	439	—	—
Cimarex (Coterra/Devon)	60	24.3	505	—	—
COG (ConocoPhillips)	56	29.8	575	—	—
Pioneer (ExxonMobil)	51	30.0	671	15,629	1,688
Permian Resources	50	23.5	532	—	—
XTO (ExxonMobil)	48	36.7	613	—	—
Chevron	42	21.7	440	—	—
Civitas (SM Energy)	38	24.3	531	—	—
Matador	35	35.3	761	—	—
BPX (newest 2026-05)	30	18.5	402	—	—
Petro Hunt (newest 2026-03)	30	16.3	362	—	—
Mewbourne Oil	29	30.2	642	—	—
FireBird Energy II	25	21.1	491	—	—
Ovintiv (newest 2026-05)	24	n/d	619	—	—
Double Eagle (DE Central) (newest 2026-05)	19	n/d	516	10,392	—
Summit Petroleum (newest 2026-05)	17	33.5	656	—	—
Blackbeard (newest 2026-03)	17	9.1	228	7,181	2,859
Continental Resources (newest 2026-04)	17	22.1	610	—	—
Surge (newest 2026-04)	16	19.6	393	—	—
Admiral Resources	15	24.0	480	—	—
Spur Energy Partners	15	7.6	427	—	—
BTA Oil Producers (newest 2026-05)	14	26.2	645	11,112	2,367
Fasken Oil and Ranch (newest 2026-05)	14	17.6	515	—	—
VTX Energy	14	25.3	647	—	—
Petroplex Energy (newest 2026-04)	13	38.9	1,039	—	—
Kaiser-Francis Oil (newest 2026-05)	11	19.3	459	—	—
Black Swan (newest 2026-04)	11	34.1	786	16,601	2,259
SM Energy (newest 2026-04)	10	57.3	1,149	10,382	2,999
Blue Arrow	10	27.1	630	—	—
Strata Production	9	3.9	56	—	—
Bayswater E&P (newest 2026-04)	8	21.8	426	—	—
PBEX Operations (newest 2026-05)	8	27.5	529	7,426	2,433
Paloma Permian AssetCo, LLC (newest 2026-02)	8	26.2	563	—	—

Water & sand by well depth (TVD)

Median job design by true vertical depth band, last-28-day jobs reporting TVD, water, and proppant (105 of 114) — a rough proxy for target bench. The deepest band is a single well this period.

TVD band	Jobs	Median water (bbl)	Median proppant (lbs)	Sand conc. (lbs/gal)
< 7,500 ft	7	127,000	6,071,000	1.14
7,500 – 10,000 ft	67	556,000	24,011,000	1.03
10,000 – 12,000 ft	30	600,000	25,706,000	1.02
> 12,000 ft	1	447,000	24,013,000	1.28

Water & sand by target formation — Texas

Texas jobs ended in the last 28 days (87), formation from the RRC wellbore join where the completion filing has caught up — 46 of 87 named. New Mexico is excluded this issue (the OCD pool join was not refreshed this cycle). Because the RRC filing trails the frac, the named rows skew toward operators that file completions promptly.

Formation	Jobs	Median water (bbl)	Median proppant (lbs)	Sand conc. (lbs/gal)
Spraberry (incl. Jo Mill)	21	644,000	24,625,000	0.91
Dean	7	732,000	30,298,000	0.99
Wolfcamp	5	547,000	23,766,000	1.03
Other named (Avalon, Delaware, Glorieta…)	13	619,000	26,567,000	1.02
Unreported	41	527,000	23,771,000	1.07

Current conditions — fleets likely on location (inferred)

Inferred from disclosure cadence: a pad (operator + surface location, ~1 km grid) whose latest job ended within ~1.5× that pad's own median gap between filing dates is probably still being pumped or just finishing. Method note vs July: pads are keyed by coordinates this issue (lease names weren't carried in this cycle's extract), and several large operators batch-date a whole pad's wells to one end date, which hides their cadence — 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.

Status	Operator	Service co.	County	Wells so far	Pad gap (d)	Last job end
🟢 Likely on location	COG (ConocoPhillips)	Halliburton	Martin, TX	7	16	Jul 26
🟢 Likely on location	Strata Production	—	Eddy, NM	2	165	Jul 18
🟢 Likely on location	Ring Energy	—	Crane, TX	3	242	Jul 11
🟢 Likely on location	Strata Production	—	Eddy, NM	2	207	Jul 9
🟢 Likely on location	Cimarex (Coterra/Devon)	Halliburton	Culberson, TX	13	48	Jul 5
🟢 Likely on location	Strata Production	—	Eddy, NM	2	249	Jul 1
🟢 Likely on location	Strata Production	—	Eddy, NM	5	107	Jun 27
🟢 Likely on location	Cimarex (Coterra/Devon)	Halliburton	Lea, NM	10	210	Jun 27
🟢 Likely on location	Mack Energy	—	Chaves, NM	3	313	Jun 23
🟢 Likely on location	Spur Energy Partners	Halliburton	Eddy, NM	2	105	Jun 21
⚪ Recently released	Diamondback	Halliburton	Glasscock, TX	6	3	Jul 24
⚪ Recently released	Devon	—	Lea, NM	4	3	Jul 17
⚪ Recently released	Devon	—	Loving, TX	8	8.5	Jul 14
⚪ Recently released	Blue Arrow	—	Reeves, TX	4	3	Jul 13
⚪ Recently released	VTX Energy	—	Reeves, TX	2	3	Jul 12
⚪ Recently released	Diamondback	Halliburton	Midland, TX	16	3	Jul 11
⚪ Recently released	COG (ConocoPhillips)	Halliburton	Martin, TX	5	3	Jul 11
⚪ Recently released	COG (ConocoPhillips)	—	Eddy, NM	4	3	Jul 9
⚪ Recently released	Matador	NexTier/P-UTI	Lea, NM	4	3	Jul 9

Frac service companies — who's pumping for whom

Pressure pumper identified on 61% of the last 12 months' jobs (2,939 of 4,832) — from FracFocus supplier records directly, plus same-pad propagation (a labeled sibling well within the pad names the crew). That 61% is not comparable to the 77% printed in July, which layered chemical fingerprinting and fleet-continuity inference on top; this issue reports only the directly-evidenced share. "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)	Top customers	TX / NM	Top counties
Halliburton	1,322	Diamondback, Cimarex, Occidental	1,012 / 310	Martin, Midland
NexTier (Patterson-UTI)	716	Pioneer, Mewbourne, COG	422 / 294	Eddy, Lea
Liberty	556	XTO, Occidental, Civitas	270 / 286	Eddy, Loving
ProFrac	235	Apache, SM Energy, Paloma	213 / 22	Midland, Howard
FTS International	84	Permian Resources, Summit, Ovintiv	49 / 35	Lea, Upton
SLB	26	Chevron, Devon	9 / 17	Lea, Culberson
Not identified	1,893	supplier not named on disclosure or pad	–	–

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 vs July: July scaled each operator by its own observed pad pace; this period too many operators batch-dated 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: 315 wells/28d ≈ 56 fleet-equivalents and ≈ 53 drillout units kept busy.

Operator	Wells / 28d (settled)	Implied fleet-equiv.	Implied drillout units
Diamondback	36.0	6.4	6.0
Occidental	31.3	5.6	5.2
Devon	22.3	4.0	3.7
Pioneer (ExxonMobil)	18.0	3.2	3.0
Apache	18.0	3.2	3.0
XTO (ExxonMobil)	16.7	3.0	2.8
Cimarex (Coterra/Devon)	16.3	2.9	2.7
COG (ConocoPhillips)	15.0	2.7	2.5
Permian Resources	14.0	2.5	2.3
Chevron	13.7	2.4	2.3
Mewbourne Oil	12.0	2.1	2.0
Civitas (SM Energy)	10.7	1.9	1.8
Matador	10.7	1.9	1.8
Ovintiv	8.0	1.4	1.3

Estimated completion spend — run-rate per 28 days

Modeled from each settled job's disclosed sand, water, and water-source mix. Basin total: ≈ $3.2B per 28 days (median ≈ $10.1M per job × 315 settled jobs/28d). The model's assumptions were revised this issue and run richer than July's — the two issues' totals are not comparable. Estimates, not invoices; assumptions below.

Operator	Jobs / 28d	Est. spend / 28d	Est. sand $	Est. water $
Diamondback	36.0	$309M	$8.9M	$11.8M
Occidental	31.3	$326M	$9.7M	$8.7M
Devon	22.3	$226M	$6.7M	$6.0M
Pioneer (ExxonMobil)	18.0	$198M	$5.9M	$6.4M
Apache	18.0	$153M	$4.5M	$6.0M
XTO (ExxonMobil)	16.7	$238M	$7.2M	$5.1M
Cimarex (Coterra/Devon)	16.3	$162M	$4.8M	$4.1M
COG (ConocoPhillips)	15.0	$191M	$5.7M	$5.6M
Permian Resources	14.0	$133M	$3.9M	$5.7M
Chevron	13.7	$135M	$4.0M	$3.9M
Mewbourne Oil	12.0	$125M	$3.7M	$3.9M
Civitas (SM Energy)	10.7	$103M	$3.0M	$3.2M
Matador	10.7	$113M	$3.3M	$3.9M

Assumptions: sand $0.012/lb delivered (≈$24/ton); water $0.50/bbl produced/recycled, $1.10/bbl fresh, mixed per each job's disclosed source split (basin default 92/8 where unreported); pumping $180k/day at a modeled ~500k lb of sand/day; plus $350k wireline & plugs and $250k other (chemicals, flowback, supervision) per well. Jobs without disclosed sand are estimated at the basin-median 1.03 lbs/gal of water. The pumping-day term dominates; operators running simul-frac beat the modeled day rate and their true spend runs below these figures.

What the wells actually made — IP90 after the frac

Wells frac'd July 2024 – Feb 2026, 6,153 with a clean 90-day production window (2,843 New Mexico + 3,310 Texas). New Mexico: true well-level oil volumes from OCD C-115 filings, all 3,175 cohort wells queried. Texas: oil + condensate from RRC lease-level filings, restricted this issue 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 3,310 of 6,687 TX cohort wells (49%; the rest sit on multi-well leases) and is stricter than July's pad-allocation method, so well counts are not comparable issue-over-issue. Wells with production predating the frac (refracs, legacy leases) excluded. IP90 = oil over the first three reported production months ÷ 90 days. Median across all 6,153 wells: 694 bopd (NM 762, TX 640).

Formation	Wells	Median IP90 (bopd/well)	bopd per 1,000 ft
Wolfcamp	2366	693	65
Bone Spring	2049	769	64
Spraberry	1206	639	52
Dean	173	741	55
Clear Fork	136	569	50
Barnett	66	569	62
Yeso	35	225	—
Delaware Mtn	32	590	—
San Andres	24	175	26
Penn	17	298	—
Strawn	12	536	51
Queen	11	438	42
Other / unreported	26	432	28

Operator	Wells	Median IP90 (bopd/well)
ExxonMobil (Pioneer/XTO)	1191	700
Devon (incl. Coterra)	622	895
EOG Resources	540	858
Mewbourne Oil	509	625
Occidental	413	997
Permian Resources	350	674
Diamondback	318	765
Chevron	301	611
ConocoPhillips (COG)	254	763
Matador Production	236	622

The single-well-lease restriction reshuffles the operator ranking versus July — operators that develop on one-well leases (New Mexico federal units, newer TX allocation leases) are fully counted; big-pad operators are under-represented. Devon, Oxy and EOG medians run high partly because their qualifying wells skew to the Delaware side. Formations under 10 qualifying wells are folded into "Other".

Per-1,000-ft figures use perforated intervals from the TX wellbore file (known for 3,211 of 3,310 TX wells) plus NM OCD completion reports where filed — only 62 of 2,843 NM wells, since OCD processes completion paperwork with a long lag. The per-foot column is therefore TX-weighted; NM-only formations (Yeso, Delaware Mtn, Penn) show a dash where the lateral sample is under 10 wells. TX production through May 2026 (June filings still arriving); NM through May–June 2026. 90-day windows ending after May 2026 are held for next issue rather than reported against part-filed months.

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 Apr–Jun vs the preceding 12-month average (intent — leads the frac 6–12 months; July permits excluded as partial); 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). Hover a row for the figures.

Operator	Settled pace /28d	TX permits	Filed last 28d	Reads as
Diamondback	· 36.0vs 37.3 prior 3 mo	· 39/moApr–Jun · vs 43 typical	38 (106%)	holding pace, filings current
Occidental	· 31.3vs 40.0 prior 3 mo	· 45.3/moApr–Jun · vs 42.6 typical	0 (0%)	easing from a hot spring; slow filer, so watch next issue
Devon	▲ 22.3vs 16.3 prior 3 mo	—no TX permits (NM program)	12 (54%)	ramping — completions up, program is NM/Culberson-weighted
Pioneer (ExxonMobil)	▼ 18.0vs 43.0 prior 3 mo	▲ 56.7/moApr–Jun · vs 43.1 typical	3 (17%)	sharp drop on paper — but a slow filer permitting hard; likely lag, not a stop
Apache	▲ 18.0vs 11.0 prior 3 mo	▲ 16.7/moApr–Jun · vs 11.4 typical	0 (0%)	ramping — completions and permits both up
XTO (ExxonMobil)	· 16.7vs 20.7 prior 3 mo	▼ 0.7/moApr–Jun · vs 9.1 typical	0 (0%)	steady output, TX permitting near zero — front end thinning
Cimarex (Coterra/Devon)	· 16.3vs 16.3 prior 3 mo	· 7.3/moApr–Jun · vs 9.6 typical	2 (12%)	holding pace
COG (ConocoPhillips)	▼ 15.0vs 24.0 prior 3 mo	· 16/moApr–Jun · vs 13.5 typical	17 (113%)	off its winter peak but on location right now
Permian Resources	▼ 14.0vs 19.7 prior 3 mo	· 7/moApr–Jun · vs 9.1 typical	0 (0%)	easing; permits soft too
Chevron	▲ 13.7vs 8.7 prior 3 mo	▼ 1.3/moApr–Jun · vs 8.1 typical	13 (95%)	ramping — completions up and filings current
Mewbourne Oil	▼ 12.0vs 24.0 prior 3 mo	▼ 2.7/moApr–Jun · vs 4 typical	2 (17%)	completions halved on paper; 516-well NM backlog says the work is coming
Civitas (SM Energy)	· 10.7vs 11.3 prior 3 mo	▼ 4.7/moApr–Jun · vs 8.9 typical	0 (0%)	holding pace
Matador	· 10.7vs 12.3 prior 3 mo	—no TX permits (NM program)	8 (75%)	holding pace
Ovintiv	▲ 8.0vs 0.0 prior 3 mo	· 14.3/moApr–Jun · vs 12.5 typical	0 (0%)	batch filer back on the board — permits steady

EOG is absent from every completions column — nothing disclosed to FracFocus since Dec 2025 — while its NM drilling backlog (794 wells spudded '24–'26 awaiting completion) is the basin's largest. Late paperwork on an active program, not idle iron.

How current is each operator's paperwork?

Every operator with 8+ Permian disclosures in the trailing 18 months — 67 of them — sorted worst-first by how stale the FracFocus file is at press time (Aug 3). current = newest job-end on file within 42 days; slow = 42–120 days; dark = nothing newer than 120 days. FracFocus has no enforced filing deadline, so a dark file is a paperwork signal, not an activity signal — and each late batch that eventually lands revises the settled-pace numbers above upward after the fact. Settled pace = jobs ended 42–126 days back ÷ 3.

Operator	Filing	Newest job-end on file	Filed last 28d	Settled pace /28d
Avant Operating, LLC	dark	Feb 7, 2025 · 542d	0	0.0
DE IV Operating LLC	dark	Feb 22, 2025 · 527d	0	0.0
OxyRock Operating, LLC	dark	Aug 28, 2025 · 340d	0	0.0
Rockport Energy Solutions LLC	dark	Oct 10, 2025 · 297d	0	0.0
U.S. Energy Development Corp	dark	Nov 2, 2025 · 274d	0	0.0
FourPoint Energy, LLC	dark	Nov 19, 2025 · 257d	0	0.0
Iron Orchard Operating, LLC	dark	Dec 9, 2025 · 237d	0	0.0
EOG Resources	dark	Dec 24, 2025 · 222d	0	0.0
Greenlake Energy Operating	dark	Dec 24, 2025 · 222d	0	0.0
UpCurve Energy LLC	dark	Dec 26, 2025 · 220d	0	0.0
Burnett Oil Co., Inc.	dark	Jan 6, 2026 · 209d	0	0.0
HighPeak Energy Holdings, LLC.	dark	Jan 14, 2026 · 201d	0	0.0
Vital Energy	dark	Jan 16, 2026 · 199d	0	0.0
IKE Operating, LLC	dark	Jan 16, 2026 · 199d	0	0.0
Triple Crown Resources	dark	Jan 18, 2026 · 197d	0	0.0
Unitex Oil Company	dark	Feb 5, 2026 · 179d	0	0.0
Circle-S Energy, LLC	dark	Feb 15, 2026 · 169d	0	0.0
Hannathon Petroleum II, LLC	dark	Feb 16, 2026 · 168d	0	0.0
Paloma Permian AssetCo, LLC	dark	Feb 25, 2026 · 159d	0	0.0
Hibernia Resources IV LLC	dark	Mar 2, 2026 · 154d	0	0.0
Blackbeard Operating	dark	Mar 23, 2026 · 133d	0	0.0
Petro Hunt, L.L.C.	dark	Mar 25, 2026 · 131d	0	0.0
Marathon Oil	dark	Apr 4, 2026 · 121d	0	0.7
SM Energy	slow	Apr 12, 2026 · 113d	0	1.3
Basin Oil and Gas Operating, LLC	slow	Apr 21, 2026 · 104d	0	1.0
Manti Tarka Permian	slow	Apr 22, 2026 · 103d	0	1.7
Bayswater Exploration & Production, LLC	slow	Apr 24, 2026 · 101d	0	1.3
Petroplex Energy Inc.	slow	Apr 26, 2026 · 99d	0	2.3
Black Swan Oil & Gas	slow	Apr 27, 2026 · 98d	0	1.3
TRP Operating LLC	slow	Apr 28, 2026 · 97d	0	2.0
Surge Operating, LLC	slow	Apr 29, 2026 · 96d	0	1.3
Continental Resources, Inc	slow	Apr 30, 2026 · 95d	0	2.3
Kaiser-Francis Oil Company	slow	May 1, 2026 · 94d	0	2.7
DE Central Operating, LLC	slow	May 7, 2026 · 88d	0	2.3
Ovintiv	slow	May 8, 2026 · 87d	0	8.0
Discovery Natural Resources LLC	slow	May 9, 2026 · 86d	0	1.7
PBEX Operations, LLC	slow	May 12, 2026 · 83d	0	1.0
Fasken Oil and Ranch, Ltd.	slow	May 22, 2026 · 73d	0	2.7
Summit Petroleum LLC	slow	May 25, 2026 · 70d	0	3.3
BTA Oil Producers LLC	slow	May 25, 2026 · 70d	0	2.0
BPX Operating Company	slow	May 30, 2026 · 65d	0	6.3
Tap Rock Resources	slow	May 30, 2026 · 65d	0	0.7
FireBird Energy II LLC	slow	Jun 10, 2026 · 54d	0	6.3
Sabalo II Operating, LLC	slow	Jun 15, 2026 · 49d	0	2.3
Admiral Permian Resources, LLC	slow	Jun 21, 2026 · 43d	0	4.3
3R OPERATING, LLC	slow	Jun 21, 2026 · 43d	0	2.3
Permian Deep Rock Oil Co., LLC	slow	Jun 21, 2026 · 43d	0	1.3
Permian Resources	current	Jun 23, 2026 · 41d	0	14.0
Apache	current	Jun 25, 2026 · 39d	0	18.0
Occidental	current	Jun 26, 2026 · 38d	0	31.3
Civitas (SM Energy)	current	Jun 30, 2026 · 34d	0	10.7
XTO (ExxonMobil)	current	Jul 2, 2026 · 32d	0	16.7
Spur Energy Partners	current	Jul 5, 2026 · 29d	0	4.0
Pioneer (ExxonMobil)	current	Jul 9, 2026 · 25d	3	18.0
Cimarex (Coterra/Devon)	current	Jul 11, 2026 · 23d	2	16.3
Ring Energy, Inc.	current	Jul 12, 2026 · 22d	3	0.7
Chevron	current	Jul 13, 2026 · 21d	13	13.7
Blue Arrow Operating, LLC	current	Jul 13, 2026 · 21d	5	2.3
Devon	current	Jul 18, 2026 · 16d	12	22.3
STRATA PRODUCTION COMPANY	current	Jul 18, 2026 · 16d	2	2.3
SEM Operating Company, LLC	current	Jul 19, 2026 · 15d	4	0.0
Mewbourne Oil	current	Jul 21, 2026 · 13d	2	12.0
Matador	current	Jul 24, 2026 · 10d	8	10.7
Mack Energy Corporation	current	Jul 24, 2026 · 10d	1	0.3
COG (ConocoPhillips)	current	Jul 26, 2026 · 8d	17	15.0
Diamondback	current	Jul 27, 2026 · 7d	38	36.0
VTX Energy Operating, LLC	current	Jul 27, 2026 · 7d	4	4.7

EOG watch: the basin's most conspicuous dark filer — newest disclosure ended Dec 24, 2025, 222 days ago — yet NM OCD well files show 794 EOG wells spudded '24–'26 still awaiting completion, the largest drilled-uncompleted backlog in the basin (see the NM pipeline section). Paperwork dark ≠ inactive.

Biggest jobs of the period

Jobs ended in the last 28 days, ranked by total base water volume. Pioneer's three Midland Co. monsters (~1.12M bbl / ~40M lbs each) look like siblings off one pad; Diamondback's Ector Co. block is seven wells of near-identical design. Well names return next issue (not carried in this cycle's extract).

Operator	County	Water (bbl)	Proppant (lbs)
Pioneer (ExxonMobil)	Midland, TX	1,127,000	40,166,000
Pioneer (ExxonMobil)	Midland, TX	1,123,000	40,554,000
Pioneer (ExxonMobil)	Midland, TX	1,119,000	40,373,000
Diamondback	Ector, TX	1,014,000	40,613,000
Diamondback	Ector, TX	1,009,000	40,293,000
Diamondback	Ector, TX	1,001,000	40,579,000
Diamondback	Ector, TX	1,001,000	40,579,000
Diamondback	Ector, TX	901,000	36,537,000
Diamondback	Ector, TX	901,000	36,731,000
Diamondback	Ector, TX	898,000	35,070,000

Where the permits are — the county map book

Every horizontal Texas permit issued in the trailing 365 days with a resolvable surface location — 3,757 wells across 24 counties — one page per county, ordered by count, coloured by operator. Each permit is drawn as a line from its surface location toward its permitted bottomhole — the direction the lateral runs — using the RRC's digital-map well layers (surface, bottomhole and horizontal-wellbore lines, joined by API). 3,731 of 3,757 permits (99.3%) are drawn as lines; the 26 with no resolvable bottomhole point appear as small gray dots at surface. Colours rank operators within each county, so the same colour on two pages is two different companies; gray lines are everyone outside the county's top 8. Frames and gridlines are lat/lon (0.25° graticule); tan lines are the major highways — interstates and US/state routes from TxDOT's roadway network, labeled where room allows and good to about a mile — county boundaries still aren't drawn. New Mexico permits aren't plotted (OCD points weren't staged for mapping this cycle).