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FRANK-MORGAN E27C

Operated by PIONEER NATURAL RES. USA, INC. (P-5 665748) in the SPRABERRY (TREND AREA) R 40 EXC field. Every figure below is a volume the Railroad Commission published, multiplied by a monthly price you can check.

Oil lease lease 20795District 7CField 85279201OilCasinghead gasSaveExport
Value, all time
$27.9 M
Jul 2019 – May 2026
Value, last 12 filed months
$589 k
at the published price for each month
Months reported
83
no gaps in the span
Streams
2
oil, casinghead gas

The SPRABERRY (TREND AREA) R 40 EXC field

The Railroad Commission's own record for the field this lease produces from, including the spacing rule that governs how close together its wells may be drilled.

These are facts about the field, not about this lease. The field holds 721 leases and 1,413 wells, and the rule below applies to all of them.

Discovered
2013-12-18
as the register files it
Field class
Oil and gas
the register's own label
Between wells
0 ft
minimum
From a lease line
330 ft
minimum

A drilling unit in this field needs at least 80 acres. The field rule took effect on 2024-02-01.

The Commission's schedule remark for this field reads: “ALLOCATION FORMULA EFFECTIVE 02/01/2024.”

What this lease produced, and what it was worth

Oil and condensate are valued on the volume the state records as disposed of; gas and casinghead gas on the volume produced. They are different columns of different files, and the difference is not cosmetic.

StreamBasisVolumeValue
OilDisposition399,267 bbl$22,467,834
Casinghead gasProduction1,521,585 Mcf$5,422,124
Total$27,889,958

Wells on this lease (21)

Every wellbore the Railroad Commission records against this lease key, with the depth, the last completion and the plug date exactly as filed. A well with no plug date is not stated to be producing — the state files no such flag.

These wells centre on 30.9173, -101.8861. A lease has no coordinate of its own — that point is the mean of its wells, and they span 36.2 miles, so treat it as the lease's centre and not as its location.

31.15248, -101.89696 · centre of the wells drawn, derived

What these wells add up to

Every figure below is counted over all of this lease's wells, not over the rows listed above. The Railroad Commission files two facts about a well's state — a plug date and a proration-schedule flag — and a well can carry both, so they are published as separate counts and never merged into a status.

On the schedule
95.2%
20 of 21 wells
With a plug date
95.2%
20 of 21 wells
Median depth
38 ft
21 wells filed one
Completion to plug
40.5 years
median over 9 wells

What the state filed about each well

On the RRC proration schedule
2095.2%
A plug date is filed
2095.2%
BothOn the schedule and plugged. Neither fact cancels the other.
2095.2%
NeitherNo plug date, and not on the schedule.
14.8%

A plug date is the date the Commission recorded the wellbore as sealed with cement and abandoned. It is the only end-of-life fact Texas files. There is no "active" flag on a well, so this page does not print one — a well with no plug date is not stated to be producing.

How deep they were drilled

Total depth in feet, 21 of 21 wells. Median 38 ft, with the middle half between 36 and 41 ft; the shallowest is 22 ft and the deepest 9,389 ft. The median is published rather than the mean, because a single mis-keyed depth moves a mean and cannot move a median.

When they were last completed

Last completion by decade, 10 of 21 wells, Apr 1965 – Jan 2020. This is the LAST completion filed on each wellbore, not the first — a well recompleted in 2019 counts once, in the 2010s.

Completions filed
Apr 1965 – Jan 2020
10 of 21 wells; 11 filed none
Plug dates filed
Feb 2006 – Oct 2016
20 of 21 wells; 1 filed none

Last completion to plug: a median of 40.5 years across the 9 wells that filed both dates, with the middle half between 37.9 years and 40.8 years. The gap is the distance between two filed dates. It is not a statement of how long the well produced.

21 wells

42-10501045146 ft—Feb 2006Yes
42-10501049538 ft—Feb 2006Yes
42-105010506211 ft—Oct 2016Yes
42-10501051741 ft—Feb 2006Yes
42-10501053937 ft—Feb 2006Yes
42-105010541038 ft—Feb 2006Yes
42-105010561222 ft—Feb 2006Yes
42-105010571336 ft—Feb 2006Yes
42-105010591539 ft—Feb 2006Yes
42-105010601637 ft—Feb 2006Yes
42-10501755240 ft—Feb 2006Yes
42-46141132203H9,389 ftJan 2020——
42-105010611740 ftJun 1968Feb 2006Yes
42-10501048435 ftApr 1968Feb 2006Yes
42-10501047355 ftMar 1968Feb 2006Yes
42-105010631934 ftNov 1965Feb 2006Yes
42-105010642036 ftOct 1965Oct 2016Yes
42-105010621838 ftAug 1965Feb 2006Yes
42-105010581441 ftApr 1965Feb 2006Yes
42-10501052835 ftApr 1965Feb 2006Yes
42-105010551138 ftApr 1965Feb 2006Yes

The API number is the state's, prefixed 42 for Texas. A well is matched to this lease by the lease key the Commission files on the wellbore record, so a well that has moved between leases appears under each one it was filed against.

Every month this lease reported (83)

Volume × price = value, one row per cycle. The price columns are the same series published on the prices page — nothing here is modelled.

83 months

May 202613184106.413.05$14,196
Apr 2026301,71298.932.87$7,881
Mar 202601,01989.753.15$3,209
Feb 2026019563.503.75$731
Jan 2026075059.138.00$5,998
Dec 202512886256.664.41$11,057
Nov 202501,03558.593.93$4,064
Oct 20251581,10759.383.30$13,041
Sep 20251,23512,63862.743.08$116,370
Aug 20251,04210,49863.933.01$98,264
Jul 20251,72616,11466.743.32$168,614
Jun 20251,54513,55966.483.13$145,134
May 20251,52013,45660.553.23$135,530
Apr 20251,54412,82362.363.54$141,717
Mar 20251,73213,40767.704.27$174,482
Feb 20251,51913,92270.884.34$168,100
Jan 20251,83916,54074.324.28$207,444
Dec 20241,89117,40468.993.12$184,784
Nov 20241,95917,42969.052.20$173,586
Oct 20242,12918,36871.372.28$193,851
Sep 20242,10818,14169.612.36$189,630
Aug 20242,07118,59075.632.06$194,993
Jul 20242,01218,19679.932.15$199,879
Jun 20242,02318,54278.082.63$206,795
May 20242,19919,00878.812.20$215,091
Apr 20242,32519,69684.451.66$229,026
Mar 20242,48519,27680.301.55$229,329
Feb 20242,40817,87176.091.78$215,100
Jan 20242,47819,49673.023.30$245,235
Dec 20232,58419,92271.262.61$236,147
Nov 20232,61918,44177.892.81$255,768
Oct 20232,61918,19085.443.09$279,925
Sep 20232,43017,36089.042.74$263,847
Aug 20232,60719,99480.522.67$263,357
Jul 20232,85221,00374.852.64$268,958
Jun 20232,55920,02468.962.26$221,692
May 20232,82219,81270.622.23$243,419
Apr 20232,81819,11578.122.24$262,917
Mar 20232,98220,30472.852.39$265,829
Feb 20232,65019,69375.112.47$247,598
Jan 20232,87323,77276.533.39$300,404
Dec 20223,20623,41976.415.73$379,140
Nov 20223,38424,71785.005.65$427,197
Oct 20223,57422,19887.185.86$441,745
Sep 20223,62424,64984.888.16$508,832
Aug 20224,04626,51794.529.13$624,453
Jul 20223,98023,413101.587.54$580,871
Jun 20223,96619,901115.097.98$615,201
May 20224,35521,492109.378.43$657,549
Apr 20224,57321,639104.226.84$624,557
Mar 20224,85621,573108.885.08$638,234
Feb 20224,49018,84891.054.86$500,394
Jan 20224,79321,65781.844.54$490,532
Dec 20215,41027,07571.323.90$491,410
Nov 20214,96028,00877.435.24$530,726
Oct 20215,95029,09479.795.71$640,990
Sep 20216,18424,85669.865.35$565,017
Aug 20215,55722,44466.024.22$461,600
Jul 20216,46628,13070.783.98$569,679
Jun 20216,53827,42269.493.38$547,029
May 20217,52429,31563.483.02$566,087
Apr 20217,97128,24260.362.76$559,033
Mar 20219,38830,90561.302.72$659,451
Feb 20216,40718,37057.805.55$472,240
Jan 20219,57930,35350.412.81$568,178
Dec 202010,44931,41444.642.68$550,490
Nov 202011,47032,42838.772.71$532,461
Oct 202012,85233,12636.972.48$557,239
Sep 202014,58535,71837.091.99$612,074
Aug 202014,44729,18439.982.39$647,198
Jul 202014,90127,25138.371.83$621,488
Jun 202014,89222,18634.901.69$557,232
May 202018,07726,27016.921.81$353,536
Apr 202019,13324,04214.751.80$325,593
Mar 202025,05131,83830.341.86$819,146
Feb 202025,54229,26249.881.98$1,331,993
Jan 202014,43515,26157.252.09$858,372
Dec 20190059.012.30$0
Nov 20190055.302.75$0
Oct 20190053.472.42$0
Sep 20190055.052.66$0
Aug 20190053.112.30$0
Jul 20190056.272.46$0

How to read this page

The arithmetic is one multiplication per stream per month. Here it is, worked, on a real row from the table above.

May 2026 — as filed, then multipliedworked
Oil                  131 bbl  × $106.41 =    $13,940
Casinghead gas        84 Mcf  × $  3.05 =       $256

────────────────────────────────────────────────────
Month total                                  $14,196

The volumes are the state's, unchanged

Every barrel and every Mcf on this page is a number the Railroad Commission of Texas published in its monthly production query. Nothing is modelled, estimated or filled in.

The dollars are a multiplication, not a valuation

Volume × a published monthly price. It is not what the operator was paid: it takes no account of a contract, a differential, a transportation deduction, or the share any one owner holds.

Oil and gas are priced differently

Oil is a Texas realisation — the crude oil first purchase price. Gas is a benchmark, because no free Texas wellhead gas series exists at any date. The prices page publishes the difference rather than correcting it away.

A lease is not a well

The state reports oil on lease and gas on well, and this page is the lease grain. 7C/O/20795 is the state's own key, not one this site invented.