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KING RANCH-STRATTON

Operated by EXXON CORP. (P-5 257097) in the STRATTON field. Every figure below is a volume the Railroad Commission published, multiplied by a monthly price you can check.

Oil lease lease 3031District 04Field 86508001NGPA filingOilCasinghead gasSaveExport
Value, all time
$94 k
Jan 1993 – Nov 1996
Value, last 12 filed months
$13 k
at the published price for each month
Months reported
47
no gaps in the span
Streams
2
oil, casinghead gas

The STRATTON 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 20 leases and 176 wells, and the rule below applies to all of them.

Discovered
1938-04-23
as the register files it
Field class
Oil and gas
the register's own label
Between wells
933 ft
minimum
From a lease line
467 ft
minimum

A drilling unit in this field needs at least 40 acres. The field rule took effect on 1989-07-14.

The Commission's schedule remark for this field reads: “CONSOL INTO STRATTON (CONSOLIDATED) FLD EFF 11/1/96.”

Severance-tax incentive filings

Applications the operator filed to have this lease's gas taxed at a reduced state rate. A filing is an application, and this page never calls one a reduction that was granted.

ProgrammeFilingsWith an approval dateDatedDocket
NGPA3none——

This says nothing about a royalty. A severance tax is charged to the operator. Whether a reduced rate reaches a royalty owner depends on the wording of the lease instrument, which is a private contract this site does not hold.

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
OilDisposition5,791 bbl$94,056
Casinghead gasProduction2,021 Mcf$0
Total$94,056

2,021 Mcf of this lease's gas, across 43 months, carries no value here. No free Texas wellhead gas price exists before 1997, so those months are left out of the total rather than valued at zero. The total above is therefore a floor, not an estimate.

Wells on this lease (79)

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 27.5899, -97.9296. A lease has no coordinate of its own — that point is the mean of its wells, and they span 8.9 miles. 21 wells have no surveyed location and are left out of it.

27.62151, -97.92544 · centre of 58 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
100.0%
79 of 79 wells
With a plug date
41.8%
33 of 79 wells
Median depth
7,200 ft
45 wells filed one
Completion to plug
9.3 years
median over 20 wells

What the state filed about each well

On the RRC proration schedule
79100.0%
A plug date is filed
3341.8%
BothOn the schedule and plugged. Neither fact cancels the other.
3341.8%
NeitherNo plug date, and not on the schedule.
00.0%

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, 45 of 79 wells. Median 7,200 ft, with the middle half between 7,045 and 7,360 ft; the shallowest is 5,668 ft and the deepest 8,617 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, 23 of 79 wells, Dec 1960 – May 2013. This is the LAST completion filed on each wellbore, not the first — a well recompleted in 2019 counts once, in the 2010s.

Completions filed
Dec 1960 – May 2013
23 of 79 wells; 56 filed none
Plug dates filed
Apr 1975 – Apr 2025
33 of 79 wells; 46 filed none

Last completion to plug: a median of 9.3 years across the 20 wells that filed both dates, with the middle half between 6.7 years and 12.9 years. The gap is the distance between two filed dates. It is not a statement of how long the well produced.

79 wells

42-24902290A 15———Yes
42-24930074A 486,390 ft—Nov 1991Yes
42-24980571130 C———Yes
42-24980573A 18 D———Yes
42-24980574A 636,466 ft——Yes
42-24980575P 16,616 ft—Nov 1978Yes
42-24980576P 15 U———Yes
42-24980577P 40 T6,657 ft——Yes
42-24980578P 61———Yes
42-24980579P 87 T7,160 ft——Yes
42-24980580P 94 T———Yes
42-24980581P122 C———Yes
42-24980582P135 T———Yes
42-24980583P138 F———Yes
42-24980585P140 F———Yes
42-24980586P140 H———Yes
42-24980587P168 F———Yes
42-24980588P180 F———Yes
42-24980590P196 D———Yes
42-24980591P220 D———Yes
42-24980592P2307,045 ft——Yes
42-27300152A 22———Yes
42-27300192P 7 U6,645 ft—Mar 1992Yes
42-27300196P 61 U———Yes
42-27300200P 12 U———Yes
42-27300241P1607,480 ft——Yes
42-27300246P140 D———Yes
42-27300248P151 D———Yes
42-27300251P 53 C7,350 ft——Yes
42-27300254P 71 T7,032 ft—Apr 1975Yes
42-27300258P114 C———Yes
42-27300263P1307,200 ft—Nov 1978Yes
42-27300270P 88 T7,123 ft——Yes
42-27300276T 14———Yes
42-27300278M 5D7,200 ft——Yes
42-27300279M 3DT———Yes
42-27300282M 4DT6,790 ft—Nov 1982Yes
42-27300284M 6D———Yes
42-27300289P125 T8,000 ft—Mar 1992Yes
42-27300292P115 T———Yes
42-27300298T 67,200 ft—Jan 1984Yes
42-27300300T 9 C7,200 ft—Nov 1982Yes
42-27300302T 5 C7,252 ft—Sep 1985Yes
42-27300313P 677,559 ft—Feb 1987Yes
42-27300375P139———Yes
42-27300384P106 L7,200 ft——Yes
42-27300385P100 T———Yes
42-27300387P107 T———Yes
42-27300390P157———Yes
42-27300393P152 D———Yes
42-27300396P109 T———Yes
42-27300397P137 F———Yes
42-27300399P102 T———Yes
42-27301734T 167,202 ft—Sep 1982Yes
42-27301804P219 E7,125 ft—Dec 1981Yes
42-27300318P123 T7,324 ftMay 2013Apr 2025Yes
42-24902293A 24 D7,150 ftNov 2006Sep 2019Yes
42-27300319P 73 T7,120 ftAug 2005Nov 2011Yes
42-273003151747,271 ftJul 2004Mar 2012Yes
42-27331207P259 D7,100 ftSep 1997May 2006Yes
42-27330427P246 F7,360 ftJul 1997Aug 2006Yes
42-27301735A 27 F8,617 ftDec 1989Sep 1991Yes
42-27300288P126 T7,200 ftDec 1985Mar 1992Yes
42-27300314P1766,660 ftMay 1985Mar 1992Yes
42-27330373P243 T7,120 ftOct 1982Jan 1984Yes
42-27331370T 42 D7,160 ftDec 1979Mar 1984Yes
42-24902289A 147,413 ftJan 1979Mar 1992Yes
42-27300307P 86 T7,518 ftMay 1975Sep 1986Yes
42-27300149A 19 D7,551 ftMar 1975Dec 1990Yes
42-27300309P 81 C7,700 ftSep 1974Feb 1984Yes
42-27300150A 20 D7,400 ftMar 1974—Yes
42-27301741P191 D7,700 ftMar 1974Mar 1983Yes
42-27300293P1357,200 ft1974—Yes
42-24902280A 56,459 ftNov 1973Mar 1983Yes
42-27300327P194 F—Dec 1972—Yes
42-27300328P199 D6,769 ftMar 1972Jan 1992Yes
42-27300264P 947,555 ftAug 1970Jul 1984Yes
42-27300365P1697,075 ftJun 1968—Yes
42-24902282A 7 C5,668 ftDec 1960Nov 2023Yes

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 (47)

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

47 months

Nov 199612021.97—$264
Oct 1996251723.31—$583
Sep 1996341622.22—$755
Aug 1996361620.26—$729
Jul 1996366519.55—$704
Jun 1996473118.73—$880
May 1996482819.43—$933
Apr 1996305521.51—$645
Mar 1996562019.38—$1,085
Feb 1996581816.98—$985
Jan 19961582117.07—$2,697
Dec 19951501517.19—$2,579
Nov 19951551316.00—$2,480
Oct 19951531315.43—$2,361
Sep 19951741216.18—$2,815
Aug 19951282015.92—$2,038
Jul 19951831415.24—$2,789
Jun 19951715116.41—$2,806
May 19951252017.56—$2,195
Apr 19951411117.73—$2,500
Mar 19951231716.44—$2,022
Feb 1995109016.58—$1,807
Jan 1995136015.92—$2,165
Dec 199484015.03—$1,263
Nov 1994127915.90—$2,019
Oct 19941291015.58—$2,010
Sep 1994140115.29—$2,141
Aug 1994150316.13—$2,420
Jul 1994141117.56—$2,476
Jun 1994196117.09—$3,350
May 1994138115.88—$2,191
Apr 19941402614.14—$1,980
Mar 199492112.46—$1,146
Feb 1994142112.50—$1,775
Jan 1994291112.66—$3,684
Dec 199320112.33—$247
Nov 1993118114.49—$1,710
Oct 1993328015.85—$507
Sep 19932293815.03—$331
Aug 199337422715.66—$5,857
Jul 19932058815.46—$3,169
Jun 199311110116.79—$1,864
May 19931694817.68—$2,988
Apr 1993166618.05—$2,996
Mar 1993167118.14—$3,029
Feb 1993184117.90—$3,294
Jan 1993165116.93—$2,793

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.

Nov 1996 — as filed, then multipliedworked
Oil                   12 bbl  × $ 21.97 =       $264
Casinghead gas         0 Mcf  ×  no price            —

────────────────────────────────────────────────────
Month total                                     $264

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. 04/O/3031 is the state's own key, not one this site invented.