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WEST RANCH -A-

Operated by HILCORP ENERGY COMPANY (P-5 386310) in the WEST RANCH (41-A & 98-A CONS.) field. Every figure below is a volume the Railroad Commission published, multiplied by a monthly price you can check.

Oil lease lease 10962District 02Field 96545691OilCasinghead gasSaveExport
Value, all time
$2.2 M
Feb 2015 – Mar 2017
Value, last 12 filed months
$527 k
at the published price for each month
Months reported
25
1 month not filed
Streams
2
oil, casinghead gas

The WEST RANCH (41-A & 98-A CONS.) 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 8 leases and 337 wells, and the rule below applies to all of them.

Discovered
2014-01-27
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 10 acres. The field rule took effect on 2015-01-27.

The Commission's schedule remark for this field reads: “NUNC PRO TUNC FOR DOCKET 02-0292677 FOR CORRECTION TO FIELD NAME.”

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
OilDisposition50,963 bbl$2,146,134
Casinghead gasProduction36,891 Mcf$89,921
Total$2,236,055

Wells on this lease (80)

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 28.7916, -96.6108. A lease has no coordinate of its own — that point is the mean of its wells, and they span 1.7 miles.

28.79009, -96.61119 · 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
31.3%
25 of 80 wells
With a plug date
16.3%
13 of 80 wells
Median depth
6,412 ft
80 wells filed one
Completion to plug
22.9 years
median over 13 wells

What the state filed about each well

On the RRC proration schedule
2531.3%
A plug date is filed
1316.3%
BothOn the schedule and plugged. Neither fact cancels the other.
1316.3%
NeitherNo plug date, and not on the schedule.
5568.8%

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, 80 of 80 wells. Median 6,412 ft, with the middle half between 6,338 and 6,470 ft; the shallowest is 5,755 ft and the deepest 8,465 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, 80 of 80 wells, Dec 1978 – Apr 2026. 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 1978 – Apr 2026
80 of 80 wells
Plug dates filed
Dec 2015 – Sep 2017
13 of 80 wells; 67 filed none

Last completion to plug: a median of 22.9 years across the 13 wells that filed both dates, with the middle half between 5.1 years and 25.9 years. The gap is the distance between two filed dates. It is not a statement of how long the well produced.

80 wells

42-2393366610376,038 ftApr 2026——
42-2393368510166,410 ftFeb 2026——
42-2393367110386,410 ftJan 2026——
42-2393369410406,271 ftNov 2024——
42-2393365210596,399 ftNov 2024—Yes
42-2393365910616,409 ftOct 2024——
42-239335816016,519 ftSep 2024—Yes
42-2393366710076,400 ftAug 2024——
42-239026743266,500 ftMay 2024——
42-2393368710196,401 ftApr 2024——
42-2393366420296,475 ftApr 2024——
42-2393367210096,420 ftApr 2024——
42-2393367810126,400 ftApr 2024——
42-2393366910066,430 ftMar 2024——
42-2393370910716,485 ftMar 2024——
42-2393368410156,406 ftMar 2024——
42-239322095126,429 ftFeb 2024——
42-2393368810186,469 ftFeb 2024——
42-2393367310086,410 ftJan 2024——
42-2393370810706,479 ftJan 2024——
42-239027213746,305 ftJan 2024—Yes
42-2393369510636,413 ftJan 2024——
42-2393370710696,438 ftDec 2023——
42-2393373721796,444 ftJul 2023——
42-2393370310216,469 ftJun 2023——
42-2393369310396,423 ftDec 2022——
42-2393368610176,400 ftNov 2022——
42-239027203736,401 ftOct 2022—Yes
42-2393370510646,440 ftOct 2022——
42-2393366810626,418 ftOct 2022——
42-2393365520576,400 ftOct 2022——
42-2393365810606,408 ftAug 2022——
42-2393365710366,408 ftAug 2022——
42-2393369120556,414 ftJul 2022——
42-2393366510056,430 ftJul 2022——
42-2393367520216,428 ftMay 2022——
42-239335806006,500 ftApr 2022——
42-2393368310146,461 ftMar 2022——
42-2393366110046,416 ftAug 2021——
42-2393366220206,435 ftNov 2020——
42-23902679332R6,354 ftSep 2020——
42-2393368121506,503 ftAug 2020——
42-23931253491 L6,222 ftJun 2020——
42-2393371010726,478 ftJan 2020——
42-2393367610106,430 ftJan 2020——
42-2393377410796,490 ftJan 2020——
42-2393369210206,427 ftJan 2020——
42-239312414856,231 ftDec 2019—Yes
42-239026943476,556 ftNov 2019—Yes
42-2393367910136,408 ftSep 2019——
42-239026623146,475 ftJul 2019—Yes
42-2393367710116,448 ftMay 2019——
42-239027403935,854 ftMay 2019—Yes
42-239027894436,480 ftNov 2018—Yes
42-239026873406,352 ftSep 2018——
42-239026192695,755 ftNov 2017—Yes
42-23902368136,493 ftAug 2017——
42-239026202715,775 ftAug 2017——
42-239026332856,191 ftAug 2017——
42-239026412936,300 ftAug 2017——
42-239312544906,248 ftAug 2017——
42-23932134509 J6,360 ftJun 2016——
42-239026773306,190 ftApr 2016—Yes
42-239308294796,235 ftMar 2016——
42-239026843376,970 ftJan 2016—Yes
42-239026422946,303 ftAug 2012Aug 2016Yes
42-23931250487R6,474 ftJul 2012Apr 2016Yes
42-239024651106,330 ftJul 2012Dec 2015Yes
42-239302074736,480 ftJun 2012Jul 2017Yes
42-239026593116,501 ftSep 2009——
42-239323545188,465 ftAug 2008——
42-23902747400 L6,225 ftFeb 2002Sep 2017Yes
42-23902735388 L5,852 ftJun 1994Jan 2017Yes
42-23902403486,580 ftOct 1993Sep 2016Yes
42-239026442966,340 ftAug 1991Sep 2016Yes
42-239026883416,324 ftJul 1991Dec 2015Yes
42-239320125056,410 ftSep 1990Aug 2016Yes
42-239303804765,865 ftAug 1987Oct 2016Yes
42-239302214746,300 ftApr 1987Oct 2016Yes
42-239025762216,503 ftDec 1978Sep 2016Yes

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 (25)

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

25 months

Mar 20170046.772.98$0
Feb 20170050.452.95$0
Jan 20170049.413.42$0
Dec 20160048.763.72$0
Nov 20160042.492.64$0
Sep 20160041.553.10$0
Aug 20160041.442.92$0
Jul 20160041.622.92$0
Jun 20163,8551,20445.352.69$178,058
May 20162,6441,34042.521.99$115,091
Apr 20163,4321,70836.561.99$128,875
Mar 20162,9643,99133.011.79$105,002
Feb 20162,5343,31926.472.06$73,924
Jan 20162,9878,91727.352.36$102,777
Dec 20152,0501,35932.362.00$69,058
Nov 20152,23451938.792.17$87,782
Oct 20152,72650043.552.43$119,931
Sep 20152,65858142.992.76$115,870
Aug 20153,0465440.162.87$122,482
Jul 20153,24961348.152.95$158,245
Jun 20152,584056.152.88$145,092
May 20153,63796255.212.96$203,642
Apr 20153,8913,48949.822.71$203,293
Mar 20153,7994,51742.892.93$176,195
Feb 20152,6733,81844.662.98$130,739

Not filed, and not zero: Oct 2016. The Railroad Commission holds no report for those months, so this page shows none — a zero would state that the lease produced nothing.

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.

Jun 2016 — as filed, then multipliedworked
Oil                3,855 bbl  × $ 45.35 =   $174,824
Casinghead gas     1,204 Mcf  × $  2.69 =     $3,234

────────────────────────────────────────────────────
Month total                                 $178,058

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. 02/O/10962 is the state's own key, not one this site invented.