UL 3
Operated by DIAMONDBACK E&P LLC (P-5 217012) in the SPRABERRY (TREND AREA) field. Every figure below is a volume the Railroad Commission published, multiplied by a monthly price you can check.
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 16,587 leases and 43,997 wells, and the rule below applies to all of them.
A drilling unit in this field needs at least 80 acres. The field rule took effect on 2018-02-13.
The Commission's schedule remark for this field reads: “SPRABERRY (TREND AREA) FIELD EFFECTIVE 10/1/2019.”
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.
| Stream | Basis | Volume | Value |
|---|---|---|---|
| Oil | Disposition | 19,210 bbl | $1,725,365 |
| Casinghead gas | Production | 28,447 Mcf | $95,924 |
| Total | $1,821,290 | ||
Wells on this lease (3)
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 32.2592, -102.4407. A lease has no coordinate of its own — that point is the mean of its wells, and they span 0.6 miles.
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.
What the state filed about each well
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
Between 9,084 and 11,330 ft, median 11,050 ft, over the 3 wells that filed a depth.
3 wells
| 42-00341770 | 11 | 9,084 ft | Nov 2021 | — | Yes |
| 42-00344418 | 7 | 11,050 ft | Sep 2012 | — | — |
| 42-00343931 | 2 | 11,330 ft | Apr 2012 | — | — |
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 (35)
Volume × price = value, one row per cycle. The price columns are the same series published on the prices page — nothing here is modelled.
35 months
| Sep 2013 | 0 | 0 | 104.11 | 3.72 | $0 |
| Aug 2013 | 0 | 0 | 104.25 | 3.52 | $0 |
| Jul 2013 | 0 | 0 | 102.52 | 3.72 | $0 |
| Jun 2013 | 366 | 0 | 94.40 | 3.93 | $34,550 |
| May 2013 | 1,399 | 1,567 | 94.83 | 4.15 | $139,169 |
| Apr 2013 | 1,076 | 1,812 | 93.96 | 4.28 | $108,861 |
| Mar 2013 | 1,768 | 2,034 | 93.62 | 3.91 | $173,479 |
| Feb 2013 | 1,377 | 1,850 | 91.23 | 3.42 | $131,951 |
| Jan 2013 | 1,042 | 1,851 | 91.60 | 3.42 | $101,777 |
| Dec 2012 | 1,716 | 1,788 | 86.77 | 3.42 | $155,013 |
| Nov 2012 | 1,778 | 2,445 | 86.95 | 3.62 | $163,460 |
| Oct 2012 | 1,950 | 3,053 | 89.38 | 3.40 | $184,670 |
| Sep 2012 | 520 | 1,509 | 94.67 | 2.92 | $53,632 |
| Aug 2012 | 817 | 1,866 | 92.66 | 2.91 | $81,130 |
| Jul 2012 | 1,203 | 3,884 | 85.13 | 3.02 | $114,144 |
| Jun 2012 | 1,734 | 2,326 | 79.82 | 2.52 | $144,267 |
| May 2012 | 1,588 | 1,146 | 91.61 | 2.49 | $148,328 |
| Apr 2012 | 8 | 0 | 101.65 | 2.00 | $813 |
| Mar 2012 | 166 | 0 | 105.05 | 2.22 | $17,438 |
| Feb 2012 | 0 | 0 | 101.10 | 2.57 | $0 |
| Jan 2012 | 0 | 0 | 98.09 | 2.73 | $0 |
| Dec 2011 | 1 | 0 | 96.87 | 3.24 | $97 |
| Nov 2011 | 172 | 0 | 95.72 | 3.31 | $16,464 |
| Oct 2011 | 2 | 0 | 84.98 | 3.65 | $170 |
| Sep 2011 | 0 | 0 | 83.62 | 3.99 | $0 |
| Aug 2011 | 0 | 0 | 83.40 | 4.15 | $0 |
| Jul 2011 | 0 | 0 | 94.14 | 4.52 | $0 |
| Jun 2011 | 179 | 0 | 92.90 | 4.64 | $16,629 |
| May 2011 | 1 | 0 | 98.13 | 4.40 | $98 |
| Apr 2011 | 0 | 0 | 105.96 | 4.33 | $0 |
| Mar 2011 | 0 | 699 | 96.36 | 4.06 | $2,836 |
| Feb 2011 | 165 | 617 | 85.64 | 4.18 | $16,710 |
| Jan 2011 | 0 | 0 | 86.50 | 4.59 | $0 |
| Dec 2010 | 182 | 0 | 85.73 | 4.35 | $15,603 |
| Nov 2010 | 0 | 0 | 80.84 | 3.80 | $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.
Oil 366 bbl × $ 94.40 = $34,550 Casinghead gas 0 Mcf × $ 3.93 = $0 ──────────────────────────────────────────────────── Month total $34,550
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. 08/O/40818 is the state's own key, not one this site invented.