RAFE
Operated by FDL OPERATING, LLC (P-5 263924) in the STA (ATOKA) 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 7 leases and 9 wells, and the rule below applies to all of them.
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 | 37,417 bbl | $1,657,015 |
| Casinghead gas | Production | 1,306,713 Mcf | $3,467,960 |
| Total | $5,124,975 | ||
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 31.6334, -102.3266. A lease has no coordinate of its own — that point is the mean of its wells, and they span 0.5 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 10,768 and 10,880 ft, median 10,826 ft, over the 3 wells that filed a depth.
Last completion to plug: a median of 6.8 years across the 1 well that filed both dates, with the middle half between 6.8 years and 6.8 years. The gap is the distance between two filed dates. It is not a statement of how long the well produced.
3 wells
| 42-10336509 | 9 | 10,880 ft | Jun 2017 | — | Yes |
| 42-10336510 | 10 | 10,826 ft | Jun 2017 | — | Yes |
| 42-10336503 | 5 | 10,768 ft | Apr 2017 | Jan 2024 | Yes |
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 (36)
Volume × price = value, one row per cycle. The price columns are the same series published on the prices page — nothing here is modelled.
36 months
| Mar 2018 | 0 | 0 | 61.22 | 2.79 | $0 |
| Feb 2018 | 0 | 0 | 61.78 | 2.77 | $0 |
| Jan 2018 | 0 | 0 | 62.87 | 4.01 | $0 |
| Dec 2017 | 0 | 0 | 57.27 | 2.92 | $0 |
| Nov 2017 | 0 | 0 | 55.42 | 3.12 | $0 |
| Oct 2017 | 0 | 0 | 49.29 | 2.98 | $0 |
| Sep 2017 | 0 | 0 | 47.52 | 3.09 | $0 |
| Aug 2017 | 0 | 0 | 45.37 | 3.00 | $0 |
| Jul 2017 | 0 | 0 | 43.87 | 3.09 | $0 |
| Jun 2017 | 0 | 0 | 42.49 | 3.09 | $0 |
| May 2017 | 14 | 0 | 45.37 | 3.26 | $635 |
| Apr 2017 | 574 | 26,275 | 47.93 | 3.21 | $111,897 |
| Mar 2017 | 668 | 30,797 | 46.77 | 2.98 | $123,131 |
| Feb 2017 | 743 | 30,952 | 50.45 | 2.95 | $128,873 |
| Jan 2017 | 762 | 32,392 | 49.41 | 3.42 | $148,392 |
| Dec 2016 | 736 | 40,093 | 48.76 | 3.72 | $185,147 |
| Nov 2016 | 882 | 34,614 | 42.49 | 2.64 | $129,008 |
| Oct 2016 | 1,032 | 45,137 | 46.19 | 3.09 | $187,153 |
| Sep 2016 | 890 | 48,083 | 41.55 | 3.10 | $186,067 |
| Aug 2016 | 954 | 51,686 | 41.44 | 2.92 | $190,681 |
| Jul 2016 | 1,037 | 53,917 | 41.62 | 2.92 | $200,832 |
| Jun 2016 | 1,201 | 53,746 | 45.35 | 2.69 | $198,818 |
| May 2016 | 1,195 | 59,312 | 42.52 | 1.99 | $168,904 |
| Apr 2016 | 1,181 | 57,392 | 36.56 | 1.99 | $157,447 |
| Mar 2016 | 1,046 | 51,760 | 33.01 | 1.79 | $127,386 |
| Feb 2016 | 985 | 38,099 | 26.47 | 2.06 | $104,695 |
| Jan 2016 | 1,386 | 56,376 | 27.35 | 2.36 | $171,200 |
| Dec 2015 | 1,354 | 56,729 | 32.36 | 2.00 | $157,353 |
| Nov 2015 | 1,856 | 75,580 | 38.79 | 2.17 | $235,801 |
| Oct 2015 | 2,531 | 89,968 | 43.55 | 2.43 | $328,540 |
| Sep 2015 | 3,033 | 87,050 | 42.99 | 2.76 | $370,509 |
| Aug 2015 | 2,676 | 63,477 | 40.16 | 2.87 | $289,805 |
| Jul 2015 | 2,515 | 51,253 | 48.15 | 2.95 | $272,041 |
| Jun 2015 | 2,916 | 63,686 | 56.15 | 2.88 | $347,331 |
| May 2015 | 4,554 | 96,428 | 55.21 | 2.96 | $536,414 |
| Apr 2015 | 696 | 11,911 | 49.82 | 2.71 | $66,913 |
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 14 bbl × $ 45.37 = $635 Casinghead gas 0 Mcf × $ 3.26 = $0 ──────────────────────────────────────────────────── Month total $635
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/46703 is the state's own key, not one this site invented.