The Million Dollar Way (The Bakken Oil Blog)

Tuesday, April 14, 2020

Work In Progress -- PetroShale Wells In Croff Oil Field -- April 14, 2020

This is a work in progress. I became interested when I saw the huge jump in production for #17778, see below. Lots of activity in the area. This post yet to be completed.

See these wells:

21985; halo effect; t6/12; cum 526K 4/20;
17778; huge halo effect; cum 272K 4/20;

See these wells, also, but not yet posted:

18436; off line for past several months; now back on line; no halo effect; t3/10; cum 480K 4/20;
36316, 35, Petroshale, Anderson North 1MBH, Croff, t9/19; cum 134K 4/20;
36317, 584, Petroshale, Anderson North 1TFH, Croff, t10/19; cum 95K 4/20;
36318, 392, Petroshale, Anderson North 2MBH, Croff, t10/19; cum 441K 4/20; just came back on line, 3/20;
22377; went off line shortly before 10/19; has just come back on line; three days in 2/20; t7/12; cum 468K 4/20; came back on line 3/20;
22520; went off line shortly before 10/19; back on line for two months; no evidence of halo effect; t12/12; cum 434K 4/20; came back on line 1/20;

And later,

37073, conf,
37074, conf,
37075, conf,
37076, conf,
37077, conf,

The graphic:

Completing The Discussion On That "Pop-Quiz" Earlier Today -- April 14, 2020

This completes the blog I started earlier -- link here to the "pop-quiz" from earlier today.

A reminder: the NDIC now reports natural gas statistics for each well: the amount of natural gas produced by the well; the amount sold, and the amount vented/flared.

In the "old days,"

MFC produced = MCF sold + vented/flared;

But now, more and more, in the Bakken:

MFC produced ≠ MCF sold + vented/flared

Where is the "missing MCF (natural gas)?

A reader provides this:

Since the DMR has added the "Flared" column in wells' production profiles, it is now possible to determine how much produced natgas is consumed or re-injected (for gas lift Artificial Lift) for each well/pad.

This is determined by starting with gross production, then subtracting amount sold, then subtracting amount flared.

The remaining balance - if any - should be the amount burned onsite to power compressors and/or generators with the rest being injected back downhole for the now near-ubiquitous (in the Bakken, soon, everywhere) gas lift approach in the Artificial Lift phase.

(There are at least 3 main subsets to this, but I am still trying to gather information).

Bottom line, using the two Lime Rock wells from today - #24511 and #-33634 - one finds: ~500 M cubic feet/month consumed for the former, with ~ 800 M cubic feet/month for the latter.

(I started tracking this months ago with the 500,000 cubic feet per month per well being about average).

Using a VERY generous 'retail' price of $2/mmbtu - essentially $2.00 for every thousand feet of natgas - these operators are 'paying' (to themselves, no less) between $1,000 and $1,600 per MONTH for the use of this natgas.

In reality, these operators - Lime Rock, in this example - are getting FREE fuel for their equipment and re-injection purposes. Equipment seems mainly to consist of the aforementioned compressors and generators.

Very little info seems to be in the public domain in these matters.

Absolutely fascinating.

US Crude Oil In Storage -- April 14, 2020

US crude oil storage: I have no idea how accurate this graphic is but if accurate, it's very helpful.

Days US supply: link here. This data will be updated by the EIA on April 15, 2020, tomorrow.

The EIA weekly petroleum report will be released tomorrow, April 15, 2020. Link here.

These graphics are a week old; the new data will be posted tomorrow.

So, we wait until 9:30 a.m. CT tomorrow.

The Enerplus "Geo Features" Pad

The wells:

37513, PNC, Enerplus, Oxbow 152-94-16BH-21H-TF, Antelope,
37514, PNC, Enerplus, Plateau 152-94-16BH-21H, Antelope,
33461, 840, Enerplus, Mesa 152-94-16A-21H, Three Forks, 30 stages; 2.3 million lbs; Antelope-Sanish, t3/18; cum 209K 9/20; permitted for middle Bakken, but changed to Three Forks first bench, July 1, 2020; cum 224K 7/21; cum 234K 4/22; subtle jump in production, 4/22;
33460, 1,687, Enerplus, Gully 152-94-16A-21H-TF1, 39 stages, 9.4 million lbs, Antelope-Sanish, t3/18; cum 335K 9/20; cum 358K 7/21; cum 358K 7/21; cum 370K 4/22;
33459, 1,192, Enerplus, Canyon 152-94-16A-21H-TF2, 39 stages, 9.5 million lbs; Antelope-Sanish, t3/18; cum 365K 9/20; permitted for Three Forks B2, but sundry form dated July 1, 2017, target change to middle Bakken "D." Cum 420K 7/21; cum 450K 3/22; off line 4/22;
33458, 1,115, Enerplus, Ravine 152-94-16A-21H, 39 stages; 8.2 million lbs; Antelope-Sanish, t11/17; cum 376K 9/20; cum 414K 7/21; cum 435K 3/22; off line 4/22;

The graphics:

WTI Barely Holds Above $20; Enerplus Adds Two "Geo Features" Play Wells -- April 14, 2020

Active rigs:

$20.11	4/14/2020	04/14/2019	04/14/2018	04/14/2017	04/14/2016
Active Rigs	34	63	61	51	30

Three new permits, #37513 - #37515, inclusive --

Operators: Enerplus (2); MRO
Field: Antelope (McKenzie); Reunion Bay (Mountrail)
Comments:

MRO has a Pelarske USA permit for NENE section 8-151-93, Reunion Bay;
Enerplus added two permits to its "Geo Features" play, in NENW section 16-152-94,

Oxbow .... TF ... 486 FNL 2384 FWL
Plateau .. MB ... 485 FNL 2294 FWL (surface separation, slightly more than 22 feet)

One dry hole:

32464, dry, BR, CCU Burner 1-1-26TFH, Corral Creek; the hole was plugged after having problems with hole stability and running intermediate casing;

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Enerplus' "Geo Features" Play