Shout-Out To A Bruin Fort Berthold Well Drilled In 2013 -- Just Went Over 500,000 Bbls -- November 11, 2019

The well:

• #20879 has two laterals, drilled at separate times. They have different names: -1H and -2H but yet carry the same permit number, #20879.
• 20879, 2,709, Bruin/HRC, Fort Berthold 147-94-1A-12-2H, McGregory Buttes, t1/14; cum 501K 9/19; off-line as of 9/18; see this note, 10/18; back on line 11/18; nice recovery with production now again over 2,000 bbls/month

**********************************

Others

The well:

This well was spud 4/5/2010 and 7/5/11 (see scout ticket below):

• 18341, 567, HRC, Fort Berthold 147-94-1A-12-1H, t10/11; cum 660K 9/19;

It was not completed until more than a year later, 10/26/2.

• 10/7/11: an open hole, 29-stage frack, with 3 million lbs sand;
• 6/29/10: an open hole frack attempted, 200,000 lbs sand; "the well was killed after flowback frac due to fishing for wireline. This lateral has also been plugged back.

The well:

• 27522, 4,207, Whiting, Flatland Federal 11-4TFHU, Twin Valley, spacing: 2560-acre; t10/14; cum 553K 9/19; huge jump, 3/19 from 3,000 bbls/month to 14,000 bbls/month;

The well:

• 20342, 1,430, Petro-Hunt, USA 153-95-4B-9-1H, t11/11; cum 1.026493 million bbls; went IA 1/14; still inactive as of 6/14; back on line and tracked here; huge jump in 7/17; another huge jump, 1/19;

This well just went over 500,000 bbls:

• 19981, 1,003, Zavanna, Gust 2-11 1H, Long Creek, t3/12; cum 509K 9/19; and still producing very nicely, 9/19;

Random Update On An Incredible Halcon Well, McGregory Buttes -- July 23, 2014

Over at "Things To Follow Up On," here's the update on an incredible Halcon well:

#20879 has two laterals, drilled at separate times. They have different names: -1H and -2H but yet carry the same permit number, #20879.

• 20879, 2,709/A/IA, Bruin/HRC, Fort Berthold 147-94-1A-12-2H, McGregory Buttes, t1/14; cum 486K 10/18; back off-line 9/18;

From the well file back in early 2013:

Frac Notes: Plug & Perf - 30 stages planned. At Stage 2, a 2,000 psi drop was observed, previous well operator, Petro-Hunt, directed contractor HES to repair sand conveyor belt, no ball seated at Stage 3. Job was shutdown by P-H anticipating a casing or tool string failure. Well to be TA'd by current operator until final cost of casing repair is determined. In March and April 2013, well flowed naturally for 4 and 13 days, respectively, and is no longer flowing. 

From the well file while drilling the lateral: gas levels at this point in the lateral were already quite [high], often averaging over 3,000 units and sometimes exceeding 9,000 units.... but was probably due to "bad" gas detector. Later, gas readings were down to 600 units with burst flares of 10 - 15 feet.

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	5-2014	31	25227	25299	10399	15775	3280	12278
BAKKEN	4-2014	30	25081	24970	12861	22524	18420	3894
BAKKEN	3-2014	31	36784	36817	14650	32178	31961	0
BAKKEN	2-2014	28	48122	47882	21409	39899	36656	3047
BAKKEN	1-2014	13	25326	24891	21916	16276	6344	9841
BAKKEN	12-2013	0	0	0	0	0	0	0
BAKKEN	11-2013	0	0	0	0	0	0	0
BAKKEN	10-2013	1	0	421	50	7	0	0
BAKKEN	9-2013	0	0	0	0	0	0	0
BAKKEN	8-2013	0	0	0	0	0	0	0
BAKKEN	7-2013	0	0	0	0	0	0	0
BAKKEN	6-2013	0	0	0	0	0	0	0
BAKKEN	5-2013	0	0	0	0	0	0	0
BAKKEN	4-2013	13	3727	3306	1250	2868	0	2777
BAKKEN	3-2013	4	966	966	896	794	0	79

Wells Coming Off Confidential List Early In The Week -- May 21, 2017

Wednesday, May 24, 2017

• 31716, 184, Crescent Point Energy, CPEUSC Aldag 3-35-36-164N-100W, runs west to east (23321, 30622), West Ambrose, t3/17; cum --
• 33156, 439, Sedalia Energy, Pratt Madison Unit 3H, Pratt, t1/17; cum 24K 3/17; , note: at this post, a graphic showing how Sedalia Energy drilled three laterals from one Madison well;

Madison wells are not fracked; no stimulation. In addition, these have been short laterals, so far. Vertical depth at 4,000 feet is about half that of a Bakken well. Madison wells typically don't have the "dreaded" Bakken decline rate. Shallow, short laterals, no fracking, and steady production over many years; previously Madison wells were simply vertical wells; now horizontal wells.

This is really quite a nice well, Sedalia, #33156: 

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
MADISON	3-2017	31	9087	9374	46420	0	0	0
MADISON	2-2017	28	11439	11005	45914	0	0	0
MADISON	1-2017	11	3586	3335	36484	0	0	0

Tuesday, May 23, 2017

• 31575, 1,530, QEP, TAT 8-33-28BHD, Grail, 65 stages, 9.4 million lbs, t12/16; cum 101K 3/17;
• 31576, 1,392, QEP, TAT-5-33-28T2HD, Grail, Three Fork 2nd bench, 51 stages, 9.6 million lbs, t12/16; cum 70K 3/17;
• 31577, 1,800, QEP, TAT 7-33-28BHD, Grail, t12/16; cum 110K 3/17;
• 31829, 1,470, QEP, TAT 4-33-28T2HDR, Grail, Three Forks 2nd bench, 65 stages, 10.1 million lbs, t12/16; cum 24K 3/17;,  (26521, 26522, 26523, 26524)(27792, 27791, 27816, 21465)
• 33169, SI/NC, Enerplus, Elbert 148-95-12D-01H-TF, Eagle Nest, no production data,

Monday, May 22, 2017

• 30623, 210, Crescent Point Energy, CPEUSC Fairholm 3-34-33-164N-100W, West Ambrose, Three Forks, 35 stages, 2.8 million lbs, t3/17; cum 8K first month -- then taken off-line,  runs east to west (31568, 22732); first month's production: 7,275 bbls;

Sunday, May 21, 2017

• 30725, 658, NP Resources, Beaver Creek State 41-36-1PH, Roosevelt, Pronghorn/Three Forks, 36 stages, 5.6 million lbs, t1/17; cum 19K 3/17;  
• 32505, 865, HRC, Fort Berthold 147-94-1A-12-12H, (20879), McGregory Buttes, Three Forks, 33 stages, 9.9 million lbs, t12/16; cum 64K 3/17; on Halcon's "Oklahoma" pad;

Saturday, May 20, 2017

• None.

****************************************

 32505, see above, HRC, Fort Berhold 147-94-1A-12-12H, (20879), McGregory Buttes:

Date	Oil Runs	MCF Sold
3-2017	21553	18149
2-2017	19686	12730
1-2017	13844	5085
12-2016	8744	5361
11-2016	132	0

30725, see above, NP Resources, Beaver Creek State 41-36-1PH, Roosevelt:

Date	Oil Runs	MCF Sold
3-2017	4756	2506
2-2017	11963	5608
1-2017	1356	0
12-2016	226	0

31829, see above, QEP, TAT 4-33-28T2HDR, Grail:

Date	Oil Runs	MCF Sold
3-2017	2968	2102
2-2017	3012	2761
1-2017	4093	3126
12-2016	13559	11541

31577, see above, QEP, TAT 7-33-28BHD, Grail:

Date	Oil Runs	MCF Sold
3-2017	22606	35126
2-2017	25906	34527
1-2017	27330	37397
12-2016	32905	22297
11-2016	1164	858

31576, see above, QEP, TAT-5-33-28T2HD, Grail:

Date	Oil Runs	MCF Sold
3-2017	18963	30055
2-2017	13783	20569
1-2017	10770	14828
12-2016	25452	15419
11-2016	397	317

31575, see above, QEP, TAT 8-33-28BHD, Grail:

Date	Oil Runs	MCF Sold
3-2017	18156	18186
2-2017	22617	29745
1-2017	22958	32472
12-2016	36559	41182
11-2016	416	443

33156, see above, Sedalia Energy, Pratt Madison Unit 3H, Pratt:

Date	Oil Runs	MCF Sold
3-2017	9374	0
2-2017	11005	0
1-2017	3335	0

Case Study -- Bakken Well -- Bruin -- Fort Berthold -- McGregory Buttes -- #20879

This page won't be updated. See this note for background. This is what makes unconventional drilling / shale oil / tight oil so exciting.

As I've mentioned many times before, over the course of a Bakken well's lifetime -- 35 years -- the well will see work-over rigs; will undergo mini-re-fracks; and, major re-fracks. Existing wells will be impacted by neighboring wells. The wells will not follow a simple/conventional "depletion" rate curve.

Here's another example.
I followed this well for quite awhile some time and then removed it from the list of wells that needed to be followed.

The well:

• 20879, 2,709, Bruin/HRC, Fort Berthold 147-94-1A-12-2H, McGregory Buttes, t1/14; cum 486K 10/18; back off-line 9/18;

I quit following this well back in 2014 after the successful frack. Since then, it has been an outstanding well, with the typical Bakken decline.

Now I see that this well is back off line. Full production profile here.

There is a lot of activity in this area, as one can see in the graphic below.

Other wells of interest in the graphic:

• 32503, off line as of 10/18; t12/16; cum 295K 9/18;
• 32505, production jump form 3,000 bbls/month (9/18) to 7,000 bbls/month (10/18) but it looks like it might have been off-line much of 8/18 and 9/18; and now back on line for the full month; t12/16; cum 249K 10/18;
• 30680, 823, Bruin, Fort Berthold 147-94-1A-12-9H, McGregory Buttes, t8/15; cum 348K 8/18;

Simple Housekeeping -- Reposting Previously Posted Material -- November 4, 2015

This is simply some housekeeping. Nothing new here. This has all been posted before. The page where this came from was getting too long. These are wells that I was watching for some reason or other; once I saw what I wanted to see, I "closed" them out.

I no longer follow these wells.

CLOSED

Page 5

Page 4

Page 3

Page 2

Page 1

January 27, 2016:  Fidelity has been sold by MDU in five separate deals; they have not been formally announced. We need to watch operator changes for Fidelity wells. For example, these two Fidelity wells were chronologically next to each other (Limestone Resources bought the Fidelity assets in this area some time ago -- not part of the recent entire Fidelity sale. Turns out that Kaiser-Francis was the operator who got the lion's share of the Fidelity wells:

• 24052, 738, Kraken/Kaiser-Francis/Fidelity, Wayne 3-4-33H, Sanish, 4 sections, 4/13; cum 277K 10/20; small jump in production 8/19;
  
• 24511, 52, Lime Rock Resources/Fidelity, Irene 12-13H-24, Alger, t4/13; cum 167K 10/20; went off line 5/19; back on line and good production, as of 9/19;

December 5, 2015: was waiting to post fracking data -- posted -- can be moved to "Closed" status:

• 25467, 1,821, Whiting, Privratsky 11-27PH, Zenith, Three Forks (Pronghorn), 40 stages, 3.04 million lbs, t3/14; cum 201K 10/20;
  
• 25468, 1,920, Whiting, Privratsky 21-27PH, Three Forks (Pronghorn), 40 stages, 3 million lbs, t3/14; cum 244K 10/20;
  
• 25469, 2,272, Whiting, Privratsky 41-27PH, Zenith, Three Forks (Pronghorn), 40 stages; 3 million lbs sand; t3/14; cum 243K 10/20;

November 16, 2015: 25924, 55, Hess, EN-Jeffrey A 155-94-2734H-5, Alkali Creek, 4 sections, t6/14; cum 184K 10/20; 34 stages; 3.5 million lbs sand. [Update, November 18, 2014: this well was fracked 2/14; still having problems. Zero bbls June/July, 2014; 25K in 27 days in August, 2014 -- was that a commingling error; but then only 9K bbls in 21 days in September; paperwork for commingling submitted. Update, June 13, 2015: looks like well is back on track]; off line as of 7/19;


November 3, 2015: follow up on this re-frack? #20755. Not a re-frack; simply some work on the pad mostly likely. Nothing to see here. This item closed November 3, 2015. But it's still a good well; cum 393K 10/20;


June 17, 2015: I need to complete the January, 2015, dockets.

September 19, 2015:

• Permitted for re-entry: 16439, 373, MRO, Hecker 21-5H, Murphy Creek, t9/07; cum 315K 10/20; last on-line 11/14; still off-line as of 6/15; back on ACTIVE status on/about 6/15; tracked here; back on line 4/18 and doing very, very well as of 9/19; continues to do well in 10/20;
  

September 27, 2014:

• 19294, PNC, Whiting, BSMU 3605, a Madison well;

Note these very low IPs for EOG in the Parshall; these wells were noted in the July 28, 2014, daily activity report, but on November 18, 2014, when re-checked, they were both back on confidential, and no IP was provided at the NDIC site. I now track both these wells here:

• #27441 - EOG RESOURCES, INC., PARSHALL 65-14H, NWNW 14-152N-90W, MOUNTRAIL CO., 446 BOPD, 2354 BWPD - BAKKEN
  #27442 - EOG RESOURCES, INC., PARSHALL 66-14H, NWNW 14-152N-90W, MOUNTRAIL CO., 394 BOPD, 2376 BWPD - BAKKEN

• 27441, 446, EOG, Parshall 65-14H, Parshall, short lateral, t7/14; from the file report, after reaching TD, gas reached a max of 10,000 units as the well began to flow; 25 stages, 7.6 million lbs; cum 131K 10/10; off line 4/19; remains off line 9/19;
  
• 27442, 394, EOG, Parshall 66-14H, Parshall, short lateral, t7/14; 19 stages, 5.8million lbs; cum 118K 3/20; intermittent since then; remains off line 10/20; went off line 1/19; back on line 9/19;

26335, PA/18, MRO, Powell 31-27TH, Wildcat, Tyler, t4/15; cum 638 bbls 4/15;  the second Tyler well "everyone" is waiting for, 24 stages; 800K lbs (minimal frack); t8/14; cum 434 bbls; apparently this well will be PNA in May, 2015; PNA as of 6/20/15;

A comment from a reader, received June 27, 2014:

I'm a non-op partner in 143-97 Leroy Petry Oxy well (#26370).  One of my buddies got his first check today and along with it was a letter saying OXY is selling part of its assets to Merit Energy.  Thought I would pass along.  When I get my paperwork I'll let you know; update July 3, 2015 -- still an OXY USA well; Lime Rock;

December 1, 2014, 4:44 p.m. CT: for some inexplicable reason, the number of active rigs in North Dakota jumped from 183 on Black Friday, November 28, 2014, to 189 on Monday, December 1, 2014 during some of the most miserable weather ever in the history of the Bakken boom during the late days of November. If the active rig rate holds or actually increases despite the slump in oil prices, one needs to ask the question, why? This could be an unintended consequence of the slump in oil prices, as operators start to circle the wagons and start to drill the better spots to "stay alive." If the marginal shale plays in the US see a decrease in rig counts, some operators to maintain their production or meet their contracts, may start to move their rigs to the better spots. The Bakken is known for a) consistency; b) reliability; c) adequate takeaway; d) improving infrastructure. So we'll see. I will not put this in a stand-alone post for several reasons. [Update, March 20, 2015 -- my irrational exuberance got ahead of me -- rigs plunged; now stand at 107. Update, June 13, 2015 -- my irrational exuberance got way ahead of me -- active rigs have plunged to lowest post-boom record, at 76]


April 9, 2015: need to get frack data on these two wells

• 28075, 3,255, MRO, Anthony USA 23-14H, Moccasin Creek, 2.5 section-long horizontal; 100% within the middle Bakken; 93% within MOC geology defined target interval; gas max at 1,300 units; 3,840 acres drilling unit; 23,148 feet TD; 43 stages; 4.5 million lbs; t2/15; cum 503K 10/20;
  
• 28076, 3,255, MRO, Hale USA 23-14TFH, Moccasin Creek, 2.5 section-long horizontal; Three Forks, 100% within the Three Forks Formation; 69% within the MOC geology defined target interval;  gas units very, very low; a 1 - 5' intermittent flare near the end of the lateral; 23,148 feet TD; 43 stages; 4.5 million lbs; t2/15; cum 271K 9/19; 296K 10/20;
  

October 16, 2014: nomenclature of this well? #29727 -- Eide 41-13HU. This well is on 4-acre spacing;

• 29727, 2,319, Whiting, Eide 41-13HU, 4 sections, middle Bakken; 30 stages; 3.4 million lbs; seam 22 feet thick?; max gas at 4,697 units, a consistent 2 - 5 foot flare; t2/15; cum 242K 10/20; jump in production, 7/19;

October 12, 2014: 20342, 1,430, Petro-Hunt, USA 153-95-4B-9-1H, t11/11; cum 900K 10/18; cum 1.140061 million bbls 10/20; went IA 1/14; still inactive as of 6/14; back on line and tracked here; according to NDIC this well has never been re-fracked since the 2011 frack; that is confirmed by FracFocus; update here;

September 11, 2014: several Oasis wells with very short horizontals; in the process of being completed? I had not seen this before (or don't recall); I was incorrect: these are not very short laterals (see explanation at the link); standard long lateral (about 9,300 feet horizontally)

August 2, 2014: a three-section horizontal lateral

• 25959, 732, CLR, Haffner 1-31H, Noonan, middle Bakken; 1920-acre; 50 stages; 7 million lbs, a true 3-section lateral (full sections 19/30/31 - 162-95); background gases "poor"; t3/14; cum 198K 1/20;

November 29, 2014: new designation for a Whiting well?  Yes, TFHU -- the "U" means "unit" -- 2560-acre unit.

• 27522, 4,207, Whiting, Flatland Federal 11-4TFHU, Twin Valley, spacing: 2560-acre; t10/14; cum 572K 1/20; huge jump, 3/19;

November 29, 2014, a huge well;

• 17314, 431, MRO, Brown 24-9H, Killdeer, a 10 - 30' flare for fifty minutes; this is a bit confusing for me, but I believe this well was spud/completed in 2008, but it was re-fracked in August, 2014, and that's why it shows up in today's report; the re-frack data was not yet scanned in; last full month production was in July, 2014; it will be interesting to see what new production numbers are and what the re-frack data is; t8/08; cum 426K 1/20; update here.

November 18, 2014: a huge CLR North Red River B well back on active status; looks like some type of workover in May/June, 2014, when there was no production; off-line from mid-April to mid-July, 2014; a huge producer back on line.

• 16529, 100, CLR, Spry 11-13NH, Cedar Hills, a North Red River B well, t8/07; cum 655K 1/20;

The Lawrence well in North Tioga,  #17745, posted May 10, 2014. They are back on line as of August, 2014. 

Also, later: #18341.

Was this well that produced 30,000 bbls in the first month really canceled by EOG? This will end up being a non-story. See this post. My hunch is that the "30,000" was an error.

Why did they take this great well off-line in July, 2013? A great well to follow periodically.

• 17310, Rosemary Eckelberg 41-26H, 459, 49,138 bbls in 15 months; t8/08; cum 173K 1/20; went back on line 1/14; significant increase in oil production; no explanation in well file;

Hit the one-million-bbl milestone:

• 7571, PA/482, Hess, Reitsch NCT-2 4, Blue Buttes, a Silurian well, t4/81; cum 1.0062 million bbls 7/17;

#20879 has two laterals, drilled at separate times. They have different names: -1H and -2H but yet carry the same permit number, #20879.

• 20879, 2,709, Bruin/HRC, Fort Berthold 147-94-1A-12-2H, McGregory Buttes, t1/14; cum 508K 1/20; see this note, 10/18;
  

The Carlson 1-11H well was taken off line 2/14; no explanation. Need to recheck in a few months. Posted 6/14. [Apparently back on-line, 5/14.]

• 19169, 685, Bruin/HRC, Carlson 1-11H, Strandahl, northwest of Williston, t2/10; cum 85K 1/20; this was GEOI's first completed Bakken well at a cost of $5.6 million; remains a lousy well (3/19);

One to follow: 18362 -- the answer here: http://themilliondollarway.blogspot.com/2014/09/random-update-on-mros-uran-31-2h-well.html

• 18362, 641, MRO, Uran 31-2H, Reunion Bay, t6/10; cum 343K 3/19; 15 stages, 2.6 million lbs; no explanation why it was taken off-line for four months in mid/late-2013, and then came back with much better production; interesting: after being offline for six months, had one bbl of crude oil over one day, 1/20;

Flaring. I doubt I will ever do a story on this, but if push comes to shove, I might. This well, along with 1,000's of others, would never have been drilled, and would now be shut down, if all flaring was banned in North Dakota: 

• 10217, 80, Legacy Reserves, Spring Creek Federal 6, Mondak, a Madison well, t10/83; cum 164K 1/20 (very little being produced, 1/20); at $50/bbl, this represents $7.7 million in crude oil; at $5/MCF natural gas, that represents $500,000 in natural gas. It would have cost several million dollars to put in a natural gas pipeline, assuming that regulators would even have allowed a pipeline for one well this remote. Spud in 1983, this well is flaring almost no natural gas but a very, very tiny bit is being flared. I cannot explain why it can go years producing oil but flaring no natural gas, and then back to flaring small amounts. Whatever meager amounts are being produced, none is being sold. [Update: I believe the rules state that the wells have to be producing at least 200 bbls of crude oil to be affected by new flaring rules, or about 6,000 bbls per month. This well is producing only 350 bbls of crude oil per month so it is not affected by new flaring rules.]

More To Follow-- Just In From a Reader -- Halcon To Buy Some Petro-Hunt, LLC, Assets In North Dakota

From the Bismarck Tribune (the link is already broken; 9/18/12; see data points below). Here's another link to the story.

A huge "thank you" to a reader for sending me the story.

Here are Petro-Hunt's ten (10) operated rigs on the day of the announcement:

• 22101, Ensign 46, Thorson 159-94-7A-18-3H, 
• 20879, Nomac 322, Fort Berthold 147-94-1A-12-2H,
• 22561, Ensign 77, Fort Berthold 148-94-21A-20-2H,
• 20355, Nomac 308, USA 153-95-1A-7-2H,
• 21716, Unit 108, Van Hise Trust 153-95-28C-21-2H,
• 21802, Unit 233, Fort Berthold 152-93-9C-10-3H,
• 22090, Unit 329, Fort Berthold 152-93-17C-08-4H,
• 23025, Unit 234, Pesek Trust 151-102-35D-26-2H,
• 23136, Ensign 24, Blikre 158-94-13B-24-1H,
• 22456, Ensign 93, Hoff 157-100-1A-12-1H,

Data points:

• Halcon Resources to buy 81,000 net acres in North Dakota from Petro-Hunt, LLC
• $1.45 billion; cash-and-stock deal; $700 million cash; $750 million in stock
• HK up almost 3% in trading today
• average net production of acquired assets: 10,500 boepd
• total proved reserves: 40 million boe (number rounded)
• five operated drilling rigs on the properties

Regular readers have noticed significant permitting activity by Petro-Hunt in the past few weeks.

On Friday, the Z-Man over at SeekingAlpha.com had a nice story on HK. I can't remember if I linked it last Friday.
Bandera, Willie Nelson  

Bach Minuet in G, Willie Nelson
If the acres that Petro-Hunt sold were acres inside the reservation, I find that interesting.

I've noted on the blog that KOG acquired acres outside the reservation (some time ago). Prior to that acquisition, I considered KOG pretty closely tied with the reservation.

My hunch is that what I am about to say next has nothing to do with any of this, but the paranoid among us at least have to think about it: The federal government/BLM is yet to announce its rules on fracking. I assume the rules will be announced if Mr Obama is re-elected. Again, don't take this as political commentary -- for me, it's just reality.

Again, I am probably in the minority on this, but a few might agree: that KOG expanding outside the reservation and Petro-Hunt selling land on the reservation (if accurate) is just hedging their bet on the Bakken. I don't mean to offend anyone by posting this, but for me it's reality, knowing that the BLM is still waiting to post its rules; the public comment period ended some time ago.

Wells Coming Off Confidential List; OXY With a Great IP/Poor Production; 4 of 7 Wells on DRL Status

Updates

Later, 7:27 pm: see first comment. Correct IP for the OXY USA well, #22881: 210.

Original Post

20879, drl, Petro-Hunt, Fort Berthold 147-94-1A-12-2H, McGregory Buttes,
22117, drl, WPX, Dora Smith 5-8HC, Van Hook,
22532, 1,491, Whiting, Mildred Roggenbuck 41-24TFX, Sanish, t8/12; cum 41K 12/12;
22730, drl BEXP, Holm 9-4 3TFH, Alger,
22881, 2,281, 2,210, 210, OXY USA, State Frank Butler 1-29-32H-142-94, Murphy Creek, t8/12; cum 9K 12/12; [Not: the scout ticket originally had "2,281" or "2,210" for the IP; the well file shows the correct IP at 210.]
23191, 682, Hess, BL-Myrtrice-156-96-2536H-2, Beaver Lodge, see below, t12/12; cum 20K 12/12;
23302, drl, BEXP, Timber Creek 13-24 1TFH, Alexander

************************

22881, 210, OXY USA, State Frank Butler 1-29-32H-142-94, Murphy Creek:

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	12-2012	28	581	688	1357	223	0	223
BAKKEN	11-2012	30	1421	1891	3363	561	0	561
BAKKEN	10-2012	31	1929	1835	4230	739	0	739
BAKKEN	9-2012	30	3377	3452	11130	1411	0	1411
BAKKEN	8-2012	7	1692	898	9821	0	0	0

23191, 682, Hess, BL-Myrtrice-156-96-2536H-2, Beaver Lodge; already on a gas line:

Date	Oil Runs	MCF Sold
12-2012	19671	24174

Initial Production For Wells Coming Off Confidential List This Next Week -- January 25, 2026

Locator: 49827WELLS. 

The wells:

• 42153, conf, Neptune Operating, Gullickson 36-25 4H, Rawson, 

Date	Oil Runs	MCF Sold
11-2025	38182	8129
10-2025	38688	20232

• 41237, conf, Hunt Oil, Clearwater 157-90-14-12H-1, Clear Water, 

Date	Oil Runs	MCF Sold
11-2025	14018	1559
10-2025	17859	5310
9-2025	18100	4839
8-2025	12327	3973

• 41236, conf, Hunt Oil, Clearwater 157-9-14-11H-3, Clear Water, 

Date	Oil Runs	MCF Sold
11-2025	13648	1377
10-2025	16152	5134
9-2025	17324	6260
8-2025	12152	4578

• 41234, conf, Hunt Oil, Clearwater 157-90-14-11H-1, Clear Water, 

Date	Oil Runs	MCF Sold
11-2025	17236	1906
10-2025	20076	5821
9-2025	20879	6603
8-2025	9022	3299

• 41461, conf, CLR, Garfield FIU 2-5HSL, Banks, 

Date	Oil Runs	MCF Sold
11-2025	39889	78231
10-2025	48741	82582
9-2025	10777	16528

• 41959, conf, Petro-Hunt, State 162-100-16B-21-2H, West Ambrose, npd, 
• 41352, conf, Hess, GO-Beck Living TR-156-98-2017H-3, Wheelock, 

Date	Oil Runs	MCF Sold
11-2025	14440	29278
10-2025	13943	27120
9-2025	9182	30321
8-2025	26077	40316

• 39807, conf, BR, Mazama 1C, Elidah, npd, 
• 41290, conf, Hess, GO-Morgan-LW-156-97-1806H-1, Dollar Joe, 

Date	Oil Runs	MCF Sold
11-2025	17675	29825
10-2025	19680	34926
9-2025	19051	38888
8-2025	27758	21952

• 42133, conf, WGO Resources, Trester 1-21, wildcat, NWNE 21-139-104, 

Date	Oil Runs	MCF Sold
11-2025	6926	0
10-2025	7854	0
9-2025	246	0

• 42032, conf, Slawson, Rebel Federal 4-32-17TFH, Big Bend, npd, 
• 41997, conf, Slawson, Rebel Federal 2-32-17H, Big Bend, npd, 
• 39806, conf, BR, Mazama 1B, Elidah, npd, 
• 42033, conf, Slawson, Rebel Federal 5-32-17TFH, Big Bend, npd, 
• 41007, conf, Hunt, Nichols-Trulson 156-90-10-14H-1, Ross, 

Date	Oil Runs	MCF Sold
11-2025	8979	3297
10-2025	9805	5199
9-2025	10438	4958
8-2025	9429	1749
7-2025	0	162

• 41006, conf, Hunt, Palermo 156-90-3-31H 3, Ross, 

Date	Oil Runs	MCF Sold
11-2025	17897	3518
10-2025	23493	7814
9-2025	20699	6855
8-2025	12426	1781
7-2025	0	312

• 42034, conf, Slawson, Rebel Federal 3-32-17H, Big Bend, npd,
• 39805, conf, BR, Mazama 1A, Elidah, npd, 
• 42035, conf, Slawson, Rebel Federal 6-32-17TFH, Big Bend, npd, 
• 40868, conf, Hess, GO-Dustin Brose-156-98-2932H-2, Wheelock, 

Date	Oil Runs	MCF Sold
11-2025	15700	25655
10-2025	14799	24923
9-2025	13834	43109
8-2025	32839	46807
7-2025	3369	3604

• 41385, conf, Hess, GN-Stundal-158-97-1819H-4, New Home, 

Date	Oil Runs	MCF Sold
11-2025	17924	35617
10-2025	16367	20791
9-2025	15760	20696
8-2025	22939	28792
7-2025	1897	7218

• 41309, conf, BR, Sandie 4A MBH, Elidah, npd, 
• 39803, conf, BR, Carlsbad 4C, Twin Valley, npd, 
• 41384, conf, Hess, GN-Stundal-158-97-1819H-3, New Home, 

Date	Oil Runs	MCF Sold
11-2025	14650	22798
10-2025	5089	7585
9-2025	14035	18381
8-2025	19067	26044
7-2025	1654	3866

• 41351, conf, Hess, GO-Dustin Brose-156-98-2932H-4, Wheelock, 

Date	Oil Runs	MCF Sold
11-2025	16962	28412
10-2025	13437	24734
9-2025	8242	27756
8-2025	25140	40064
7-2025	4649	6514

• 41308, conf, BR, Sandie 3A MBH, Elidah, npd, 
• 40079, conf, Devon, Cuda 14-26F 5H, Round Prairie, 

Date	Oil Runs	MCF Sold
11-2025	21901	20742
10-2025	32318	24842
9-2025	32766	25077
8-2025	19731	12510
7-2025	4124	1904

NDIC Hearing Dockets: September, 2013

Note: as you go through these cases, think about folks who elected to not participate in a given well in a given spacing unit, and become a working partner; some of these spacing units will see 15+ wells. 

Note: along that line, look at all the risk penalty cases.

Note: the percentage of cases in which maximum production and flaring is being requested; Lynn Helms and the commission have the authority to deny these requests which the majority of those commenting elsewhere would like to see. Activist environmentalists would be pleased. Again, the flaring issue in the Bakken could become a non-issue fairly quickly.

Note: permits for 600 or so wells being requested by EOG

Wednesday, September 25, 2013

20854, Evertson Operating, proper spacing, Ray-Red River, Williams County
20855, Whiting, proper spacing, Hoot Owl-Red River, Golden Valley County
20856, Whiting, temporary spacing, Williams 24-25; Golden Valley County
20857, Whiting, temporary spacing, Jones 44-25; Golden Valley County
20858, SM Energy, amend, Phelps Bay-Bakken, terminate a 960-acre spacing unit, and establish a 640-acre unit; 8 wells; McKenzie County
20859, Oasis, amend, Bull Butte-Bakken, establish an overlapping 2560-acre unit; 1 well, Williams
20860, Oasis, amend, Tyrone-Bakken; establish four overlapping 2560-acre units; 1 well each; Williams
20861, Oasis, amend, Squires-Bakken, establish two overlapping 2560-acre units; 1 well each; Williams
20862, Oasis, amend, Missouri Ridge-Bakken; i) establish one overlapping 2560-acre unit, 10 wells; ii) establish one overlapping 2560-acre unit, 1 well; iii) alter the stratigraphic definition Williams
20863, Oasis, amend, Robinson Lake and Alkali Creek-Bakken, establish an overlapping 2560-acre unit; 1 well; Mountrail
20864, Oasis, amend Willow Creek-Bakken; establish an overlapping 2560-acre unit; 1 well; Williams
20865, Oasis, amend, Baker-Bakken, establish an overlapping 2560-acre unit; 1 well; Williams, McKenzie
20866, Oasis, amend Camp-Bakken, establish an overalapping 2560-acre unit; 1 well; McKenzie
20867, Oasis, authorize, Baker-Bakken; 15 wells on some or all 1280-acre units; McKenzie, Williams
2868, Oasis, authorize, North Tioga-Bakken; 15 wells on a 1280-acre unit; Burke, Divide, Williams
20869, Oasis, authorize, Gros Ventre-Bakken; 15 wells on a 1280-acre unit; Burke, Mountrail
20870, OXY USA, amend, Little Knife-Bakken, establish one overlapping 2560-acre unit 1+ wells; Dunn
20871, OXY USA, amend, Cabernet-Bakken, establish one overlapping 2560-acre unit; 1+ wells; Dunn
20872, OXY USA, amend, Cabernet and Murphy Creek-Bakken, establish one overlapping 2560-acre unit; 1+ wells; Dunn
20873, OXY USA, amend, Dimond-Bakken, max production, flaring, Burke
20874, OXY USA, note to dismiss, amend, Fayette-Bakken, max production, flaring, Dunn
20875, OXY USA, amend, Little Knife-Bakken, max production, flaring, McKenzie, Billings, Dunn
20876, OXY USA, amend, Vanville-Bakken, max production, flaring, Burke
20877, Hess, amend, Truax-Bakken, authorize 8 wells on a 1280-acre unit; Williams
20878, Hess, amend, Rainbow-Bakkken, max production, flaring, Williams
20879, Hess, amend, Juniper-Bakken, max production, flaring, McKenzie
20880, Hess, amend, Hawkeye-Bakken, max production, flaring, McKenzie
20733, cont'd
20737, cont'd
20728, cont'd
20881, cont'd
20882, cont'd
20883, cont'd
20607, notice to dismiss, QEP, amend, Van Hook-Bakken, 16 wells on a 3200-acre unit; Mountrail, Dunn
20884, Nuverra, treatment facility
20885, Nuverra, treatment facility
20886, Nuverra, treatment facility
20887, Nuverra, treatment facility
20888, Earthworks, treatment facility
20889, Murex, Stanley-Bakken; 8 wells on 4 1280-acre units (32 wells total); Mountrail
20890, Murex, Sanish-Bakken, 8 wells on 4 1280-acre units (32 wells total); Mountrail
20891, Murex, pooling
20892, Murex, pooling
20893, Murex, pooling
20894, Murex, pooling
20895, Oasis, Cow Creek-Bakken, 9 wells on a 1280-acre spacing unit; Williams
20896, KOG, Epping-Bakken, 10 wells on a 1280-acre unit, Williams
20897, Samson Oil & Gas, pooling
20898, Samson Oil & Gas, pooling
20899, BR, pooling
20900, BR, pooling
20901, BR, pooling
20902, Whiting, SWD, conversion of 16581, Curl 23-14, McKenzie,
20903, Whiting, SWD, conversion of 16177, Mork 24-8, McKenzie,
20904, Whiting, Ash Coulee-Bakken, 4 wells on a 1280-acre unit; Billings
20905, Whiting, pooling
20906, Whiting, pooling
20907, OXY USA, Crooked Creek-Bakken, 7 wells on 7 1280-acre units (49 wells), Dunn
20908, OXY USA, pooling
20909, True Oil, SWD, conversion of 15507 Burlington Northern 31-27A;
20910, True Oil, pooling
20911, True Oil, pooling
20912, True Oil, pooling
20913, True Oil, pooling
20914, True Oil, pooling
20915, True Oil, pooling

Thursday, September 26, 2013 

20916, North Plains, suspend, revoke Murex permit, Dwight Ludwig 13-24H, Divide
20917, Sakakawea Ventures, treatment facility,
20918, New Frontier Group, treatment facility
20919, EOG, Clarks Creek-Bakken, proper spacing, McKenzie
20920, EOG, Parshall-Bakken, establish a 1280-acre unit; and establish two 1920-acre units 6 wells on each spacing unit; Mountrail
20787, cont'd
20495, cont'd
20921, Fram Operating, South Greene-Madison, proper spacing, Renville
20922, Zenergy, Eightmile-Bakken, establish an overlapping 2560-acre unit; multiple wells; Williams
20923, Zenergy, Sand Creek-Bakken, 16 wells on an existing 1280-acre unit; McKenzie;
20924, CLR, Twin Valley and Banks-Bakken, create an overlapping 2560-acre unit; mulitple wells; McKenzie
20925, CLR, Elidah-Bakken, create two overlapping 2560-acre units; multiple wells; McKenzie
20926, CLR, suspend, revoke a Hess permit, SC-5WX-152-99-0310H-1, McKenzie
20927, CLR, suspend, revoke a Hess permit SC-4WX-153-98-3130H-3, McKenzie
20928, CLR, suspend, revoke a Hess permit SC-4WX-153-98-3130H-2, McKenzie
20929, CLR, suspend, revoke a Hess permit, SC-4WX-153-98-3130H-1, McKenzie
20930, CLR, Beaver Lodge-Bakken, max production, flaring, Williams
20931, Corinthian, extend Haram-Spearfish; create five 320-acre units; 12 wells on each spacing unit; Bottineau (that could mean as many as 24 wells in each section)
20932, Corinthian, extend Northeast Landa-Spearfish/Madison; establish three 320-acre units; 12 wells on each unit; Bottineau;
20933, Enduro, recomplete the Beicegel Creek 27 42 well, McKenzie
20934, Enerplus, Eagle Nest-Bakken, establish an overlapping 1280-acre unit; 4 wells; Dunn
20935, Triangle, extend Sioux and/or Ragged Butte-Bakken, establish a 1280-acre unit; 8 wells, McKenzie
20936, XTO, Morgan Draw-Bakken, establish a 2560-acre unit; multiple wells; Golden Valley, Billings
20937, Slawson, Stockyard Creek-Bakken, establish two overlapping 960-acre units; 8 wells on each 960-acre unit; Williams
20797, cont'd
20938, Powers Energy, risk penalty legalese
20939, Fiedlity, Heart River-Bakken, max production, flaring, Stark
20940, Fideltiy, Zenith-Bakken, max production, flaring, Stark
20941, Crescent Point, Colgan-Bakken, max production, flaring, Divide
20942, Baytex, et al, West Ambrose-Bakken, max production, flaring, Divide
20943, Baytex, et al, Ambrose-Bakken, max production, flaring, Divide
20795, cont'd
20944, Newfield, Tobacco Garden-Bakken, max production, flaring, Mckenzie
20945, Mountain Divide, Fortuna-Bakken, max production, flaring, Divide
20946, WPX, Squaw Creek-Bakken, 11 wells on a 1280-acre unit; McKenzie
20947, WPX, Eagle Nest-Bakken, 11 wells on a 1280-acre unit; McKenzie
20948, WPX, Mandaree-Bakken, 11 wells on each of two 1280-acre units; Dunn
20949, WPX, Van Hook-Bakken, max production, flaring, Mountrail, Dunn, McLean
20498, cont'd
20500, cont'd
20501, cont'd
20800, cont'd
19901, cont'd
20658, cont'd
20950, Bakken Hunter, risk penalty legalese
20951, BOH, SWD
20952, BOH, SWD
20953, WPX, risk penalty legalese
20954, WPX, risk penalty legalese
20955, WPX, risk penalty legalese
20956, WPX, risk penalty legalese
20957, XTO, pooling
20958, XTO, pooling
20959, XTO, risk penalty legalese
20960, XTO, risk penalty legalese
20961, XTO, risk penalty legalese
20962, XTO, risk penalty legalese
20963, XTO, risk penalty legalese
20964, XTO, risk penalty legalese
20965, CLR, pooling
20966, CLR, pooling
20967, CLR, pooling
20968, CLR, pooling
20969, CLR, risk penalty legalese
20970, CLR, Alkali Creek-Bakken, 9 wells on an existing 1280-acre unit; McKenzie, Mountrail
20971, CLR, Banks-Bakken, 5 wells on each of two existing 1280-acre units; McKenzie
20972, CLR, Camel Butte-Bakken, 7 wells on an existing 12i80-acre unit; McKenzie
20973, CLR, Elidah-Bakken, 7 wells on an existing 1280-acre unit; McKenzie
20974, CLR, Camp-Bakken, 14 wells on an existing 2560-acre unit; McKenzie
20814, cont'd
20815, cont'd
20816, cont'd
20975, Baytex, risk penalty legalese
20976, Baytex, risk penalty legalese
20977, Newfield, risk penalty legales
20978, Triangle, pooling
20979, Triangle, pooling
20980, Triangle, pooling
20981, Triangle, pooling
20982, Triangle, Elk-Bakken, 8 wells on each of 3 1280-acre units; McKenzie
20983, Emerald, pooling
20984, Emerald, pooling
20985, Emerald, pooling
20986, Emerald, pooling
20987, Emerald, pooling
20988, Emerald, pooling
20989, Emerald, pooling
20990, Emerald, pooling
20991, Emerald, commingling
20992, Emerald, commingling
20993, Emerald, commingling
20994, Emerald, commingling
20995, Zenergy, pooling
20996, Zenergy, pooling
20997, Zenergy, pooling
20998, Zenergy, pooling
20999, Zenergy, pooling
21000, Zenergy, pooling
21001, Zenergy, pooling
21002, Zenergy, pooling
21003, Zenergy, pooling
21004, Zenergy, pooling
21005, Zenergy, pooling
21006, Zenergy, pooling
21007, EOG, Parshall; 6 wells on each of 37 existing 1280-acre units; and 6 wells on each of 43 existing 1920-acre units (approximately; I was unable to quickly count each spacing unit). But it looks like 6 wells on each of about 80 existing spacing units, which would be about 480 wells, Mountrail
21008, EOG, Van Hook-Bakken, 5 wells on each of 2 320-acre units; 7 wells on an existing 1280-acre unit; 7 wells on an existing 1920-acre unit' 7 wells on each of 3 1600-acre units; Mountrail
21009, EOG, Stanley-Bakken 6 wells on 4 1280-acre units; 6 wells on each of 9 1920-acre units; Mountrail
21010, Slawson, Sanish-Bakken, 7 wells on each of 2 640-acre units; 9 wells on an overlapping 1280-acre unit; 6 wells on each of several 640-acre units; Mountrail
21011, Slawson, Van Hook-Bakken, 7 wells on an existing 1280-acre unit; Mountrail
20839, cont'd
21012, Arsenal, commingling
21013, Enduro, commingling
21014, Enduro, commingling
21015, Fidelity, commingling
21016, Fidelity, commingling
21017, Flatirons, SWD
21018, Armstrong, Patterson Lake-Lodgepole, injection in the unitized formation, Stark

Give Him A Great Big Kiss, Shangri-La's