ECO-Pad = $$$$-Pad -- June 24, 2022

Early on in the Bakken, there were many reports of small mom-and-pop mineral owners becoming millionaires overnight. 

A lot of these folks were farmers who happened to still hold their mineral rights after all these years. 

In the early days of the Bakken, operators were drilling as fast as they could for many reasons, but mostly to hold the leases by production. 

To drill that fast, operators often drilled one well in any given spacing unit

Often, the small mom-and-pop mineral owners were "living" off one well. And still becoming millionaires. Maybe some hyperbole, but not much.

Fast forward to 2022. Now, it is the norm to drill mega-pads with six wells on each pad. 

Can you imagine a small mom-and-pop mineral rights owner with one well all these years to now see six new wells coming in. All at once. And with oil at $110 / bbl. 

What a great country. 

Yesterday, as the most recent example: Oasis with six new permits on one pad. That's been the norm for quite some time. Pioneered by Harold Hamm, one might argue. 

CLR Getting Active In Cedar Coulee -- Update -- February 27, 2021

The CLR Gale wells are tracked here.

This page won't be updated. This well is tracked here. Is something going on? This well was taken off line almost two years ago, back in 4/19. Now, almost two years later, the well was brought back on line for 19 days, 12/20, producing 1,167 bbls of oil:

• 24735, 981, Hess, LK-Pohribnak-147-96-16H-5, 1 section, t10/13; cum 221K 6/19; cum 223K 12/20;
  

It was noted:

• December 4, 2020: CLR activity in this field, update.
  

There's a lot of activity about four miles south of the LK-Pohribak wells. See the graphics at that link posted December 4, 2020 (link). At that time, about three months ago, there was only one rig in section 32-147-96. Now there are four rigs:

These wells run west to east on one pad:

• 37373, conf, CLR, Gale 5-32H,
• 37374,
• 37375,
• 37376,
• 37377,
• 37378,
• 37379, ros, CLR, Rodney 8-29H1,

These wells run north to south on one pad:

• 37396, ros,  CLR, Rodney 10-29H1,
• 37397,
• 37398,
• 37399,
• 37400,
• 37401,
• 37402, 

These wells run north to south on one pad:

• 37410,
• 37409,
• 37408,
• 37941, ros, CLR, Bang 3-33H1,
• 37407, ros, CLR, Gale 14-32HSL,
• 37406,
• 37405,

The CLR Rodney / Gale wells are tracked elsewhere.

NDIC's list of active rigs shows only two active CLR rigs, both drilling Rodney wells.  

The BR Mathistad Wells In Croff Oil Field

Locator: 10010MATHISTAD.

 

Updates

 September 4, 2024: compare today's map with the original map --

January 14, 2018: see first comment. A reader has really made some interesting observations, including a great link.

Just a couple notes of interest:

The lateral for the Mathistad 2-35H runs 50 feet above and parallel to the 1-35H. It was originally owned by Continental Resources and was an experimental well partially funded by the State of North Dakota to determine possible communication between nearby laterals most notably the 1-35H. The details are on the attached link:

https://www.rigzone.com/news/oil_gas/a/79041/Continental_Reports_Successful_TwoReservoir_Test_in_Bakken_Shale

Also, there looks to be room for another 4 well pad between the new and older wells? 

And, then, of course, my reply: yes, there is more than enough room for another 4-well pad between the older well pads, and then, of course, vertically, additional benches in the Three Forks, possibly.

With regard to communication between formations, see this post: http://themilliondollarway.blogspot.com/2010/02/communication-between-formations.html, February 7, 2010.

Also, this post from May 4, 2011.

Also, a "fracturing question," March 3, 2011.

Original Post 

Note production profile of two older Mathistad wells, scroll down to bottom of post. 

The Mathistad wells:

• 16983, 15 (no typo), BR, Mathistad 1-35H, Croff, API: 33-053-02852, t6/08; cum 321K 11/19; was off line 6/19; returned to production, 9/19; cum 380K 6/24; off line;
  
• 18013, 842, BR, Mathistad 2-35H, Croff, API: 33-053-03011, t7/09; cum 281K 11/19; cum 337K 2/24; off line;
  
• 33144, 318, BR, Mathistad 22A MBH, Croff, 30 stages; 10.5 million lbs, t10/17; cum 476K 11/19; cum 766K 7/24;
  
• 33146, 273, BR, Mathistad 22B UTFH, Croff, 4 sections, Three Forks, 31 stages; 15 million lbs, t10/17; cum 493K 11/19; cum 702K 7/24;
  
• 33152, 414, BR, Mathistad 6-8-35 MBH, Croff, 29 stages; 10 million lbs large, t11/17; cum 562K 11/19; cum 791K 7/24;
  
• 33150, 655, BR, Mathistad 3NC-MTFH, Cross, 4 sections, Three Forks, 29 stages; 14.5 million lbs, t11/17; cum 466K 11/19; cum 633K 7/24; off line;
• 33155, 40, BR, Mathistad 7-8-24 MBH,t3/20; cum 381K 7/24;
  
• 37580, conf, BR, Mathistad 2A MTFH, no production data,
  
• 37578, conf, BR, Mathistad 2B MTFH, no production data,

The graphic:

Recent production for two older wells:
16983:

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	11-2017	15	3277	3289	508	2839	2802	0
BAKKEN	10-2017	1	0	0	0	0	0	0
BAKKEN	9-2017	0	0	0	0	0	0	0
BAKKEN	8-2017	23	894	685	286	1558	1501	0
BAKKEN	7-2017	30	1136	1109	256	1977	1903	0
BAKKEN	6-2017	30	1156	1349	196	1928	1854	0
BAKKEN	5-2017	31	1132	905	228	2111	2034	0

18013:

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	1-2018	11	1776	1638	336	1728	1701	0
BAKKEN	12-2017	27	5528	5169	958	5814	5747	0
BAKKEN	11-2017	15	3024	3084	621	2899	2862	0
BAKKEN	10-2017	0	0	0	0	0	0	0
BAKKEN	9-2017	0	0	0	0	0	0	0
BAKKEN	8-2017	11	411	597	44	847	822	0
BAKKEN	7-2017	31	1461	1350	213	2897	2820	0
BAKKEN	6-2017	30	1449	1597	141	2573	2499	0
BAKKEN	5-2017	31	1575	1586	165	2675	2598	0
BAKKEN	4-2017	28	1788	1576	170	2305	2235	0

16983:

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	1-2018	31	6003	5930	1024	6635	6558	0
BAKKEN	12-2017	31	6246	6280	1621	7012	6874	61
BAKKEN	11-2017	15	3277	3289	508	2839	2802	0
BAKKEN	10-2017	1	0	0	0	0	0	0
BAKKEN	9-2017	0	0	0	0	0	0	0
BAKKEN	8-2017	23	894	685	286	1558	1501	0
BAKKEN	7-2017	30	1136	1109	256	1977	1903	0
BAKKEN	6-2017	30	1156	1349	196	1928	1854	0

Pad Drilling Vs Density Drilling

I'm in the middle of a swim meet, so I'm not concentrating as much as I should, so take everything I write this morning with "a grain of salt," as they say.

The Dickinson Press has a story on pad drilling today, something regular readers have known about for two, three, four years -- whenever Harold Hamm (CLR) introduced Eco-Pads, a copyright term, by the way, I believe.

In my mind, there is a difference between pad drilling and density drilling. Perhaps one can think of density drilling being a subset of pad drilling, though technically there would be no reason why density drilling couldn't be done on individual well sites, but that would be a real waste. So, for now, in my simple mind, density drilling is a subset of pad drilling. Another way one could say it, I suppose, is that density drilling is facilitated by pad drilling.

Be that as it may, the linked Dickinson Press article is about pad drilling and not density drilling.

Multi-well pads are becoming bigger and a more common sight in the western North Dakota Oil Patch.

The pads consolidate impacts to nearby landowners and the environment to one concentrated spot, rather than single wells being sprinkled across the landscape.

The wells’ coziness doesn’t extend underground though — horizontal drilling allows the wells to start in one spot but spawn in various directions, to wherever the oil is.

So far this year, 60 percent of the wells permitted were for shared pads, up from about a third from 2011, according to Department of Mineral Resources data.

Eleven (11) New Permits -- Bakken, North Dakota, USA

Daily activity report, August 26, 2011 --

Operators: CLR (4), Whiting (2), Hess (2), Oasis, Enerplus, Petro-Hunt

Fields: Sanish, Beaver Lodge, Eagle Nest, Sauk, and two wildcats.

Hess has a 2-well pad in Beaver Lodge; CLR has an Eco-Pad in Sauk oil field.

Whiting has two wells in their cash cow, the Sanish.

Oasis has one wildcat in Williams County, and Petro-Hunt has the other, also in Williams.

One well was released from confidential list today, but no data, so waiting to be fracked.

Update on Two CLR Eco-Pads -- Bakken, North Dakota, USA

I recently showcased the CLR Morris/Carson Peak Eco-Pad in Oakdale oil field. Someone sent me a comment reminding me about two other Eco-Pads in the same area (but different oil fields), the Meadowlark/Skachenk Eco-Pad, and the Bonneville/Bridger Eco-Pad.

The Meadowlark/Skachenko Eco-Pad in Jim Creek oil field; apparently this well has been choked back due to weather conditions; this well is in the are of State Highway 22 north of Killdeer that has been site of major road slides; road under major repair

• 19021, 744, CLR, Meadowlark 3-6H, tested 6/11; 10K after 21 days
• 19021, 879, CLR, Skachenko 3-31H, tested 6/11; 13K after 21 days
• 19022, 453, CLR, Meadowlark 2-6H, tested 6/11; 20K after 25 days
• 19023, 726, CLR, Skachenko 2-31H, tested 6/11; 12K after 25 days

The Bonneville/Bridger Eco-Pad in Rattlesnake Point oil field.

• 19009, 651, CLR, Bonnevile 3-23H, tested 12/10; 68K as of 6/11
• 19011, 725, CLR, Bridger 3-14H, tested 12/10; 65K as of 6/11
• 19012, 365, CLR, Bonnevile 2-23H, tested 12/10; 36K as of 6/11
• 19013, 399, CLR, Bridger 2-14H, tested 12/10; 45K as of 6/11

It was also noted that some years ago a vertical well drilled in the Meadowlark/Skachenko Eco-Pad area was quite remarkable:

• 8499, 1,652, Citation Oil and Gas, Skachenko A 1, Jim Creek, Bakken, tested, 1981; 1.5 million barrels as of June, 2011, and still producing from the Duperow, the original target; the Red River was dry; this well sits between the two horizontals running north from the Meadlowlark/Skachenko Eco-Pad.

As exciting as this is now, can you imagine reporting the Citation Skachenko well back in 1981 with an IP of 1,652? I can't even imagine what the local folks must have thought when that well was reported. Even today, 1,652 catches your attention, but back in 1981, it would have been awe-inspiring. 

Oakdale Oil Field Update

Locator: 10010OAKDALE.

January 29, 2025: production data updated.

 

Permits in Oakdale Oil Field

2021 (none as of May 27, 2021)

2020

• 37794, drl/NC-->drl/A, CLR, Carson Peak 13-35H, first production, 5/21; t--; cum 85K 7/21; cum 268K 4/22; cum 442K 11/24;
  
• 37716, drl/NC-->drl/A, CLR, Carson Peak 12-35H1, first production, 5/21; t--; cum 86K 7/21; cum 252K 4/22; cum 430K 11/24;
  
• 37715, drl/NC-->drl/A, CLR, Carson Peak 11-35H2, first production, 5/21; t--; cum 112K 7/21; cum 313K 4/22; cum 547K 11/24;
  
• 37714, drl/NC-->drl/A, CLR, Morris 13-26H, first production, 5/21; t--; cum 72K 7/21; cum 248K 4/22; cum 357K 11/24;
  
• 37713, drl/NC-->drl/A, CLR, Morris 12-26H1, first production, 5/21; t--; cum 57K 7/21; cum 197K 4/22; cum 300K 11/24;
  

2019

• None.

2018

• 35273, F/2,405, Carson Peak 4-35H2L, t6/19; cum 562K 3/21; cum 616K 7/21; cum 693K 3/22; offline 4/22; cum 760K 11/24;
  
• 35272, 3,376, Carson Peak 4-35HSL, t6/19; cum 677K 3/21; almost 700K in less than two years; cum 720K 7/21; cum 791K 2/22; offline 3/22; cum 926K 11/24;
  
• 35109, F/956, Morris 7-26H2, t4/19; cum 304K 1/21; off line 1/21; back on line 5/21; cum 311K 7/21; cum 362K 3/22; off line 4/22; cum 425K 11/24;
  
• 35108, 1,824, Carson Peak 6-35H1, t5/19; cum 448K 3/21; off line for much of 2/21 - 3/21; cum 481K 7/21; cum 530K 3/22; offline 4/22; cum 727K 11/24;
  
• 35087, drl/A, Morris 11-26H, Oakdale, first production, 5/21; t--; cum 108K 7/21; cum 254K 4/22;
  
• 35086, drl/A, Morris 10-26H2, first production, 5/21; t--; cum 85K 7/21; cum 200K 4/22; cum 209K 4/22; cum 264K 11/24;
  
• 35085, drl/A, Morris 9-26H, Oakdale, first production, 5/21; t--; cum 75K 7/21; cum 209K 4/22; cum 302K 11/24;
  
• 35084, drl/A, Carson Peak 1-35H1, first production, 5/21; t--; cum 101K 7/21; cum 308K 4/22; cum 531K 11/24;
  
• 35083, drl/A, Carson Peak 9-35H, first production, 5/21; t--; cum 81K 7/21; cum 262K 4/22; cum 538K 11/24;
  
• 35082, F/1,593, Morris 8-26H1, four sections; t4/19; cum 330K 9/20; off line 10/20; back on line 6/21; cum 341K 7/21; cum 408K 4/22; cum 451K 11/24;
  
• 35081, 3,556, Carson Peak 8-35H2, t5/19; cum 633K 1/21; off line 2/21; back on line 5/21; cum 648K 7/21; cum 666K 4/22; offline 4/22; cum 876K 11/24;
  
• 35080, 2,076, Carson Peak 7-35H, t6/19; cum 455K 12/20; off line 1/21; remains off line 7/21; back on line 8/21; cum 568K 4/22; cum 818K 11/24;
  

2017

• 34354, 2,485, CLR, Hawkinson 16-22HSL1, 4 sections, NENE 22-147-96; 465 FNL 681 FEL, see graphic; t2/19; cum 382K 3/21; cum 406K 7/21; cum 431K 4/22; off line 4/22; cum 488K 11/24;
  
• 34353, 2,913, CLR, Morris 4-23HSL, NENE 22-147-96; 466 FNL 636 FEL, see graphic; t3/19; cum 349K 3/21; cum 354K 7/21; cum 377K 4/22; off line 4/22; cum 411K 11/24;
  
• 34352, 2,698, CLR, Morris 523H2, NENE 22-147-96; 466 FNL 500 FEL, see graphic; t4/19; cum 277K 3/21; but essentially off line since 6/19; remains off line 9/19; back on line 10/19; cum 286K 7/21; cum 306K 4/22; off line 4/22; cum 338K 11/24;
  
• 34351, 1,969, CLR, Morris 6-23H, NENE 22-147-96; 467 FNL 456 FEL, see graphic; t4/19; cum 337K 3/21; off line most of 2/21 - 3/21; back on line 6/21; cum 348K 7/21; cum 390K 4/22; offline 4/22; cum 439K 11/24;
  

2016

• None.

2015 (list is compete)

• 31104, 133, CLR, Hawkinson 15-22H, Oakdale, t4/16; cum 100K 3/21; off line since 11/18; see below; back on line 1/19; cum 107K 4/22; cum 132K 11/24;
  

2014

• No new Oakdale permits in 2014.

2013

• No new Oakdale permits in 2013.

2012

• Only the CLR Hawkinson wells noted below

2011

• None

Hawkinson Wells

Hawkinson wells in section 22/27-147-96 in Oakdale oil field (it should be noted that wells #20208 and #20211 are in this spacing unit, but sited in section 34 to the south):

• 18275, single well, 1,020, CLR, Hawkinson 1-22H, t2/10; cased hole, 2 million lbs; cum 733K 3/21; went off line 3/19; still off line 4/19; back on line as of 5/19; unremarkable change in production; cum 767K 11/24;
  

A singleton (see above):

• 31104, 133, CLR, Hawkinson 15-22H, t4/16; cum 95K 1/20; off line as of 11/18; back on line as of 1/19; still a lousy well; cum 132K 11/24;

There are two more Hawkinson wells that were drilled from the other end of the spacing unit:

• 20208, 960, CLR, Hawkinson 2-27H, Oakdale, 4-section spacing, Three Forks; 24 stages, 2.4 million lbs; t9/11; cum 472K 1/20; off line as of 5/18; back on line as of 2/19; cum 526K 11/24;
• 20211, A/AB-->A/263, CLR, Hawkinson 3-27H, Oakdale, 4-section spacing, middle Bakken, 24 stages, 2.4 million lbs, t9/11; cum 389K 1/20; was AB, now active again, back on line as of 2/18; not much production since coming back on line; off line 10/19 but then back online 1/10; cum 403K 11/24;
  

Three-well pad:

• 24223, 400, CLR, Hawkinson 4-22H2, Oakdale, Three Forks, 30 stages, 2.8 million lbs; t91/13; cum 382K 1/20; went offline 3/19; see this post; cum 498K 11/24;
  
• 24224, 681, CLR, Hawkinson 5-22H, Oakdale, middle Bakken, 30 stages, 2.8 million lbs, t9/13; cum 495K 1/20; went offline 3/19; see this post; cum 583K 11/24;
  
• 24225, 809, CLR, Hawkinson 6-22H3, Oakdale, Three Forks, 30 stages, 2.8 million lbs, t10/13; cum 236K 1/20; went off line 3/19; see this post; intermittent production until 5/19; cum 263K 11/24;
  

Five-well pad:

• 24282, 175, CLR, Hawkinson 7-22H2, Oakdale, middle Bakken, 29 stages, 2.7 million lbs, t10/13; cum 257K 1/20; off line since 11/18; back online as of 3/19; cum 282K 11/24;
  
• 24283, 504, CLR, Hawkinson 8-22H, Oakdale, middle Bakken, 29 stages, 2.7 million lbs, t11/13; cum 257K 1/20; cum 291K 11/24;
• 24284, AB/203, CLR, Hawkinson 9-22H3, Oakdale, Three Forks, 30 stages, 2.8 million lbs, t10/13; cum 151K 1/20; off line since 11/18; back online as of 1/19 but still a lousy well;cum 151K 8/20;
  
• 24285, 922, CLR, Hawkinson 10-22H1, Oakdale, Three Forks, 30 stages, 2.8 million lbs, t10/13; cum 193K 1/20; off line since 11/18; online as of 1/19; but still a lousy well; cum 219K 11/24;
  
• 24286, 323, CLR, Hawkinson 11-22H2, Oakdale, Three Forks, 30 stages, 2.7 million lbs, t10/13; cum 261K 1/20; off line since 11/18; back on line as of 1/19; looks like some increase in production; cum 308K 1124;
  

Three-well pad:

• 24350, 445, CLR, Hawkinson 12-22H3, Oakdale, Three Forks, t9/13; cum 204K 1/20; off line since 12/18; back on line for 6 days, 9/19; small amount of production; cum 270K 11/24;
  
• 24455, 2,323, CLR, Hawkinson 13-22H, Oakdale, middle Bakken, 29 stages, 2.7 million lbs, t10/13; cum 299K 1/20; off line since 10/18; on line for 15 days 3/19 but offline again as of 4/19; back on line as of 6/19; cum 375K 11/24;
  
• 24456, 542, CLR, Hawkinson 14-22H2, Oakdale, Three Forks, t9/13; cum 243K 1/20; off line since 10/18; back on line for 12 days in 3/19 but back off line as of 4/19; mediocre well at best; back on line as of 9/13; cum 254K 11/24;
  

Updates

May 27, 2021: Oakdale wells permitted in 2018, updated this date.

June 6, 2019: #24282 back on line after being offline for about five months; not much change in production; 

• 24282, 175, CLR, Hawkinson 7-22H2, Oakdale, t10/13; cum 282K 11/24;

February 4, 2019: lots of activity right now in this area. Several great wells off-line since 10/18; in addition, two new wells on DRL status are now on the 18858-18861 pad:

• 35272, 3,376, CLR, Carson Peak 4-35HSL, t6/19; cum 926K 11/24;
• 35273, 2,405, CLR, Carson Peak 5-35H2, t6/19; cum 760K 11/24;
  

June 4, 2014: Oakdale field is very small; only eight (8) sections. It is two sections wide (west/east) by four sections long (north/south). It has four 1280-acre spacing units; and CLR proposes two overlapping 2560-acre units in the June NDIC dockets.

Case (not permit) 22550, CLR, Oakdale-Bakken, 16 wells on each existing 1280-acre unit within Zone I; 32 wells on each 2560-acre unit in Zones III and IV; Dunn

Since 32 wells works out to 16 wells sited in every 1280 acres, that would suggest a maximum of 32 wells in every 1280 acres. I assume they wouldn't drill a well unless they anticipated a EUR of at least 500,000 bbls. 16 x 500,000 = 8,000,000 boe in each section. 8 million boe / 640 acres = 12,500 boe/acre. 

November 6, 2013: Hawkinson Unit density test produces at an initial combined rate of 14,850 boe per day from middle Bakken and Three Forks benches one, two and three. CLR will dedicate four rigs to drill mega-pads. CLR will drill 350 wells on 25 pads over the next four to five years.


October 18, 2012:  Three new CLR permits in Oakdale -- testing the lower benches of the Three Forks?

Original Post

I recently updated the Morris 2-26H well which is in the Oakdale oil field in the Williston Basin.

• 18860, 517, CLR, Morris 2-26H, Oakdale, Bakken; t5/11; cum 285K 10/17;  4-section spacing; cum 329K 11/24;
  

Here's the rest of the story:

• 18858, 715, CLR, Morris 3-26H, Oakdale, Bakken, t5/11; cum 478K 12/18;  (Kind of HUGE), 4-section spacing; off line as of 9/18; cum 522K 11/24;
  
• 18859, 680, CLR, Carson Peak 3-35H, Oakdale, Bakken, t5/11; cum 671K 12/18;  4 (Really HUGE); 4-section spacing; off line as of 10/18; cum 924K 11/24;
  
• 18861, 759, CLR, Carson Peak 2-35H, Oakdale, Bakken; t5/11; cum 718K 12/18;  (Really HUGE); 4-section spacing: off line as of 10/18; cum 752K 11/24;
  

This Eco-Pad is in the Oakdale oil field, a field we don't hear much about. That's because it is a very small field, all of eight (8) sections. In fact, it's hard to get more than a couple of Eco-Pads in a field this small. Smile.

The field is in the core Bakken, in the northwest corner of Dunn County and surrounded by some "name" oil fields, including Little Knife and Jim Creek. The field is "owned" by Continental Resources.

Just east of this Eco-Pad is another Continental Resources Eco-Pad, the Hawkinson-Whitman Eco-Pad, 4-section spacing:

• 20208, A/IA/960, CRL, Hawkinson 2-27H, Oakdale, Bakken; t9/11; cum 452K 12/18; off line as of 6/18; cum 526K 11/24;
• ******20210, 803, CLR, Whitman 2-34H, Oakdale, Bakken, t9/11; cum 1.629573 million bbls/112/18; FracFocus/NDIC: no record of refrack; huge jump 9/18; cum 1.828001 million bbls 1124;
  
• 20211, AB/263, CLR, Hawkinson 3-27H, Oakdale, Bakken; t9/11; cum 385K 10/17; cum 403K 11/24;
  
• **** 20212, 482, CLR, Whitman 3-34H, Oakdale, Bakken; t9/11; 308K 12/18; re-fracked 9/17; cum 1.154427 million bbls 11/24;

Just to the west of the Hawkinson-Whitman Eco-Pad is a superb CLR well:

• 17061, IA/664, CLR, Whitman 11-34H, Oakdale, Bakken; tested 6/08; 461K 12/18;

To the north is an old legacy well, still considered active, but last produced in 2008:

• 6130, 220/PA, RM Resources, Hawkinson 1-27, Oakdale, Madison; t8/77; cum 341K as of 1/12 but no production since 5/08, abandoned

Another nice horizontal well drilled in this boom in this oil field:

• 18275, 1,020, CLR, Hawkinson 1-22H, Oakdale, Bakken; t2/10; cum 712K 12/18; time to re-frack; cum 767K 11/24;
  

Others:

• 17079, 559, CLR, Carson Peak 44-2H, Oakdale, Bakken; t6/08; cum 311K 12/18; off line as of 11/18;cum 384K 11/24;
  
• 17334, 811, CLR, Morris 1-23H, Oakdale, Bakken, t11/08; cum 278K 12/18; off line as of 8/18; cum 395K 11/24;
  

Everything suggests this will end up being a very good field. Eight sections, two Eco-Pads: one wonders if this field is an early candidate for unitization.

Thirteen (13) New Permits -- Bakken, North Dakota, USA

Daily activity report, August 1, 2011 --

Operators: BEXP (4), Continental Resources (4), Slawson, Petro-Hunt, EOG, Marathon, and Strike Oil

Fields: Parshall, Squires, Elmore, Reunion Bay, Sakakawea, Lindahl, North Tobacco Garden and two wildcats.

This is Strike Oil's third permit in North Dakota. They currently have one other well in DRL status (permit 17632) and one inactive well (17606).

BEXP will have two wells on one pad, another in Sakakawea oil field, and a wildcat.

CLR will have another Eco-Pad with their four well permits, in Lindahl field, Williams County.

Petro-Hunt has the other wildcat, in Williams County,

Other news in the daily activity report:

One nice well:

• 20214, 2,004, BEXP, Field Trust 7-6 1H, Williams County

Bakken Operators Worried About Losing Their Leases? Sixteen (16) New Permits Today -- Sweet Sixteen -- Bakken, North Dakota, USA

Daily activity report, July 20, 2011 --

Operators: KOG (4), Hess (3), Whiting (2), BEXP (2), EOG, Newfield, EOG, North Plains Production, GE (GeoResource)

Fields: Pembroke, Climax, Pleasant Hill Ray, Sanish, Elk, Patent Gate, South Tobacco Garden, Wildrose, Parshall, and a wildcat.

KOG's four permits are on same section in Pembroke oil field (McKenzie), an Eco-Pad-like setup?

BEXP has the wildcat, in McKenzie County.

Two of the Hess wells will be on same permit in Ray field, Williams County.

Whiting has one permit in Pleasant Hill and one in their cash cow, Sanish oil field.

Two of three wells coming off confidential list had not data (DRL status, most likely); the third was Hess' EN-Lalim A-156-94-27H-1, in Mountrail County, with an IP of 250.

Crescent Point Energy canceled permit #10827, CPEC Ridgeway 25-36-163N-101W, Divide County.  (That NDIC entry, by the way, was filled with typographical errors.)

Eight (8) New Permits -- Eco-Pad Results -- Bakken, North Dakota, USA

Daily activity report, July 5, 2011 --

Operators: Samson Resources (2), BEXP (2), Dakota-3 (WMB), Whiting, Oasis, Enerplus

Fields: Antelope, Ragged Butte, Blooming Prairie, Sanish, Alger, Moccasin Creek

The two BEXP wells will be on the same pad in Ragged Butte (McKenzie County); likewise, the two Samson Resources wells will be on the same pad, Blooming Prairie, Divide County.

Whiting's permit is in its cash cow, the Sanish.

Enerplus is in Moccasin Creek, the reservation.

Producing wells completed include (an Eco-Pad):

• 19020, 744, CLR, Meadowlark 3-6H, Dunn County
• 19021, 879, CLR, Ckachenko 3-31H, Dunn County
• 19022, 453, CLR, Meadowlark 2-6H, Dunn County
• 19023, 726, CLR, Skachenko 2-31H, Dunn County

ad well as:

• 19167, 517, Oasis, Holmes 5601 44-32H, Williams County

In addition, another nine (9) wells came off the confidential list, but no production data provided except for one, which is not worth noting (19862, 86, CLR, Flor 24-10NH, Slope County) except for the fact that it was a North Red River B well, and not a Bakken.

This may or may not be interesting: a change of operator from EOG to Zenergy (was this based on a NDIC hearing? I don't know):

• 20286, Zenergy, Hardscrabble 2-0112H, Lot 2, S1-153N-103W (spelling error in the original report)

More On the Eco-Pad Permit Noted Yesterday -- Bakken, North Dakota, USA

Yesterday it was noted that CLR has four permits for an Eco-Pad series:

• File numbers: 20609, 20610, 20611, and 20612; a Salo/Hamlet Eco-Pad in section 35-160-96
• The two Salo wells will be long laterals going north, sections 35/26 in T160N-R96W
• The two Hamlet wells will be long laterals going south, sections 2/11 in T160N-R96W
• Spacing for all wells, according to the GIS map server: 1280-acre

There are already two producing wells in the same sections:

• 17587, 807, CLR, Salo 1-26H, spud 10/12/09; IP test date 4/11/10; total cumulative 59K,
• 17429, 435, CLR, Hamlet 1-11H, spud 9/26/08; IP test date 12/9/08; total cumulative 101K,
• Both are running about 2,000 barrels oil/month, slow decline now

At 101K cumulative, that well may be close to paying for itself (at the wellhead); if so, nice cash flow for the next 25 years as well as holding the acreage by production for more Bakken wells, or other formation.

Note: the relative short period to bring on-line #17429 compared to #17587, suggests problems with the well, or most likely, already seeing fracking backlog.

CLR: New Presentation -- Bakken, North Dakota, USA

Link here.

If you want to see a great photograph, go to slide 21 of this 25-slide presentation -- an Eco-Pad.

World proved reserves (billion barrels)

• Ghawar, Saudi Arabia: 140
• Rumalia, Iraq: 22
• Cantarell, Mexico: 11 - 20
• Prudhoe Bay, Alaska: 13
• Tupi, Brazil: 5 - 8
• Bakken: 11 - 24 (depending on analyst)
• Total official estimated US reserves: 19 billion

Fracking

• 24 - 30 stage fracs
• 8 stages per day
• Sand + ceramic proppant

Cost/Well Completion (CWC): $6.5 million
Increasing production rates (90-day average) (my estimate based on graph)

• 2007: 180 bbls/day
• 2008: 220 bbls/day
• 2009: 400 bbls/day
• 2010: 450 bbls/day

Higher IPs = higher EURs

More frac stages = higher EURs

CLR using 518 as representative for EUR in presentation

Similar to Whiting, CLR is estimating 8 horizontals on 1280-acre spacing units

CLR says IHS esimates North Dakota to produce 1,000,000 bbls opd by 2020; I've seen others suggest 1 million by 2015. The delta probably relates to infrastructure and takeaway capacity.

Eight (8) New Permits -- QEP With an "Eco-Pad-Like" Endeavor -- North Dakota, USA

On a day that we hit a new record for rigs actively drilling in North Dakota, we see eight (8) more permits.

Producers: QEP (4), SM (2 ), XTO, Zavanna.

Fields: Heart Butte, Long Creek, Elk, and West Ambrose.

XTO had one of the permits in Heart Butte, but QEP had four permits in Heart Butte. All four (4) are on the same pad. Is this an Eco-Pad-like endeavor? The four wells will be in section 32-150N-91W.

The rest of the daily activity report was pretty unremarkable, although Wesco got a nice well targeting the Red River in Golden Valley with an IP of 211. 

Eco-Pad Results -- Bonneville - Bridger -- North Dakota, USA

In today's (January 12, 2011) daily activity report: results of CLR's Eco-Pad in Rattlesnake oil field:

• 19009, Bonneville 3-23H, 651
• 19011, Bridger 3-14H, 725
• 19012, Bonneville 2023H, 365
• 19013, Bridger 2-14H, 399

CLR's Eco-Pad Update -- Bakken, North Dakota, USA

Long before others were saying anything at sites targeted to amateur armchair Bakken observers, I noted and posted at this blog, that fracturing only went out about 400 feet laterally. I first noted that in Whiting presentations, some of the best presentations among the E&P companies.

Long before others were saying anything at sites targeted to amateur armchair Bakken observers, I suggested that "they" were going to eventually put six to seven wells on a 1280-acre spacing unit. I noted that in the Whiting cases brought before the NDIC for approval (monthly hearing dockets).

Click here for Continental Resources' most recent presentation. Then go to slide 10.

If that link is broken or changes over time, the slide was a graphic of the CLR Eco-Pads:

• Eight wells on one Eco-Pad on 1280-acre spacing unit
• Four wells targeting the Bakken
• Four wells targeting the Three Forks Sanish
• Average EUR for each well: 500,000 bbls
• Equivalent to 2 million bbls per section
• Note the lateral reach of fracking

Yup.

Note: Whiting is doing about the same thing, but a little bit differently. [To clarify, WLL appears to be putting 7 - 8 wells on 1280-acre spacing units (in the best Bakken sites) but on separate pads, not multi-well pads.]

Note: Once all wells are completed on an Eco-Pad, it is my hunch that CLR will request that production from all eight wells be commingled for cost-savings; this will generate a lot of discussion among mineral rights owners. Whiting, although keeping the wells on different pads, will probably eventually request commingling of production from all wells in proximity to each other.

Note: EUR stands for estimated ultimate recovery; the estimate of the total amount of oil that will be recovered by an individual well or by a spacing unit, depending upon context in which it is used

Photograph and Video of a Continental Resources Eco-Pad (Bakken, ND, USA)

To see some of the nicest North Dakota landscape and a Continental Resources Eco-Pad, click here, and then go to slide #45 of this series of 79 slides. I assume over time, the corporate presentation will change, and this particular photograph will move to a different location within the presentation.

This is an incredible photograph.

Here is a promotional video of a CLR Eco-Pad.

A Dry Eco-Pad Well?

This is interesting. No fanfare. No announcement. In today's daily activity report (October 19, 2010), file number 18544, CLR, Kennedy 2-31T, SWSE 31-151N-96W, McKenzie County, 1,925 feet, Dimmick Lake: a dry hole.

Rare as hen's teeth: dry holes in the current boom in western North Dakota. Non-economical, occasionally, but "never" a dry hole.

This was CLR's first Eco-Pad, I believe, and one can find numerous postings about this well on this blog, by using the search application to find the Kennedy 2-31T.

Looking at the GIS Map Server, the other three wells on this Eco-Pad are long laterals and producing. There is a new permit/file number right next to the failed Kennedy 2-31T: #18946, Kennedy 2X-31H. My hunch: a drilling problem with Kennedy 2-31T. Kennedy 2X-31H is the "replacement."

More to follow, I'm sure.

CLR Restricting Production?

There are two very interesting items in CLR's most recent press release:

• The results of the Arthur-Hegler Eco-Pad
• A cryptic comment from the CEO stating that production from the wells is being restricted.

From the Continental Resources (CLR) press release, dated October 11, 2010, with regard to the Bakken (some figures rounded):

• CLR added 47,000 net acres in the Bakken, in the third quarter
• CLR now has 865,000 net acres leaded in the Bakken

CLR completed 26 company-operated gross wells (16.4 net wells) in the Bakken in 3Q10 (one-day tests):

• 18795, Bonney 2-3H, 1,765
• 18769, Roadrunner 1-15H, 1,722
• 18909, Rollesfstad 2-3H, 1,714
• 18679, Medicine Hole 2-27H, 1,702
• 19115, Mack 2-2H, 1,471
• 18584, Ravin 1-1H, 1,300
• 18958, Howard 1-5H, 1,201
• 18851, Bjella 1-24H, 1,029

Eco-Pad Results

The Arthur-Hegler Eco-Pad, one-day test: 4,359 boe, for an average of 1,090 boepd per well.
Harold Hamm, CLR/CEO: "We are producing these wells under restriction to conserve the energy resource and minimize flaring." Elsewhere someone has suggested that choking down keeps the pressure up and the proppants/sand in the stimulated fractures to keep the oil flowing. EUR is the important number, not the initial 24-hour flowback. If this is true, we might start seeing some lower 24-hour flowbacks if drillers are able to choke down immediately after fracking. I am way beyond my depth on this, so I will say no more.

The Arthur-Hegler Eco-Pad is at the eastern edge of the Little Knife oil field. Zooming in on these wells on the GIS map server suggests that the GIS map server is, in fact, an Etch-A-Sketch.

CLR's Arthur-Hegler Eco-Pad Reported Out Today

Three of the wells of CLR's Arthur-Hegler Eco-Pad reported out today (CLR presentation):

• 18747, Hegler 2-13H, 689 (1,203)
• 18515, Hegler 1-13H, 418 (1,195)
• 18513, Arthur 1-12H, 708 (?)
• 18748, Arthur 2-12H, 1,103, Last of the four to report; this is the farthest east of the four wells on this pad running west to east

The IPs outside the parentheses were from the NDIC Daily Activity Report; the number inside the parentheses were from a CLR presentation in October, except for Arthur 1-12H.

We'll have to see the cumulative numbers a year from now to really know how good these wells were.

Harold Hamm, CLR/CEO made a special comment on the October 11, 2010, press release regarding the Arthur-Hegler Eco-Pad.

Another Eco-Pad Permit for CLR -- Where CLR "Proved" Two Separate Formations

There is a lot of information hidden in this posting. Most notable is at the end of the day, CLR will know a lot more about the Middle Bakken and the TFS in this area of the "Bakken."

NDIC awarded a permit to CLR for -- what appears to be -- another Eco-Pad today (September 13, 2010). This one is in Williams County, section 12-159N-95W. It's in the North Tioga oil field which has a long history of activity with regard to conventional wells, but fewer horizontal wells.

The four wells will be in the SWSW sub-quadrant of section 12, lined up west to east, all of them 250 feet from the south line. If this is an Eco-Pad, then I would expect two of the long horizontal laterals would go due north through sections 12 and 1. The other two long horizontal laterals would go due south through sections 13 and 24.

The four permits:

• 19534, Lawrence 2-13H
• 19535, Omar 3-12H
• 19536, Lawrence 3-13H
• 19537, Omar 4-12H

Two will target the TFS and two will target the Middle Bakken if this is a typical Eco-Pad

There are currently three long horizontals in these sections:

• 17745, Lawrence 1-24H, 616, CLR, long lateral, going due north through sections 24 and 13 (sited in section 24)
• 18352, Omar 2-1H, 431, CLR, long lateral, going due south through sections 1 and 12
• 17282, 660, Omar 1-1H, CLR, long lateral, exactly parallel to 18352 , going through sections 1 and 12. 

18352 is about 50 feet west of 17282.

With regard to the Omar wells, here is an earlier report:

18352, Omar 2-1H (second of two), 694
17282, Omar 1-1H (first of two), cumulative 137K in about 15 months (huge well), 660

(Omar 1-1H, completed in 3rd quarter of 2008, had produced a cumulative 137,300 boe at year-end 2009. At $60/bbl = $8.25 million.) Omar 1 and Omar 2 were drilled by CLR as a test to see if the Bakken and the TFS were separate formations. The fact that Omar 1 produced a cumulative 137,300 boe even though Omar 2 was drilled parallel to and offset from Omar 1, suggests to some that the two formations, at least in this locality, are separate.) Bice 1-29H (#16943) had an IP of 516.  Folks are wondering what this is all about. I, too, am curious. 

Bottom line: CLR is going back in with an Eco-Pad exactly where they "proved" to themselves that the Bakken formation is separate from the TFS formation.