Moving To Twenty Wells In 1280-Acre Drilling Units In The Bakken -- August 6, 2019

Generally speaking, fourteen wells is about the maximum number of wells I've seen in any 1280-acre drilling unit in the Bakken. If any 1280-acre unit has more than fourteen wells, they are few and very far in between.

However, in the August, 2019, NDIC hearing dockets:

Case 27809, Newfield, Siverston-Bakken; 14 wells on each of two existing 1280-acre units; 6/7-150-98; and, 30/31-151-98, McKenzie; already 6 wells on each of these units; this will make it 20 wells in each of these 1280-acre units;

Reminder: that's a case, not a permit.

It's been said that operators won't drill wells in the Bakken if the EUR is not at least one million bbls.

Back of the envelope ciphering:

20 wells x one million bbls (EUR) = 20 million bbls

20 million bbls x $50 / bbl = $1,000,000,000 ($1 billion)

Each well with  infrastructure, etc: $10 million/well (wells are now costing about $6 million to drill/complete).

20 wells x $10 million/well = $200,000,000 ($200 million)

$1 billion - $200 million = $800 million

$800 million / 1280 acres = $625,000 / acre.

CLR's Well-Spacing Pilot Projects -- Previously Posted

CLR's May, 2013, corporate presentation (this is a dynamic link, and the presentation will change over time), a PDF:

Slide 31: CLR's 160-acre density spacing for the middle Bakken and Three Forks formations. I've seen this slide before and I think I've even posted links to it with comments. Some observations:

the 320-acre spacing pilot project

• long laterals on 1280-acre spacing units
• 4 wells per formation (that's where the 320-acre spacing comes from: 1280 acre/4 = 320 acres)
• 4 formations (MB, TF1, TF2, TF3)
• 23 net wells across three pilot projects
• $123 million net cost/23 net wells = $5.3 million/well

the 160-acre spacing pilot project

• long laterals on 1280-acre spacing units
• 8 wells per formation (that's where the 160-acre spacing comes from: 1280 acre/8 = 160 acres)
• 4 formations (MB, TF1, TF2, TF3)
• 6 net wells - one pilot project
• $36 million net cost/6 net wells = $6 million/well

Just How Effective Is Fracking (Radially)?

Early on, I suggested the "effectiveness" of fracking extends out no more than 500 feet radially. See this note posted back on October 11, 2011:

Somehow the conversation got around to "how many wells in a section?"

Of course that depends on how many formations one is talking about and how "good" the location is.

There is also the question of how effective fracturing is the farther one gets away from the borehole. I suggested that the general consensus is that fracturing is effective out to 500 feet laterally (500 foot radius, or 1,000 feet diametrically) suggesting 4 to 5 wells average across a 5,280-foot section line. Note: "general consensus" in previous sentence.

I suggested that it is very likely that fracturing is not necessarily effective that far out. I am way beyond my depth here, so it was just idle chatter. And then this: Coincidentally I see that "luckyone" elsewhere has opined the very same thing -- back on September 22, 2011. I don't recall reading that entry before (although I probably have) but the point is that there are at least a couple of us armchair observers suggesting that it may be as little as 300 feet laterally or radially. That is a game changer. I also think (and have previously posted) that the farther away from the well, the less effective the fracturing. And, of course, that is borne out by the number of reports in which not all stages were successfully fracked, and usually it is farther out than closer in.

Fast forward to May, 2013, and Oasis corporate presentation, slide #10. Oasis plans to:

• vary spacing distances to as low as 400 feet in certain areas (equates to 6 wells per formation in single spacing unit). [The link will take you to the current corporate presentation which will change over time; this refers to the May, 2013, Oasis presentation only.]

If that pans out, and there are four payzones in the "better" Bakken (middle Bakken, TF1, TF2, TF3), that could be as many as 24 wells in one spacing unit. [By the way, CLR has a graphic that suggests one could see as many as 40 wells in one spacing unit.]

24 x 300,000 = 7.2 million bbls/spacing unit @$50/bbl = $360 million/spacing unit.

By the way, contrary to some folks' early concern, there are now indications that fracking a "new" well actually improves the production of an older, neighboring well. Of course, the jury is still out on that, but it certainly makes common sense.

Another CLR 14-Well Section: The CLR Mack Wells In Antelope-Sanish

Permits

See below: original case -- 17 wells on 640-acre spacing unit.

These are the new permits since the original post. At some point, I may consolidate all the Mack wells to make them easier to track (again, IPs, production, are updated).

• 26627, 283, CLR, Mack 13-2H3, Antelope, t10/14; cum 20K 3/15;
• 26629, 516, CLR, Mack 12-2H2, Antelope, t9/14; cum 35K 3/15;
• 26630, 630, CLR, Mack 11-2H1, Antelope, t8/14; cum 34K 3/15;
• 26631, 289, CLR, Mack 10-2H3, Antelope, t8/14; cum 11K 3/15;
• 26632, 202, CLR, Mack 9-2H2, Antelope,  t8/14; cum 26K 3/15;
• 26633, 481, CLR, Mack 8-2H, Antelope, t8/14; cum 45K 3/15;

Updates

June 20, 2015: Mack wells updated here. 

March 3, 2015: look at the same section today, compared to that taken for the original post:

Original Post

 
Antelope oil field.

This is section 2-152-94, as of June 1, 2013:

It should be noted that under the "24499/25524" there are three wells on confidential status. These were originally three Petro-Hunt permits but they were all canceled. Now, identical siting, but different permits, and a different operator: G3 Operating.

In addition, under the rig and #24359, there are two wells.

Interestingly enough, that one 640-acre spaced unit is the only single-section-space unit in the immediate area; it is surrounded by 1280-acre spaced units.

So, I count 10 wells sited in that section. The three G3 Operating wells will run south into sections 11/14.

So I count 7 short lateral wells in that section (2-152-94).

Big deal, huh?

In the June 26 - 27, 2013, NDIC hearing dockets, CLR's request for 17 wells in this 640-acre spaced wells to this section. There is some confusion: they call this the Sanish pool but in fact wells are targeting both the middle Bakken and the Three Forks.

• 20464, CLR, Antelope-Sanish, 17 wells on a 640-acre unit

And that gives us the 24-well section CLR has been talking about.

• 17640, 380, CLR, Mack 1-2H, Antelope, a Three Forks well, t3/09; cum 176K 3/15; CS 11,183; TD 15,544; 157,920 lbs sand;
• 19115, 609, CLR, Mack 2-2H, Antelope, a middle Bakken well, t10/10; cum 158K 3/15; CS 10,915, TD 15,767; 15 stages; 1.26 million lbs sand and ceramic;
• 20623, 571, CLR, Mack 3-2H, Antelope, a middle Bakken well, t10/11; cum 129K 3/15; CS 10,912; TD 15,955; 15 stages; 1.42 million lbs;
• 21151, 446, CLR, Mack 5-2, Antelope, a middle Bakken well, t11/12; cum 111K 3/15; CS 10,704; TD 15,650; 15 stages; 1.26 million lbs sand and ceramic;
• 21152, 901, CLR, Mack 4-2H, Antelope, a Three Forks well, t11/12; cum 165K 3/15; CS 11,015; TD 16,192; 15 stages; 1.26 million lbs sand and ceramic;
• 24358, 206, CLR, Mack 6-2H, Antelope, t813; cum 57K 3/15;
• 24359, 842, CLR, Mack 7-2H, Antelope, t8/13; cum 74K 3/14;

Disclaimer: I am assuming 17 "additional" wells in this section; it's possible that CLR is only asking for 7 more wells to be sited in the section, which would result in a 14-well array. 

Click here for a graphic of a 14-well array on 1280-acre spacing; the above is on a 640-acre spacing unit.

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

[Note: EOG's Fertile 53-3024H, Section 30-151-90 accidentally filed with #20623.]

Fourteen CLR Wells In Section 6-153-101, Baker Field, Southwest of Williston -- Case No 20154, April Hearing Dockets; 14-Well Array

Updates

January 19, 2019: production data updated below the graphic. In the big scheme of things, these wells have been disappointing.

September 21, 2014: one can see the fourteen donkeys at this Vern Whitten site, photo #23, Summertime In The Bakken. 

January 15, 2015: an alert reader noted there are two laterals coming off #23362 on the Atlanta pad. The two horizontals seemed to have been there "from the beginning."

January 1, 2014: update on the Atlanta wells. They have all been drilled to depth, and the last 12 are now on DRL status. Activity during the past two months suggests that they are now being fracked. This is how the NDIC GIS server map now looks:

September 24, 2013: the status of the Atlanta wells as of this date on the NDIC GIS server map:

Zooming in on the wells, note the salt water disposal well in the far northwest corner:

June 1, 2013: another 14-well array -- the CLR Mack wells in Antelope-Sanish. 

Original Post

An aerial photograph of this 14-well pad can be seen at the Rolfstad Presentation, slide # 43. In that photograph, the Williston-Missouri River bridge can be seen at the top left of the photograph.  One can also make out, just barely, the Burlington Northern track running along the river; the track is between the pad and the river. Go to this post to get links to the photograph, the presentation, and the graphic layout of the pad.

These wells will be important to note when they come off the confidential list. In the northeast corner of the section, CLR has three pads: two 4-well pads, and one 6-well pad, as well as a salt water disposal well. It looks like these 14 wells are on 2560-acre spacing.

From west to east (IPs and production updated August 6, 2014):

• 23372, 364, CLR, Atlanta 1-6H, Baker, middle Bakken; 27 stages; 3.1 million lbs sand/ceramic; t4/13; cum 159K 9/19; taken offline in September, 2013; back on-line 2/14;
• 23371, 499, CLR, Atlanta 2-6H, Three Forks, Baker, t3/14; cum 72K 9/19;
• 23370, 597, CLR, Atlanta 3-6H, Baker, middle Bakken; 27 stages; 3.2 million lbs sand/ceramic; t4/13; cum 215K 9/19; taken offline in October, 2013;
• 23369, 370, CLR, Atlanta 4-6H, Three Forks, Baker, t3/14; cum 77K 9/19;

• 23368, 441, CLR, Atlanta Federal 5-6H, middle Bakken, Baker, t3/13; cum 180K 9/19;
• 23367, 540, CLR, Atlanta Federal 6-6H, Three Forks, Baker, t3/14; cum 104K 9/19;
• 23366, 527, CLR, Atlanta Federal 7-6H, middle Bakken, Baker, t3/14; cum 183K 9/19;
• 23365, 311, CLR, Atlanta Federal 8-6H, Three Forks, Baker, t3/14; cum 115K 9/19;

• 23364, 583, CLR, Atlanta Federal 9-6H, Baker, middle Bakken, t3/14 cum 144K 9/19;
• 23363, 410, CLR, Atlanta Federal 10-6H, Baker, Three Forks, gas 237, 42 - 3420; trip gas 200 - 8,100; t3/14; cum 87K 9/19;
• 23362, 604,  CLR, Atlanta 11-6H, Baker, middle Bakken, two horizontal laterals; t3/14; cum 140K 9/19;
• 23361, 407, CLR, Atlanta 12-6H, Three Forks, Baker, t3/14; cum 82K 9/19;
• 23360, 522, CLR, Atlanta 13-6H, Baker, middle Bakken, t4/14; cum 116K 9/19;
• 23359, 343, CLR, Atlanta 14-6H, Baker, 27 stages, 3 million lbs, Three Forks, gas 82, 82 - 1388, trip gas 2,500 - 4,200; t3/14; cum 107K 9/19;

See this SeekingAlpha article for possible configuration of these wells. A quick run-through of the dockets over the past year would suggest this will become the norm.

The Wahpeton Family Of Wells: Another Look At CLR's Testing The Lower Benches of the Three Forks, Banks Oil Field; Natural Gas Flaring Continues to Decrease (As A Percentage of Production) -- January 27, 2013

Updates

July 22, 2020: 

• 335914, SI/A, CLR, Wahpeton 16-16H1, 33-053-08890, Banks, t--; cum 116K over 3 months,7 days; fracked 12/6/2019 - 12/17/2019; 7.143 million gallons of water; water 88.52% by mass; Three Forks first bench; vertical operations required three BHAs; curve build with one BHA, no problems; the lateral was completed with a single BHA; drilled out of the shoe on July 29, 2019; TD reached on August 2, 2019; four days to drill the lateral; background gas, moderate;

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	5-2020	31	29504	29655	24396	53683	53276	0
BAKKEN	4-2020	30	25690	25268	24697	41414	41020	0
BAKKEN	3-2020	31	42567	43003	40235	66283	66283	0
BAKKEN	2-2020	7	17874	17185	14630	23089	22139	950
BAKKEN	1-2020	3	117	117	2218	758	0	758

 

July 19, 2020: another CLR Wahpeton well comes off the confidential list this week.

• 35914, conf, CLR, Wahpeton 16-16H1, Banks,

Date	Oil Runs	MCF Sold
5-2020	29655	53276
4-2020	25268	41020
3-2020	43003	66283
2-2020	17185	22139
1-2020	117	0

July 12, 2020: updated graphic --

June 4, 2020: see this post. Updated graphics:

June 3, 2020: production data update, see below: see this update --

• 35915, SI/A, CLR, Wahpeton 17-16H, Banks, t--; cum 107K in 2.5 months;

November 28, 2017: production data updated; five wells now AB/TA. 

December 11, 2016: production of these wells updated; see below; five wells now IA/AB/TA. 

February 9, 2014: screenshot of the Wahpeton Pad, this date.

September 11, 2013: from Mike Filloon --

The most important is the Wahpeton Pad. Continental chose the important location to drill a total of 32 wells from the middle Bakken to the 3rd bench. Since this was the first 160-acre pilot project, it very well could be the best area overall for pad drilling. 

Original Post

From a Continental Resources exhibit. Sent in by a reader:

The Wahpeton wells are sited in section 16, and run north to south, ending in section 21. This page is updated periodically, last update, July 12, 2020.

• 19450, 322, CLR, Wahpeton 1-16H, Banks, t7/11; cum 253K 4/20; off line 5/20;

• 24843, 1,050, CLR, Wahpeton 6-16H, Banks, t6/14; cum 176K 4/20; off line 5/20;
• 24809, 1,786, CLR, Wahpeton 9-16H, Banks, t5/14; cum 221K 4/20; off line 5/20;
• 24840, 382, CLR, Wahpeton 4-16H1, Banks, t7/14; cum 85K 4/20; off line 5/20;
• 24810, 550, CLR, Wahpeton 8-16H1, Banks, t6/15; cum 138K 4/20; off line 4/20;
• 24807, 354, CLR, Wahpeton 11-16H1, Banks, t6/14; cum 101K 4/20; off line 4/20;
• 24837, 652, CLR, Wahpeton 2-16H2, Banks, t6/14; cum 122K 4/20;
• 24842, IA/411, CLR, Wahpeton 5-16H2, Banks, t6/14; cum 69K 2/20; off line 2/20; remains off line 5/20;
• 24808, IA/IAW/AB/IA/366, CLR, Wahpeton 10-16H2, Banks, t6/14; cum 20K 6/19;
• 24804, AB/IAW/AB/1,031, CLR, Wahpeton 14-16H2, Banks, t5/14; cum 24K 8/15;
• 24838, TA, CLR, Wahpeton 3-16H3, Banks, no production;
• 24844, IAW/AB/334, CLR, Wahpeton 7-16H3, Banks, t6/14; cum 23K 5/16;
• 24806, A/IAW/AB/1,031 CLR, Wahpeton 12-16H3, Banks, t5/14; cum 17K 3/20; off line 4/20;
• 24805, 1,612, CLR, Wahpeton 13-16H3, Banks, t5/14; cum 213K 5/20; remains on line in 5/20;

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

Meanwhile, the "Charlotte" wells sited in either section 22 or 27-152-99, Banks, but all probably drilling 22/15-152-99:

• 19918, 496, Charlotte 1-22H, middle Bakken, SWSE 22-152-99; Banks, 30 stages; 2.5 million lbs; t6/11; cum 360K 4/20; total depth: 21,090 feet;
• 23664, 657, Charlotte 3-22H, Banks, TF1, SESE 22-152N-99W, t11/12; cum 186K 4/20;
• 21128, 692, Charlotte 2-22H, Banks, TF2, SWSW 22-152-99; 30 stages; 2.3 million lbs; t10/11; cum 255K 4/20; total depth: 21,358 feet;
• 23612, 673, Charlotte 4-22H, TF3, 4 secs, Banks, [Update: see press release, December 3, 2012], t7/13; cum 173K 4/20;
• 23608, 1,303, Charlotte 5-22H, Banks, ?TF4, 4 secs; t6/13; cum 248K 4/20;
• 23664, 657, CLR, Charlotte 3-22H, Banks, t11/12; cum 186K 4/20;

So, unless I'm misreading the GIS map server and/or the permits, it appears the Wahpeton wells will be parallel to the Charlotte wells, in adjoining sections (spacing units). But the Wahpeton wells will be running north-to-south; and the Charlotte wells will be running south-to-north.

By the way, look at #23664, Charlotte 3-22H, still confidential, but production runs for first month:

Date	Oil Runs	MCF Sold
11-2012	7583	12383

What do you notice?  Yes, it was hooked up to a natural gas pipeline almost immediately. As the well density increases, the natural gas flaring will take care of itself. Already we are starting to see this happen on a larger scale. In the most recent Director's Cut:

Additions to gathering and processing capacity are helping with the percentage of gas flared dropping to 29%. The historical high was 36% in September 2011.

With more wells/month being drilled; more production/well; to see a downward trend this early in the boom speaks volumes about a non-issue.

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

And, then, of course, to the east, in the next spacing unit to the east are the very good Chicago/Syracuse wells.