Sunday, November 4, 2012

The Paradox Basin: MDU Teaser/Cryptic Comment; Now Million-Plus EURs

Updates

June 29, 2016: BLM to okay 6,000 new Newfield wells (MDU no longer involved, after selling Fidelity).

December 17, 2015: random update on the Moab/Paradox Basin, from MDU perspective.

May, 2015: Cane Creek shale of the Paradox Basin, geology report/summary.

November 1, 2014: random update on the Moab/Paradox Basin:
An interesting thing happened after Fidelity Exploration and Production Co. started drilling near the entrance to Dead Horse Point State Park.
Cane Creek Well 12-1 let loose.
Without the aid of pumps or fracking, the oil just flooded out — more than 600,000 barrels in its first year, making it the nation’s most productive on-shore well in 2012.
The hydrocarbon bounty, however, includes unexpectedly large amounts of methane and other components of natural gas that Fidelity has to burn off because there is no way to get those fuels to market.
To solve its delivery problem, the company proposes an intensive network of pipelines that is fueling a backlash among red-rock recreationists and preservationists alike.
My understanding was that when this well hit in 2012, it was the largest onshore well in 2012 in the lower 48. In February, 2014, it was still flowing without a pump; I don't know if it still is.

April 13, 2014: Million-plus EURS in the Paradox Basin for MDU, far exceeding Fidelity EURs in the Bakken.
 
Original Post
 
It's possible I missed it or did not understand the transcription, but there seemed to be a teaser /cryptic comment made by MDU without expanding on it. I was surprised that it was not followed in the Q&A unless the analysts are all aware of this particular project. This from the transcript:
"...quality insight electrical work...where we've been engaged on a substantial project. Further development in the region by our major tech company should provide opportunities going forward from both our materials and our service business." 
But the particular project was not mentioned, unless I missed it. I am open to suggestions. [May 2, 2013: in their 1Q13 earnings conference call, MDU said:
Included in the forecast is 86 million for the 88-megawatt simple cycle natural gas turbine to be located adjacent at our Heskett Generating Station here in Mandan, North Dakota ...
I wonder if that might not be the answer to the question.]

So, this is how I see MDU: solid, possibly turning the corner but will depend on economy outside the Bakken. The Bakken is driving earnings now. The usual comments about requests for rate increases for their regulated utilities. The natural gas segment is a drag on earnings -- as it is for everyone in the natural gas business. But then this: the Paradox Basin could be a game changer for MDU. From the transcript:
Now moving on to the Paradox basin, to put that simply, the Paradox basin is a potential game changer for us. As we mentioned before, we kick things off in this play with a great well that was a Cane Creek unit number 26-2H well. Then our next two wells were completed open hole and did not turn out so well, so we’ve returned to [cast] hole completions. We recently put the Cane Creek unit 12-1H well on production and it has been consistently producing approximately 1,500 barrels of oil a day over the past three weeks. It has a flowing pressure above 2,800 PSI. We have 50 to 75 future locations with gross EURs estimated up to 1 million barrels and perhaps beyond.
For newbies: in the Bakken, EURs are in the 500K - 700K range; in the sweet spots, EURs up to 900,000 are being estimated. Rarely folks talk about 1 million bbl-EURs in the best Bakken.

The Paradox Basin is centered at Four Corners, USA (Colorado, New Mexico, Arizona, Utah). From various USGS PDF files the unconventional shale sounds a lot like the Bakken:
Reservoirs: The play depends on extensive fracturing in the organic-rich dolomitic shale and mudstone in the interbeds between evaporites of the Pennsylvanian Paradox Formation or carbonate and clastic rocks of the related cycles on the shelf of the Paradox evaporite basin. These shales and mudstones may be as thick as 130 ft but are more commonly less than 20 ft thick
Source rocks: These organic-rich black dolomitic shales and mudstones are the source rocks for most, if not all, of the oil and gas in the Paradox Basin. Total organic carbon commonly ranges from 1 to 5 percent but may be as high as 20 percent. Oil produced by these source rocks typically has 40û–43û API gravity and low sulfur content.
Exploration status and resource potential: Until recently, the only significant production from this play was from the Cane Creek Shale in the Lone Canyon field discovered in 1962. Recently, nearby Bartlett Flat field has been developed by directional drilling in the Cane Creek Shale at a depth of approximately 9,000 ft. The Cane Creek, Chimney Rock, Gothic, and Hovenweep Shales have the most potential due to both organic content and thickness.
The USGS summary: The USGS assessed undiscovered, technically recoverable oil and gas resources in nine assessment units in the Paradox Basin. Four conventional AUs were assessed to contain means of 89 million barrels of oil (MMBO), 833 billion cubic feet of gas (BCFG), and 18 million barrels of natural gas liquids (MMBNGL). Four unconventional AUs were assessed to con- tain means of 471 MMBO, 11,868 BCFG, and 472 MMBNGL. The Kaiparowits Plateau Coalbed Gas AU was assessed to contain a mean of 450 BCFG. The assessment was based on 2011 IHS well and production data.

For newbies: compare the USGS assessment of the Paradox Basin (above) with the USGS assessment of the Bakken back in 2008:
The USGS estimated 3.65 billion barrels of recoverable oil in five "assessment units" in the Montana and North Dakota Bakken Pool.
Here are the assessment units (AU), amount of estimated recoverable oil, and percent (in terms of acreage) in Montana/North Dakota:

  • Northwest Expulsion Threshold AU, 868 million barrels, 80/20 (MT/ND)
  • Eastern Expulsion Threshold AU, 973 million barrels, 100 (ND)
  • Nesson-Little Knife Structural AU, 909 million barrels, 100 (ND)
  • Elm Coulee-Billings Nose AU, 410 million barrels, 55/45 (MT/ND)
  • Central Basin-Poplar Dome AU, 485, 45/55 (MT/ND)

End of Coal Union in North Dakota?

Link here to the Bismarck Tribune.

The Coyote Station Power Plant is a coal-fired power station south of Beulah, North Dakota, with four owners and operated by Otter Tail Power, Fergus Falls, MN.

It currently receives its coal from the last union-operated coal mine in North Dakota: the Dakota Westmoreland.

In four years, 2016, the contract between the power plant and the coal mine will end. The power plant has announced that it will get its coal from a new non-union mine:
The Coyote Station owners announced last month they’ll switch to a new coal provider starting May 2016.
North American, owner of the two largest coal mines in the state and both non-union, will open a new mine they’re calling Coyote Creek Mining Co. just west of Dakota Westmoreland’s open coal pits.
Coyote Creek Mining Co. exists in coal lease documents for now. The Public Service Commission must issue a mining permit and North American won’t make application for the 13-square-mile reserve area until next year or possibly 2014, says its spokesman David Straley.
The contract would expire in 2040.
As usual, lots of story lines. Go to the link for more information. 

Pipelines in the Bakken? The Story is Just Beginning

Link to the Dickinson Press.

The story is about the frustration, irritation, patience, relationships, etc., with regard to all the pipeline that is being laid in the Bakken.

But when you get past the human interest part of the story here are the data points and quotes:
In North Dakota, 74 percent of crude oil is gathered by truck and 26 percent gathered by pipeline, according to Kringstad. For Williams County, the ratio is 95 percent truck and 5 percent pipeline.
“That’s not sustainable,” said Lynn Helms, director of the Department of Mineral Resources. “That’s not a paradigm that we can live with long-term.”
But the process to obtain easements for pipeline projects is taking longer and becoming more expensive, Helms said.
The price to obtain an easement used to be about $25 per rod, or 16-1/2 feet, but now the price can be as high as $135 per rod, Dukart said.
The prices have risen similarly in Williams County, with landowners typically not accepting less than $100 a rod, Jorgenson said.
Five years of explosive growth in the Bakken and 95 percent of Williams County production is still "gathered" by trucks. I don't even know where to begin: there are so many story lines one could explore. 

Antelope Field

Updates

June 1, 2013: NDIC June hearing dockets; 17 wells in section 2-152-94.

January 18, 2013: with four new CLR permits, CLR will have 10 wells sited in section 3-152-94



  • 33238, conf, AN-Dinwoodie-153-94-2833H-8,
  • 33237, conf, AN-Dinwoodie-153-94-2833H-7,
  • 33236, conf, AN-Dinwoodie-153-94-2833H-6,
  • 33235, conf, AN-Dinwoodie-153-94-2833H-5,
  • 33234, conf, AN-Dinwoodie-153-94-2833H-4,
  • 32862, 1,952, Hess, AN-Dinwoodie-LE-153-84-2833H-1, Antelope, Sanish, 60 stages; 6 million lbs (small/large), t10/17; cum --
  • 32861, 2,202, Hess, AN-Dinwoodie-153-94-2833H-3, Antelope, Sanish, Three Forks, 60 stages; 6 million lbs (small/large), t10/17; cum --
  • 32860, 2,708, Hess, AN-Dinwoodie-153-94-2833H-2, Antelope, Sanish, 60 stages, 4.2 million lbs (small/large), t10/17; cum --;
  • 19887, conf, AN-Dinwoodie-153-94-2833H-1, Antelope, Sanish, t7/11; cum 221K 9/17; off-line of course as of 8/17; frack data never provided; permitted as a double lateral, the middle Bakken lateral 2 and a Three Forks lateral 1; only the Three Forls was drilled; the lateral was drilled 100% within the upper portion of the Three Forks with greater than 70% of the well bore to be completed within the ideal preferred target porosity;
Permits


2019 (as of January 13, 2019)
None.

2018 (complete)
35865,
35864,
35863,
35862,

35861,
35811,
35810,

35716,
35546,
35545,
35544,
35543,
35542,
35541,
35540,
35539,
35493,
35492,
35491,
35490,
35489
35488,
35487,

35370,
35369,
35368,
35367,
35366,
35365,
35364,
35095,
35094,
35093,
35092,
35091,

35068,
35067,
35066,
35065,
35064,
35063,
35062,
35061,
35060,
35059,

34966,
34965,
34964,
34963,
34962,
34961,

34884,
34883,
34882,
34881,

34880,
34680,
34679,
34678,
34677,
34676,
34584,
34583,
34582,
34581,
34580,
34577,
34576,
34575,
34488,
34487,
34486,
34485,

2017 (complete)
34385,
34384,

34342,
34071,
34070,
34069
33966,
33639,
33638,
33637,
33636,
33602,
33601,
33494, loc, MRO, Timothy USA 11-1TFH-2B,
33493, loc, MRO, Mark USA 11-1H,
33492, loc, MRO, Mamie USA 21-1TFH,
33491, loc, MRO, Shoots USA 41-2H,
33461, loc, Enerplus, Mesa
33460, loc, Enerplus, Gully
33459, loc, Enerplus, Canyon
33458, loc, Enerplus, Ravine
33416, conf, MRO, Miles
33415, conf, MRO, June
33414, 5,524, MRO, Wilbur USA 31-2TFH, Antelope-Sanish, t4/18; cum 289K 11/18;
33413, conf, MRO, Chauncey
33412, conf, MRO, Winona
33334, loc, EOG, Clarks Creek
33290, conf, MRO, Lena
33281, 3,026, MRO, Iron Woman USA 14-9H, t7/17; cum 355K 11/18;
33280, PNC, EOG, Clarks Creek
33279, PNC, EOG, Clarks Creek
33278, PNC, EOG, Clarks Creek
33277, PNC, EOG, Clarks Creek
33276, PNC, EOG, Clarks Creek
33275, PNC, EOG, Clarks Creek

2016 (the list is complete)
33238, conf, AN-Dinwoodie-153-94-2833H-8,
33237, conf, AN-Dinwoodie-153-94-2833H-7,
33236, conf, AN-Dinwoodie-153-94-2833H-6,
33235, conf, AN-Dinwoodie-153-94-2833H-5,
33234, conf, AN-Dinwoodie-153-94-2833H-4,
33204, conf, Petroshale, Petroshale
33203, conf, Petroshale, Petroshale
33202, conf, Petroshale, Petroshale
33011, conf, Petroshale, Petroshale
33010, conf, Petroshale, Petroshale
33009, conf, Petroshale, Petroshale
33008, conf, Petroshale, Petroshale
33007, conf, Petroshale, Petroshale
33006, conf, Petroshale, Petroshale
33005, conf, Petroshale, Petroshale
33004, conf, Petroshale, Petroshale
33003, conf, Petroshale, Petroshale
33002, PNC, Petroshale, Petroshale
33001, PNC, Petroshale, Petroshale
32891, conf, MRO, Begola
32890, conf, MRO, Murphy
32889, conf, MRO, Lockwood
32888, conf, MRO, Forsman
32865, 3,634, MRO, Demaray USA 41-2TFH, Antelope-Sanish, t4/18; cum 232K 11/18;
32862, 1,952, Hess, AN-Dinwoodie-LE-153-84-2833H-1, Antelope, Sanish, 60 stages; 6 million lbs (small/large), t10/17; cum 208K 11/18;
32861, 2,202, Hess, AN-Dinwoodie-153-94-2833H-3, Antelope, Sanish, Three Forks, 60 stages; 6 million lbs (small/large), t10/17; cum 201K 11/18;
32860, 2,708, Hess, AN-Dinwoodie-153-94-2833H-2, Antelope, Sanish, 60 stages, 4.2 million lbs (small/large), t10/17; cum 164K 11/18;
********************32849, conf, Enerplus, Redbelly
********************32832, conf, Enerplus, Garter
********************32831, conf, Enerplus, Garter
********************32830, conf, Enerplus, Smooth Green
32778, conf, Petroshale, Petroshale US 10H,
32777, conf, Petroshale, Petroshale US 9H,
32767, 2,759, Petroshale, Petroshale US 8H, Antelope-Sanish, t1/17; cum 359K 11/18;
32600, conf, WPX, Ruby Parshall 31-30HZ,
32599, conf, WPX, Ruby Parshall 31-30HC,
32598, conf, WPX, Ruby Parshall 31-30HY,
32572, conf, EOG, Hawkeye 12-2413H,
32571, conf, EOG, Hawkeye 11-2413H,
32570, conf, EOG, Hawkeye 156-2413H,
32569, conf, EOG, Hawkeye 155-2413H,
32568, conf, EOG, Hawkeye 154-2413H,
32567, conf, EOG, Hawkeye 1153-2413H,
32566, conf, EOG, Hawkeye 152-2413H,
32565, conf, EOG, Hawkeye 118-2413H,
32564, conf, EOG, Hawkeye 115-2413H,
32563, conf, EOG, Hawkeye 112-2413H,
32526, conf, MRO, Arden USA 14-9TFH,
32525, conf, MRO, Kermit USA 14-9H,
32524, conf, MRO, Reno USA 24-9TFH-2B,
32455, conf, MRO, Cunningham USA 31-4H,
32454, conf, MRO, Garness USA 31-4TFH-2B,
32453, conf, MRO, Marcella USA 21-4TFH,
32452, 3,004, MRO, Grady USA 21-4H, Antelope-Sanish, t8/17; cum 291K 11/18;
32444, PNC, Petroshale, Petroshale US H1,
********************32431, conf, Bruin/HRC, Fort Berthold 151-94-26B-35-13H, huge well;

2015 (list is complete)
32233, drl, Bruin/HRC, Fort Berthold 151-94-15A-22-8H,
32232, drl, Bruin/HRC, Fort Berthold 151-94-15A-22-9H,
32216, conf, EOG, Hawkeye 129-2413H,
32215, conf, EOG, Hawkeye 127-2413H,
32214, conf, EOG, Hawkeye 130-2413H,
32213, conf, EOG, Hawkeye 128-2413H,
32212, conf, EOG, Hawkeye 126-2413H,
32211, conf, EOG, Hawkeye 4-2413H,
32158, 2,128, Bruin/HRC, Fort Berthold 152-94-13B-24-13H,
32157, 1,758, Bruin/HRC, Fort Berthold 152-94-13B-24-11H,
32156, 416, Bruin/HRC, Fort Berthold 152-94-13B-24-12H, t9/17; cum 90K 11/18;
31995, 1,706, Bruin/HRC, Fort Berthold 152-94-13A-24-16H, t9/17; cum 230K 11/18;
31994, 769, Bruin/HRC, Fort Berthold 152-94-13A-24-15H, t9/17; cum 172K 11/18;
31945, 392, ERF, Fire 151-94-16DH, Antelope-Sanish, t2/17; cum 218K 11/18;
31944, 972, ERF, Water 151-94-16DH-TF, Antelope-Sanish, t2/17; cum 173K 11/18;
31943, 690, ERF, Furlong 151-94-21A-28H, Antelope-Sanish, t2/17; cum 290K 11/18;
31923, conf, PetroGulf, Three Tribes 151-94-19H, 
31922, conf, PetroGulf, Three Tribes 151-94-18HTF, 
31921, conf, PetroGulf, Three Tribes 151-94-8HTF, 
31920, conf, PetroGulf, Three Tribes 151-94-7H,
31890, SI/NC, Bruin/HRC, Fort Berthold 152-94-22D-15-11H,
31889, SI/NC, Bruin/HRC, Fort Berthold 152-94-22D-15-10H,
31784, 2,155, WPX, Lucy Evans 29-3HUL, Antelope-Sanish, t6/17; cum 296K 11/18;
31783, 1,154, WPX, Lucy Evans 29-32HF, Antelope-Sanish, t6/17; cum 213K 11/18;
**************31778, conf, Bruin/HRC, Fort Berthold 151-94-26B-35-10H,
**************31777, conf, Bruin/HRC, Fort Berthold 151-94-26B-35-11H, Antelope-Sanish,
**************31776, conf, Bruin/HRC, Fort Berthold 151-94-26B-35-12H, Antelope-Sanish,
**************31775, conf, Bruin/HRC, Fort Berthold 151-94-27A-34-15H, Antelope-Sanish,
**************31774, 5,058, Bruin/HRC, Fort Berthold 151-94-27A-34-16H, Antelope-Sanish, t7/18; cum 294K 11/18;
31743, conf, EOG, Hawkeye 169-1324H,
31742, conf, EOG, Hawkeye 158-1324H,
31741, conf, EOG, Hawkeye 158-1324H,
31740, PNC, EOG, Hawkeye 19-1324H,
31739, PNC, EOG,
31738, PNC, EOG,
31737, PNC, EOG,
31736, PNC, EOG,
31731, 1,154, Enerplus, Flyer 152-94-34DH TF, Antelope-Sanish, t5/17; cum 194K 11/18;
31665, 814, Hess, AN-Evenson-152-95-0310H-10, Sanish pool, t3/16; cum 53K 5/16;
31664, 1,066, Hess, AN-Evenson-152-95-0310H-11, t3/16; cum 75K 5/15;
31663, 968, Hess, AN-Evenson-152-95-3010H-12, t2/16; cum 63K 5/16;
31662, 1,489, Hess, AN-Evenson-152-05-0310H-13, t2/16; cum 136K 8/16;
31623, 97 (no typo), BR, Craterhawk 8-14 UTFH-ULW, Antelope-Sanish, t1/18; 249K 11/18;
31453, PNC, EOG, Riverview 11-3229H,
31452, PNC, EOG, Riverview 10-3229H,
31451, PNC, EOG, Riverview 9-3229H,
31450, conf, EOG, Riverview 113-3229H,
31449, conf, EOG, Riverview 111-3229H,
31448, conf, EOG, Riverview 112-3229H,
31447, conf, EOG, Riverview 109-3229H,
31446, conf, EOG, Riverview 110-3229H,
31445, PNC, EOG, Riverview 107-3229H,
31444, PNC, EOG, Riverview 108-3229H,
31424, 1,006, Hess, AN-Evenson-152-95-0310H-14, t2/16; cum 59K 5/16;
31423, 1,195, Hess, AN-Evenson-152-95-0310H-1, t2/16; cum 89K 5/16;
31313, 2,204, Hess, AN-Brenna-153-94-3130H-2,
31312, 1,091, Hess, AN-Brenna-153-94-3130H-3,
31311, 1,903, Hess, AN-Brenna-153-94-3130H-4,
31310, 1,179, Hess, AN-Brenna-LW-153-94-3130H-1, Antelope-Sanish, t9/16; cum 308K 11/18;
31061, 2,942, MRO, Juanita USA 13-35H, 40 stages, 12 million lbs, t7/16; cum 115K 8/16;
31060, 3,473, MRO, Heather USA 13-35TFH, 44 stages, 12 million lbs, t5/16; cum 123K 8/16;
31059, SI/NC --> TA, MRL, Ethel USA 14-35TFH-2B,
31058, 3,661, MRO, Clarks Creek USA 14-35H, t5/16; cum 267K 6/17;
31057, 3,490, MRO, Charmaine USA 14-35TFH, t6/16; cum 249K 2/17;
30805, conf, MRO, Cavanaugh USA 12-35TFH-2B,
30803, conf, MRO, Robin USA 13-35TFH-2B,
30802, conf, MRO, St Pierre USA12-35TFH,
30801, conf, MRO, Black USA 12-35H,
30800, conf, MRO, Winnie USA 12-35TFH,
30546, 661, Bruin/HRC, Fort Berthold 151-94-26A-35-9H, well file available,
30545, 2,070, Bruin/HRC, Fort Berthold 151-94-26A-35-8H, well file available,
30544, 1,129, HRC, Fort Berthold 151-94-26A-35-7H, well file available,
30543, 2,837, Bruin/Bruin/HRC, Fort Berthold 151-94-26A-35-6H, well file available,
30542, 2.010, Bruin/HRC, Fort Berthold 151-94-26A-35-5H, well file available,
30541, 4,871, Bruin/HRC, Fort Berthold 151-94-26A-35-4H, Antelope-Sanish, t6/18; cum 350K 11/18;
30488, 4,144, MRO, Veronica USA 14-22TFH, Antelope-Sanish, t12/17; cum 264K 11/18;

2014 
30286, 1,974, EOG, Riverview 102-32H, 23 stages, 13 million lbs, t6/15; cum 475K 2/17; 320-acre spacing; short lateral
30242, 2,324, HRC, Fort Berthold 152-93-7C-6-12H, Antelope-Sanish, t12/16; cum 285K 11/18;
30241, 2,614, Bruin/HRC, For Berthold 152-93-7C-6-13H, Antelope-Sanish, t12/16; cum 273K 11/18;
30167, 423, Hess, AN-Prosser-LE-152-95-1102H-1, t1/16; cum 24K 2/17; off-line much of the early months;
30166, 1,134, Hess, AN-Prosser-152-95-1102H-9, t12/15; cum 113K 5/16;
30165, 1,376, Hess, AN-Prosser-152-95-1102H-8, t12/15; cum 127K 5/16;
30164, 1,113, Hess, An-Prosser-152-95-1102H-7, t12/15 cum 65K 5/16;
30163, 989, Hess, AN-Prosser-152-95-1102H-6, t11/15; cum 40K 5/16;
30162, 1,229, Hess, AN-Prosser-152-95-1102H-5, t11/15; cum 197K 2/17; off-line much of the early months;
30135, 4,881, MRO, Deane USA 24-22H, Antelope-Sanish, t12/17; cum 277K 11/18;
30134, 3,503, MRO, Rough Coulee USA 24-22TFH, Antelope-Sanish, t1/18; cum 233K 11/18;
30133, 4,855, MRO, Veronica USA 14-22TFH/TAT USA 14-22H, Antelpe-Sanish, t12/17; cum 234K 11/18;
30132, PNC, MRO,
30131, 2.420, MRO, Blue Creek USA 24-22TFH-2B, Antelope-Sanish, t1/18; cum 144K 11/18;
29931, 1,636, Hess, AN-Lone Tree-152-95-1207H-1, Antelope-Sanish, t12/17; cum 166K 11/18;
28930, 1,132, CLR,Quale Federal 2-1H, 30 stages, 3.5 million lbs, t2/15; cum 244K 8/16;
28523, 1,572, Petrogulf, Three Tribes 151-94-4HTF, t12/14; cum 251K 5/16;
28522, 2,106, Petrogulf, Three Tribes 151-94-3H, t12/14 cum 211K 2/17; went inactive 4/16;
28395, 969, Hess, AN-Evenson-LW-152-95-1003H-2, a Sanish well, t1/15; cum 103K 5/16;
28375, 974, Hess, AN-Brenna-LE-153-94-3129H-2, t5/14; cum 102K 5/16;
28374, 913, Hess, AN-Brenna-LE-153-94-3130H-1, t3/15; cum 113K 5/16;
28373, 259, Hess, AN-Brenna-LE-153-94-3129H-2,  t9/15; cum 5K 10/15; inactive after 21 days; back on status as of 3/16; cum 26K 5/16;
28372, 1,254, Hess, AN-Brenna-153-94-3130H-7, t3/15; cum 119K 5/16;
28371, 941, Hess, AN-Brenna-153-94-3130H-6, t9/15; cum 92K 5/16;
28370, 1,191, Hess, AN-Brenna-153-94-3130H-5, t3/15; cum 152K 5/16;
28335, 1,197, CLR, Salers Federal 6-27H1, t11/15; cum 187K 5/16;
28334, 1,297, CLR, Salers Federal 7-27H, t11/15; cum 187K 5/16;
28330, 1,716, CLR, Salers Federal 3-27H, 50 stages; 19 million lbs; 14 days spud to TD, t10/14; cum 383K 8/16;
28257, 2,059, XTO, Nelson Federal 41X-5D, t10/15; cum 97K 5/16;
28256, 1,804, XTO, Nelson Federal 41X-5H, t10/15; cum 65K 5/16;
28255, 2,513, XTO, Nelson Federal 41X-5C, t10/15; cum 130K 8/16;
28185, 2,712, XTO, Nelson Federal 21X-5E, t11/15; cum 77K 5/16;
28184, 2,171, XTO, Nelson Federal 21X-5A, t11/15; cum 103K 5/16;
28183, 2,459, XTO, Nelson Federal 21X-5B, t11/15; cum 128K 5/16;
28103, 2,625, WPX, Lucy Evans 29-32HX, a Sanish well, Three Forks B1, 35 stages; 5.6 million lbs, t11/14; cum 323K 11/18;
28102, 2,917, WPX, Lucy Evans 29-32HB, a Sanish well, t11/14; cum 275K 5/16;
28101, conf, WPX, Lucy Evans 29-32HW,
28100, 673, WPX, Lucy Evans 29-32HA, a Sanish well, t10/14; cum 249K 5/16;
28072, 1,336, Hess, AN-Evenson-LW-152-95-1003H-1, 4 sections, t1/15; cum 138K 5/16;
27798, 1,032, Hess, AN-Evenson-152-95-1003H-9, t1/15; cum 125K 5/16;
27797, 1,044, Hess, AN-Evenson-152-95-1003H-8, t12/14; cum 107K 5/16;
27796, 949, Hess, AN-Evenson-152-95-1003H-7, t1/15; cum 78K 5/16;
27795, 910, Hess, AN-Evenson-152-95-1003H-6, t1/15; cum 105K 5/16;
27728, 1,458, WPX, Ruby 31-30HX, a Sanish well, t8/14; cum 217K 5/16;
27591, 2,079, ERF, Monarch 152-94-32D-29H, t12/14; cum 259K 5/16;
27590, 1,608, ERF, Viceroy 152-94-32D-29H TF, t12/14; cum 355K 5/16;
27589, 171, ERF, Swallow Tail 152-94-32D-29H, t11/14; cum 320K 5/16;
27588, IA/1,867, ERF, Snapper 152-94-33C-28H, t11/14; cum 271K 5/16;
27587, 2,188, ERF, Softshell 152-94-33C-28H TF, t11/14 cum 733K 11/18; another update here;



2013 (list is complete)
26990, 3,102, Enerplus, Hognose 152-94-18B-19H-TF, a Sanish well, t4/14; cum 539K 11/18;
26989, 2,357, Enerplus, Rattle 152-94-18B-19H, t6/15; cum 267K 5/16;
26988, 2,842, Enerplus, Bull 152-94-18B-19H-TF, t6/15; cum 323K 5/16;
26798, 2,295, HRC, Fort Berthold 152-94-24D-13-5H, a Sanish well, t7/14; cum 231K 5/16;
26797, 2,236, HRC, Fort Berthold 152-94-24D-13-6H, a Sanish well, t8/14; cum 255K 5/16;
26796, 2,131, HRC, Fort Berthold 152-94-24D-13-7H, a Sanish well, t8/14; cum 104K 5/16;
26737, 3,374, ERF, Ribbon 152-94-18B-19H, a Sanish well, 42 stages; 10 million lbs, 13 days drilling time, t4/14; cum 624K 11/18;
26633, 481, CLR, Mack 8-2H, a Sanish well, 1 section, middle Bakken, 15 stages, 1.7 million lbs, t8/14; cum 60K 5/16;
26632, 202, CLR, Mack 9-2H2, a Sanish well, 1 section, Three Forks B2, 25 stages, 6.2 million lbs; less than 2 days to drill the lateral; target, second bench of the Devonian, Three Forks, on the permit, Three Forks B2; t8/14; cum 58K 5/16;
26631, 289, CLR, Mack 10-2H3, a Sanish well, 1 section, Three Forks B3, 15 stages; 2.9 million lbs; less than 3 days to drill the horizontal; 6 days from spud to curve; 3rd bench of the Devonian, Three Forks, t8/14; cum 18K 5/16;
26630, 630, CLR, Mack11-2H1, 1 section, Three Forks B1, 15 stages 2.9 million lbs; t8/14; cum 355K 5/16;
26629, 516, CLR, Mack 12-2H2, 1 section, t9/14; cum 66K 5/16;
26627, 283, CLR, Mack 13-2H3, a Sanish well, t10/14; cum 34K 5/16;
25949, 1,367, Petrogulf Corporation, Sandstrom 151-94-2HTF, a Sanish well, t12/13; cum 525K 11/18;
25948, 2,088, Petrogulf Corporation, Sandstrom 151-94-1H, a Sanish well, t12/13; cum 315K 5/16;
25815, 1,351, CLR, Salers 2-27H, a Sanish well, t6/14; cum 395K 5/16;
25814, 1,256, CLR, Salers 1-27H, a Sanish well, t5/14; cum 352K 5/16;
25701, A, Hess, AN-Evenson 152-95-0310H-2, no IP, s8/13; cum 134K 2/17;
25700, 1,263, Hess, AN-Evenson 152-95-0310H-3, t5/14; cum 206K 5/16;
25699, 1,253, Hess, AN-Evenson 152-95-0310H-4, t5/14; cum 167K 5/16;
25698, 1,056, Hess, AN-Evenson 152-95-0310H-5, t6/14; cum 94K 5/16;
25526, 2,000, HRC, Fort Berthold 152-94-11B-14-7H, t3/14; cum 195K 5/16;
25525, 2,510, HRC, Fort Berthold 152-94-11B-14-6H, t3/14; cum 239K 5/16;
25524, 2,584, HRC, Fort Berthold 152-94-11B-14-5H, t3/14; cum 493K 11/18;
25494, 2,265, HRC, Fort Berthold 152-94-15B-22-4H, t10/13; cum 156K 3/15;
25400, 2,443, HRC, Fort Berthold 152-94-13A-24-3H, t11/13; cum 161K 3/15;
25399, 2,271, HRC, Fort Berthodl 152-94-13A-24-4H, t11/13; cum 200K 3/15;
25370, 1,292, HRC, Fort Berthold 152-94-13B-24-2H, Antelope-Sanish, t10/17; cum 239K 11/18;
25063, 1.010, Hess, AN-Prosser-152-95-0211H-2, t12/13; cum 127K 3/15;
25062, 1,400, Hess, AN-Prosser-152-95-0211H-3, t12/13; cum 157K 3/15;
25061, 1,432, Hess, AN-Prosser-152-95-0211H-4, t12/13; cum 264K 2/17;
25060, 599, Hess, AN-Mogen Trust-153-94-3229H-1, t11/13; cum 174K 3/15;
24815, 1,112, CLR, Rollefstad Federal 11-3H-1, t3/14; cum 135K 3/15;
24814, A, CLR, Rollefstad Federal 12-3H-3, s5/131; no IP, cum 97K 5/16;
24813, 773, CLR, Rollefstad Federal 13-3H, t3/14; cum 129K 3/15;
24812, A, CLR, Rollefstad Federal14-3H-2, s5/13; no IP, cum 136K 5/16;
24802, 725, CLR, Rollefstad Federal 10-3H-2, t3/14; cum 71K 3/15;
24801, A, CLR, Rollefstad Federal 9-3H, no IP, cum 237K 2/17;
24800, A, CLR, Rollefstad Federal 8-3H-3, no IP, cum 45K 3/15;
24799, A, CLR, Rollefstad Federal 7-3H-1, no IP, cum 173K 5/16;
24739, 2,397, HRC, huge well, t10/13; cum 254K 10/15;
24738, 2,171, HRC, t10/13; cum 274K 11/18;
24737, 2,224, HRC, t10/13; cum 275K 11/18;
24731, 2,171, Bruin/HRC, t10/13; cum 582K 11/18;
24724, PNC CLR, Rollefstad Federal 4-3H-2,
24723, PNC, CLR, Rollefstad Federal 5-3H-3,
24722, PNC, CLR, Rollefstad Federal 6-3H-2,

2012
24501, PNC, Petro-Hunt,
24500, PNC, Petro-Hunt,
24499, PNC, Petro-Hunt,
24359, 842, CLR, Mack 7-2H, t8/13; cum 132K 11/18;
24358, 206, CLR,Mack 6-2H, t8/13; cum 130K 11/18;
24337, 2,519, EOG, Hawkeye 3-2413H, t5/13; cum 754K 11/18;
23573, 1.065, Hess, t5/13; cum 286K 11/18;
23572, 934, Hess, t5/13; cum 171K 11/18;
23571, 1,290, Hess, t51/3; cum 186K 2/16;
23555, 2,018, HRC, t6/13; cum 183K 2/16;
23554, 2,909, HRC, t8/13; cum 138K 10/14;
23550, 965, HRC, t1/13; cum 116K 10/14;
23484, PNC, WPX, Ruby 31-20HY,
23483, 1,471, WPX, Ruby 31-30HB, t1/13; cum 387K 11/18;
23482, 1,503, WPX, Ruby 31-30HW, t8/14; cum 247K 11/18;
23481, 1,399, WPX, Ruby 31-30H1, t8/14; cum 71K 10/14;
23287, 844, Hess, AN-Bohmbach 153-94-2734H-2, t4/13; cum 96K 10/14;
23177, 648, ERF, Coyote 151=94133DH TF, t1/13; cum 95K 10/14;
23148, PNC, Hess, AN-Mogen Trust 153-94-3239H-1PNC,
22708, 1,776, HRC, Fort Berthold 151-94-26B-35-2H,t4/14; cum 241K 5/16;
22707, 1,959, HRC, Fort Berthold151-94-26B-34-3H, t4/14; cum 357K 5/16;
22706, PNC, Petro-Hunt, Fort Berthold 151-94-26A-35-5H,
22705, PNC, Petro-Hunt, Fort Berthold151-94-26A-35-4H,
22505, 1,437, EOG, Clarks Creek 100-0805H, t6/12 cum 347K 2/17;

2011
21891, PNC, WPX, Bird 30-31HC,
21387, 2,502, White Butte Oil Operations, LLC/Slawson, Panzer 4-20MLH, t4/14; cum 146K 11/18;
21386, 1,905, White Butte Oil Operations, LLC/Slawson, Panzer 2-20MLH, t4/14; cum 237K 11/18;
21385, 2,221, White Butte Oil Operations, LLC/Slawson, Panzer 1-20MLH, t4/15; cum 166K 11/18;
21152, 901, CLR, Mack 4-2H, t10/11; cum 220K 11/18;
21151, 446, CLR, Mack 5-2H, t11/12; cum 159K 11/18;
21104, 228, WPX, Delores Sand 29-32H, t4/12; cum 410K 11/18;
20916, 2,361, HRC, Fort Berthold 151-94-34C-27-2H, t1/14; cum 320K 11/18;
20783, 1,388, ERF, Miles 151-94-28D-21H TF, t9/11; cum 387K 11/18;
20674, 843, CLR, Rollefstad 3-3H, t6/12; cum 416K 11/18;
20623, 571, CLR, Mack 3-2H, t10/11; cum 186K 11/18;
20602, 670, EOG, Clarks Creek 15-0805H, t7/12; cum 527K 11/18;
20567, 530, HRC, Fort Berthold 152-94-22D-15-2H, t9/11; cum 353K 11/18;
20550, 1,478, EOG, Clarks Creek10-0805H, t6/12; cum 422K 11/18;
20384, PNC, ERF, Fool Bear 16-12H,
20376, 988, ERF,Fool Bear 23-34H, Antelope, t5/17; cum 188K 11/18;
20328, 1,647, Bruin/HRC, Fort Berthold 151-94-26B-35-1H, t3/12; cum 546K 11/18;
20307, 1,328, EOG, Clarks Creek 103-17H, t11/11; cum 152K 11/18;

Prior to 2011
19887, 714, AN-Dinwoodie-153-94-2833H-1, Antelope, Sanish, t7/11; 248K 11/18; off-line of course as of 8/17; frack data never provided; permitted as a double lateral, the middle Bakken lateral 2 and a Three Forks lateral 1; only the Three Forls was drilled; the lateral was drilled 100% within the upper portion of the Three Forks with greater than 70% of the well bore to be completed within the ideal preferred target porosity;
 
Original Post: The Antelope Oil Field

This is duplicated, cut and paste material from an earlier post. This post will soon "go away" and the post will be linked in the sidebar at the right as the Antelope Field.

Antelope Field is an irregularly-shaped rectangular field, almost entirely within the reservation, on the east end of the northeast McKenzie County sweet spot in the Bakken. It is about two townships in size. It is of interest due to the fact that EOG plans to place 6 wells on a 320-acre spacing unit in this field.

It is interesting how things work out: in this immediate area, there are only three sections with 320-acre spacing: section 32-152-94; section 17-151-94; and section 20-15-94. When you expand the NDIC GIS map, you can find a few more such spacing units in: section 16-152-94; section 24-151-92; section 20-152-93, and you have to expand to almost the entire map to see additional such units: they are few and far between. It looks like most of them are inside the reservation. This puts things into perspective.

Case 19211, W/2, 17-151-94, Antelope-Sanish, EOG, 6 wells on a 320-acre spacing unit. If you were to stand in the middle of section 17, and take out your binoculars, and scare the antelope away, you would see, 1.5 miles in all directions --

to the northwest:
  • 19790, 1,318, EOG, Clarks Creek 3-0805H, Antelope, a Sanish Pool well; t6/11; cum 441K 11/18;
  • 20307, 1,328, EOG, Clarks Creek 103-17H, Antelope, a Sanish Pool well; 320-acre spacing; t11/11; cum 152K 11/18;
  • 20550, 1,478, EOG, Clarks Creek 10-0805H, Antelope, a Sanish Pool well; t6/12; cum 422K 11/18;
  • 20602, 670, EOG, Clarks Creek 3-0805H 15-0805H, Antelope, t7/12; cum 527K 11/18;
  • 20886, 317, EOG, Clarks Creek 101-1819H, Clarks Creek, a Bakken Pool well; 4-section spacing; t4/12; cum 401K 11/18;
  • 20887, 1,455, EOG, Clarks Creek 13-1806H, Clarks Creek, a Bakken Pool well; 4-section spacing; t3/12; cum 340K 11/18; huge jump in 8/18; see this post;
  • 20888, 3,415, EOG, Clarks Creek 14-1819H, Clarks Creek, a Bakken Pool well; 4-section spacing; t6/11; cum 292K 11/18;
  • 20890, 600, EOG, Clarks Creek 11-0706H, Clarks Creek, a Bakken Pool well; 4-section spacing; t3/12; cum 348K 11/18; huge jump in production, 9/18;
  • 20891, 603, EOG, Clarks Creek 12-0719H, Clarks Creek, a Bakken Pool; 4-section spacing; t8/11; cum 304K 11/18;
  • 20892, 1,352, EOG, Clarks Creek 16-0706H, Clarks Creek, a Bakken Pool well; 4-section spacing; t3/12; cum 334K 11/18;
  • 22505, 1,437, EOG, Clarks Creek 100-0805H, Antelope, a Sanish Pool well; t6/12; cum 386K 11/18;
    to the northeast:
    • 19790, 1,318, EOG, Clarks Creek 3-0805H, Antelope, Sanish, t6/1l; cum 441K 11/18; long lateral; 2-section spacing;
    • 20602, see above, EOG, Clarks Creek 15-0805H, Antelope,
    to the southwest: (see Panzer wells here)
    to the southeast:
    • 19693, 722, Peak/ERF, Danks 17-44H, Sanish, Antelope; t7/1l; cum 233K 11/18; 320-acre spacing; 10,874 feet; 
    ***************************
    After posting the original note, a reader sent this, a phenomenal well about 3 miles southeast of section 17 in which EOG will be placing 6 wells on a 320-acre spacing unit:
    • 20328, 1,647, Petro-Hunt, Fort Berthold 151-94-26B-35-1H, F,  t3/12; cum 546K 11/18; updates above; jump in production in 11/18;

    Random Update on Slawson's Upper Bakken Shale Drilling Program; EOG's Plans for 6 Wells On A 320-Acre Spacing Unit

    A little closer look at two interesting cases in the November NDIC dockets, cases 19087 and 19211:

    Case 19087, 2,14, and 22-146-104, Squaw Gap, Slawson, 5 wells on each of those three 640-acre spacing units (sections 2, 14, and 22). This is an interesting little field. I blogged about it earlier this year with an update a month later:
    June 16, 2012: Slawson Drilling the Upper Bakken; Slawson says it is drilling the "upper" Bakken, very interested in the area along the Montana-North Dakota border.
    There are several wells in this field, but they were all drilled several years ago, some of them were drilled many years ago. The earlier Bakken wells in this field are all very short horizontals, shorter than the conventional "short" laterals, and although they took a long time to reach 100,000 bbls, they are turning out to be nice wells, based on cumulative production. 

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

    Case 19211, W/2, 17-151-94, Antelope-Sanish, EOG, 6 wells on a 320-acre spacing unit. If you were to stand in the middle of section 17, and take out your binoculars, and scare the antelope away, you would see, 1.5 miles in all directions,
    to the northwest:
    • 20891, 1,167, EOG, Clarks Creek 12-0719H, Clarks Creek, Bakken, F, t8/12; cum 55K 9/12; 4-section spacing; long lateral;
    • 20892, 1,352, EOG, Clarks Creek 16-0706H, Clarks Creek, Bakken, F, t3/12; cum 69K 9/12; 4-section spacing; long lateral;
    • 20307, 1,328, EOG, Clarks Creek 103-17H, Clarks Creek, Sanish, AL, t11/11; cum 58K 9/12; 320-acre spacing;
    • 20550, conf, EOG, Clarks Creek 10-0805H, Antelope,
    • 22505, conf, EOG, Clarks Creek 100-0805H, Antelope,
    to the northeast:
    • 19790, 1,318, EOG, Clarks Creek 3-0805H, Antelope, Sanish, t6/1l; cum 176K 9/12; long lateral; 2-section spacing;
    • 20602, conf, EOG, Clarks Creek 15-0805H, Antelope,
    to the southwest:
    • 21385, conf, Slawson, Panzer 1-20H, Antelope,
    • 21387, conf, Slawson, Panzer 4-20TFH, Antelope,
    to the southeast:
    • 19693, 722, Peak/ERF, Danks 17-44H, Sanish, Antelope; F; t7/1l; cum 93K 9/12; 320-acre spacing; 10,874 feet;
    • 19694, 723, Peak/ERF, Danks 20-41H, Sanish, Antelope, F; t7/11; cum 95K 9/12; 320-acre spacing;  10,949 feet;

    On Tap For Monday: Wells Off Confidential List; Two Nice BEXP Wells; Jack Welch on CNBC

    Jack Welch on CNBC this a.m., couldn't say enough about the Bakken. He has a company making steel buildings; can't get them built fast enough for the Dakotas. He mentioned in passing a huge chemical specialty distribution center (or something along that line) in Minot. Andrew Sorkin asked his predictable question. Also at CNBC on-line: natural gas could be bigger than the internet (both were invented by Al Gore). Video.


    RBN Energy: primer on crude oil spot pricing.

    Saudi Arabia is raising prices. This will be tough on France, Spain, and Greece. 

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

    From the series of photographs from the Williston area, October, 2012, sent in by a reader:



    ******************
    Active rigs: 188 (steady) -- Monday morning

    Well coming off confidential list on Monday:

    Note the CLR Midnight Run well below.   The Liberty Resources Fritz well is classified as a wildcat, but it certainly isn't a wildcat in the traditional sense: it is located in a section not yet designated as any oil field, but it is immediately between two nice fields in McKenzie County: the Sather Lake oil field to the south and the Pronghorn oil field to the north. It should be a good well.

    ******************
    11/3
    20521, 1,412, XTO, George Federal 21X-19B, Lost Bridge, t7/12; cum 34k 9/12;
    21217, 686, WPX/Helis, Linseth 13-12HW, Squaw Creek, Three Forks; 10 stages; 800K lbs; 21,000 feet to the Birdbear vertically; and 11,000 feet to the Three Forks; interesting file report; trip gases exceeded 8,000 units; t9/12; cum 7K 9/12; NB: the NDIC scout ticket has the IP at 6,867 bbls (wrong);
    22186, 400, Hess, EN-Horst 154-93-0310H-3, Robinson Lake, t8/12; cum 21K 9/12;
    22252, drl, Oasis, Delta 6093 34-15H, Gros Ventre,
    22324, 223, Oasis, Celeste 6092 43-34H, Cottonwood, t6/12; cum 20K 9/12;
    22339, 573, Whiting, Knife River State 21-16TFH, Sanish, t5/12; cum 25K 9/12;
    22381, drl, BEXP, Vachal 3-34 4TFH, Alger,
    22467, drl, KOG, Skunk Creek 12-7-8-9H, Heart Butte,

    11/4
    21421, 648, Liberty Resources, Fritz 15-101-32-29-1H, Wildcat, t5/12; cum 46K 9/12;
    21958, 1.044, Whiting, Iver & Minnie 21-14PH, Zenith, t5/12; cum 32K 9/12;
    22022, 3,382, BEXP, Edna 11-2 1H, Camp, t7/12; cum 35K 9/12;
    22477, 881, Denbury Onshore, Grimestad 34-33NEH, Charlson, t7/12; cum 25K 9/12;
    22579, 446, CLR, Marcy 2-24H, Oliver, t8/12; cum 16K 9/12;

    11/5
    22604, 170, Hunt, Halliday 2-40-42H, Werner, t9/12; cum 9K 9/12;
    22617, drl, CLR, Sorenson 1-21AH, Alkali Creek,
    22619, drl, CLR, Sorenson 2-21AH, Alkali Creek,
    22675, drl, BR, Midnight Run 11-1TFH, Union Center,
    22732, 350, Crescent Point, CPEUSC Fairholm 33-34-164N-100W, West Ambrose, t7/12; cum 6K 9/1;2
    22454, 3,634, BEXP, Marcia 3-10 1H, Last Chance, t8/12; cum 40K 9/12;

    With regard to CLR's Sorenson wells (above), it looks like CLR had permits for a 4-well pad to the west in this section which were canceled and the four permits were simply "moved" a few feet to the east, in the same section. The "A" in the "AH" is the change in the name of the wells. For newbies, this is another example of some permits being canceled, only to be re-permitted in a slightly different location. In general, permits in the Bakken that are canceled do not concern me. (I guess the only problem is they skew the total number of permits in a given year when tracking statistics.)