Marathon's Mylo Monitoring Wells -- Tri-Frac? a Trifecta?

Updates

February 15, 2016:

• 18491, SI/NC, MRO, Mylo Monitor 1,
• 18492, SI/NC, MRO, Mylo Monitor 2,
• 18511, 39, MRO, Mrymidon SWD 1 -- poor production; converted to a salt water disposal well, 10/9/2015; 

Original Post

 

I've placed the following on my "wells to watch" page:

Marathon, section 11, T151N-93W (Reunion Bay oil field, southeast of New Town)

18491, Mylo Monitoring 1, comes off confidential list Jul 2010
18492, Mylo Monitoring 2, on confidential list; no date (not completed?)
18511, Mylo Wolding 14-11, rig on site, comes off confidential list Aug 2010

Hopefully someone with some information on these three wells will share. These three wells are aligned, offset 500 feet from each other: #18511 (the one being drilled Feb, 2010) sits in the middle with #18491 500 feet to the east, and #18492 500 feet to the west.

My hunch: testing a relatively new concept called "tri-frac" -- fracturing three wells simultaneously -- not only has this been done before (including by Enerplus) but also by Marathon!

Big Bend Update

Updates

March 16, 2014: four rigs actively drilling in the Big Bend.

June 8, 2012: IPs and production updated this date going back to permits issued in 2009. Some observations: 

• there are only a handful of wells that are even two years old so far, and this was one of the first fields to be developed in the Bakken
• look at the cumulative production of these wells; huge; they will reach payback within two years or so; and then keep producing for another 30 years
• look at how much work yet needs to be done; most of the permits issued in 2011 are still on confidential list
• when you look at Big Bend on the NDIC GIS map server, note that the field -- this most productive field -- averages only one (1) per spacing unit. This field will eventually see a minimum of four, maybe six, maybe eights wells per spacing unit

April 10, 2010:  Slawson has a rig on site, 18792, Jericho 2-5H-TF  -- on same pad as two producing wells, Jericho 1-5H and Coyote 1-32H.  Slawson has another rig on site for 18312, Whirlwind 1-31H.

March 9, 2010: Slawson and NOG will drill Jericho 2-5H-TF below the Jericho 1-5H to see if the two formations are separate.

Permits

2016


 
2015 (list is complete)
32408, conf, Slawson,
32407, conf, Slawson,
32400, conf, Slawson,
32399,
32398,
32278,
32277,
32276,
32275,
32274,
32273,
32272,
32271,
32118, conf, Slawson,
32217, conf, Slawson,
32116,
32115,
32114,
32113,
32112,
32111,
31985, conf, Slawson,
31844, conf, Slawson,
31820, conf, Slawson,
31819,
31563, conf, Slawson,
31562,
31561,
31478, conf, Slawson,
31476, conf, Slawson,
31473,
31442,
31441,
31440,
31439,
31438,
31437,
31435,
31433,
31432,
31431,
31394, conf, Slawson,
31393,
31295,
31294,
31293,
31292,
31291,
31290,
31289,
31279,
31278,
31277,
31276,
31275,
31274,
31273,
31272,
31271,
31270,
31269, conf, Slawson,
30820,
30819,
30765,
30764,
30763,
30762,
30761,
30733,
30732,
30731,
30730, drl, Slawson,
30614, PNC, Slawson,
30540, PNC, Slawson,
30539, PNC, Slawson,
30538, PNC, Slawson,
30537, PNC, Slawson,
30536, PNC, Slawson,
30417, PNC, Slawson,
30416, PNC, Slawson,
30415, PNC, Slawson,
30414, SI/NC, Slawson,
30413, SI/NC, Slawson,
30412, SI/NC, Slawson,

Issued in 2014 (list is complete)
30319, 947, Slawson,
30305, PNC, Slawson,
30304, PNC, Slawson,
30303, PNC, Slawson,
30302, PNC, Slawson,
30263, conf, Slawson,
30236, PNC, Slawson,
30235, conf, Slawson,
30179, conf, Slawson,
30178, conf, Slawson,
30177, PNC, Slawson,
30074, 981, Slawson,
30000, PNC, Slawson,
29999, conf, Slawson,
29998, PNC, Slawson,
29997, conf, Slawson,
29996, 401, Slawson,
29995, PNC, Slawson,
29983, 481, Slawson,
29959, 1,590, Slawson,
29958, PNC, Slawson,
29896, 1,226, Slawson,
29895, PNC, Slawson,
29894, 1,146, Slawson,
29859, 15 (no typo), Slawson,
29776, conf, Slawson,
29775, PNC, Slawson,
29774, conf, Slawson,
29773, SI/NC, Slawson,
29772, SI/NC, Slawson,
29621, conf, Slawson,
29620, conf, Slawson,
29619, PNC, Slawson,
29618,
29617,
29616,
29615,
29609,
29608,
29575, PNC, Slawson,
29574, PNC, Slawson,
29573, PNC, Slawson,
29472, 2,002, Slawson,
29471, 1,423, Slawson,
29435, 1,288, Slawson,
29305,
29304,
29294,
29293,
29292,
29286,
29285,
29284,
29283,
29151,
29144,
28934,
28925,
28923,
28922,
28840,
28839,
28838,
28837,
28777,
28668, 842, Slawson,
28662,
28661,
28621,
28620,
28479,
28478,
28451,
28450,
28220,
28219,
28208,
28114,
28113,
28004,
28003, 301, Slawson,
27887, 845, Slawson, Mustang 1 SLH,
27877, 415, Slawson, Cruiser 7-16-9TFH,
27876, 305, Slawson, Cruiser 6-16-9TFH, 
27675, 464, Slawson, Mole 3-20H,
27619, 519, Slawson,Whirlwind 6-31TFH,
27618, 271, Slawson, Whirlwind 3-31H,
27594, 352, Slawson, Challenger Federal 6-29-32TFH,
27593, 519, Slawson, Challenger Federal 3-29-32H,
27592, 780, Slawson, Challenger Federal 5-29-32TFH,
27499, 666, Slawson, Alamo 8-19-18TF2H,
27493, 336, Slawson, Tempest 3-14H,

Issued in 2013 (list complete)
27337, 205, Slawson, Hunter 8-8-17TF2H,
27312, 553, Slawson, Nightmaker 4-8-17TFH,
27274, 346, Slawson, Cruiser 3-16-9H,
26892, 905, Slawson, Alamo 5-19-18TFH,
26891, 847, Slawson, Alamo 4-19-18TFH,
26604, 434, Slawson, MacCougar 3-30-19H,
26442, 665, Slawson, Bazooka 3-20H,
26441, 579, Slawson, Minx 3-29H,
25812, 165, Slawson, Jugard (Federal) 6-26-35TFH, t1/14; cum 4K 1/14;
25811, 928, Slawson, Jugard (Federal) 2-26-35h, t1/14; cum 17K 1/14;
25485, 1,635, MRO, Kari 11-13TFH, t11/13; cum 41K 1/14;
25050, 891, Slawson, Alamo 3-19-18H, t6/13; cum 121K 1/14;
25049, 737, Slawson, Alamo 6-19-18TFH, t6/13; cum 85K 1/14;
25027, 281, Slawson, Jericho 4-5H, t9/13; cum 38K 1/14;
25026, 447, Slawson, Coyote 3-32H, t7/13; cum 60K 1/14;
24921, 188, Slawson, Jeriyote 6-5-32TFH,
24920, 530, Slawson, Hunnter 6-8-17TFH,
24919, 660, Slawson, Jeriyote 7-5-32TFH,
24918, 279, Slawson, Hunter 7-8-17TFH,
24897, 325, Slawson, Jeriyote 5-32-5TFH, t7/13; cum 64K 1/14;
24896, 448, Slawson, Jeriyote 4-32-5TFH, t7/13; cum 52K 1/14;

Issued in 2012
24218, 997, Slawson, Mooka 4-29-20H, t6/13; cum 115K 1/14;
24217, 733, Slawson, Mooka 3-29-20TFH, t6/13; cum 114K 1/14;
24011, 1,092, MRO, Cummings 44-31TFH, t8/13; cum 57K 1/14;
23917, PNC, Slawson, Silencer 2-29H,
23891, 388, Slawson, MacCougar 4-30-19TFH,
23890, 1,002, Slawson, MacCougar 2-30-19H,
23889, 1,372, Slawson, MacCougar 5-30-19TFH,
23563, 1,398, MRO, Don 34-31TFH, t2/13; cum 93K 1/14;
23255, 1,092, Slawson, Sniper Federal 5-6-7TFH, t10/12; cum 144K 1/14;
22446, 1,319, MRO, Aisenbrey 21-25TFH, t8/12; cum 145K 114;
22910, 1,430, MRO, Pearl 41-13TFH, Big Bend, t10/12; cum 143K 1/14;
22911, 1,538, MRO, pearl 41-13H, Big Bend, t10/12; cum 129K 1/14;

Issued in 2011
20403, 1,391, Slawson, Jaguar 2-32H, t7/11; cum 305K 12/15;
20422, 684, Slawson, Howitzer 2-25H, t10/11; cum 168K 1/14;
20423, PNC, Slawson, Skybolt 2-24H,
20810, 669, Slawson, Mooka 2-29-20H, t6/13; cum 115K 1/14;
21112, 1,358, MRO, Aisenbrey 21-25H, s4/12; t7/12; cum 195K 1/14;
21121, 1,231, Slawson, Spyder 1-17H, t12/11; cum 95K 1/14;
21205, PNC,  Slawson, Spyder Web 3-17H,
21206, PNC, Slawson, Spyder Web 2-17H,
21426, 891, Slawson, Whirlwind 2-31H, t10/12; cum 104K 1/14;
21427, 1,502, Slawson, Sniper (Federal) 2-6-7H, Big Bend, t10/12; cum 195K 1/14;
21434, 929, Slawson, Spyder 2-17H, t12/11; cum 75K 1/14;
21435, 505, Slawson, Spyder 3-17H, t12/11; cum 103K 1/14;
21595, 1,351, Slawson, Jericho 3-5H, t9/12; cum 112K 1/14;
21596, 703, Slawson, Coyote 2-32H, t1/13; cum 88K 1/14;

Issued in 2010
18574, 1,427, Slawson, Mole 1-20H, t12/10; cum 161K 1/14;
18575, 1,007, Slawson, Hunter 1-8-17H, t6/11; cum 298K 1/14;
18589, 962, Slawson, Sniper Federal 1-6-7H, t5/10; cum 473K 12/15;
18590, 252, Slawson, Alamo 1-19-18H, t8/10; cum 233K 1/14;
18792, 368, Slawson, Jericho 2-5H-TF, t6/120; cum 95K 1/1/4;
18865, 1,026, Slawson, Silencer 1-29H, t12/10; cum 219K 1/14;
19241, 820, Slawson, Jaguar 1-32H, t12/10; cum 168K 1/14;
19958, 1,494, MRO, Rhoda 24-31H, t12/11; cum 217K 1/14;
19996, 1,148, Slawson, Alamo 2-19-18H, t6/11; cum 397K 12/15;
20203, 833, Slawson, Stallion 2-1-12H, t1/12; cum 269K 1/14;
20204, 743, Slawson, Zephyr 2-36H, t1/12; cum 136K 1/14;
20228, 1,204, Slawson, Wizard 2-35H, t6/11; cum 188K 1/14;
20229, 1,184, Slawson, Jughead Federal 2-26H, t6/11; cum 233K 12/15;

Issued in 2009
18153, 647, MRO, Brodahl 31-25H, t9/09; cum 279K 1/14;
18180, 2,561, Slawson, Stallion 1-1-12H, t2/10; cum 368K 1/14;
18274, 636, MRO, Wolding 41-24H, t2/10; cum 392K 1/14;
18287, 911, Slawson, Skybolt 1-24H, t1/10; cum 184K 1/14;
18312, 902, Slawson, Whirlwind 1-31H, t6/10; cum 222K 1/14;
18363, 981, Slawson, Howitzer 1-25H, t1/10; cum 217K 1/14;
18364, 1,526, Slawson, Zephyr 1-36H, t2/10; cum 246K 1/14;
18416, 849, Slawson, Wizard 1-35H, t3/10; cum 155K 1/14;
18514, 672, MRO, Howard USA 11-1H, t6/10; cum 408K 12/15;

Prior to 2009
17801, 750, Slawson, Jericho 1-5H, Big Bend, t3/09; cum 166K 12/15;
 

Original Post

The Big Bend field may be a small field, but it's an exciting field, especially for Slawson.

The field is only 32 sections, nestled inside a loop of the Missouri, and entirely inside the Fort Berthold Indian Reservation, on the north side of the  river. At the north end is New Town, a town that has an interesting history as any.

The Big Bend is a favorite of mine. My dad loved to take me to New Town every time I came home. It was a beautiful drive, especially at sunset. I will always have good memories. Maybe more memories later.

But for now, here's what is going on in Big Bend: four producing wells, 10 wells on the confidential list, and one well being drilled.

I consider it a "Slawson field, but Marathon has a couple of wells in this field, but that's about it.

The first thing one notices when visiting this small field is that the producers seem to be pairing up wells, offsetting two wells 100 feet from each other.

"Slawson Snake Eyes"

Slawson well pairings (IPs in red):

17864, Jughead 1-35H, 1,255 (was Thompson 1-35H with Windsor), t6/10; cum 193K 11/12;
18416, Wizard 1-35, 849, t3/10; cum 132K 11/12; 

18287, Skybolt 1-24H, 911, t1/10; cum 160K 11/12;

18363, Howitzer 1-25H, 981, t1/10; cum 184K 11/12;


18207, Machete 1-19H, confidential, 1,215, t3/10; cum 186K 11/12;

18195, Cougar Federal 1-30H,1,264, cum 208K 11/12;

18211, Minx 1-29H, 1,000, short lateral, north, t10/09; cum 173K 11/12;
18239, Bazooka 1-20H, 876, short lateral, south, t11/09; cum 169K 11/12;


18312, Whirlwind 1-31H, 902, t6/10; cum 187K 11/12;
18589, Sniper Federal 1-6-7H, 962, t5/10; cum 321K 11/12;

18364, Zephyr 1-36H, 1,526, t2/10; cum 212K 11/12;

18180, Stallion 1-1-12H, 2,561, t2/10; cum 298K 11/12;

17801, Jericho 1-5H, 750, short lateral, south, t3/09; cum 101K 11/12;
18220, Coyote 1-32H, 846, short lateral, north; t9/09; cum 155K 11/12;
18792, Jericho 2-5H-TF, 368, t6/12; cum 58K 11/12;

18574, Mole 1-20H, 1,427, t12/10; cum 128K 11/12;
18865, Silencer 1-29H, 1,026, t12/10; cum 172K 11/12;

Of all producers, Slawson has the best names for their wells.

For more on this phenomenon of Slawson drilling wells right next to each other, click here.

Murphy Creek Update

NEWS

January 20, 2013: a comment concerning this field posted elsewhere:

I was doing some personal research near some of my area. 5 Bartlett wells (145-95-16) caught my attention. I was seeing 80,000 mcf in one month. Similiar to what you are saying 4 million pounds of sand. A boost in an old well about three times higher than ever on oil production. My question is I did not see alot of oil yet unsure if not posted or shutting in very interesting overall next month or two should tell.
[The Bartlett wells do not look promising; strange.]

October 8, 2012: remember -- Encore --> Denbury --> XOM (Bakken assets)

August 8, 2011: Highway 22 will get temporary gravel fix for the winter; definitive repair in spring, 2012.

July 17, 2011: The major road running through this field, ND State Highway 22, was opened one or two weeks ago. 

July 17, 2011: In the original posting, I said Murphy field was fairly inactive. Not true this month: seven rigs on site. A lot of permits/wells have changed hands since the original post: a) OXY USA bought Anschutz; b) Denbury bought Encore; c) Hess bought Tracker's TRZ LLC.

March 27, 2010: 18453, Hess/Tracker, 2,121, Murphy 11-1H; s2/10; t5/10; cum 177K 2/12; 

Permits

Murphy Creek is just too big to update all the permits, but I will start with 2014 and work backwards. 

2020 (as of March 24, 2020)
37470, conf, MRO,
37469, conf, MRO,
37468, conf, MRO,
37468, conf, MRO,
37467, conf, MRO,

2019 (the list is complete)
36617, SI/NC, MRO, Easton 44-20H, Murphy Creek, huge production.
36557, loc, Lime Rock Resources,
36556, loc, Lime Rock Resources,
36555, loc, Lime Rock Resources,
36478, drl, CLR, Jack 8-4H, Murphy Creek,

36477, drl, CLR, Jack 7-4H1, Murphy Creek,
36476, drl, CLR, Jack 6-4H, Murphy Creek,
36475, drl, CLR, Jack 5-4H1, Murphy Creek,
36322, loc, Lime Rock Resources,
36198, SI/NC, MRO, Parmeter 14-21H, Murphy Creek, huge production.
36197, SI/NC, MRO, Reagan 14-21H, Murphy Creek, huge production.
36196, dry, MRO, Raleigh 44-20H, Murphy Creek,
36080, loc, Lime Rock Resources,

2018 (the list is complete)
35655,
35654,
35029,
34845,

2017 (the list is complete)
34117,
34116,
34115,
34114,

2016 (the list is complete) 
None.

2015 (the list is complete)
32309,
32308,
32297,
32253,
32252,
32251,
32250,
32249,
30462,
30461,
30460,
30400,
31960,
31959,
31958,
30484,
30483,
30459,
30401, conf, MRO, Coan 14-34H, Murphy Creek,


2014 (the list is complete)
30009, 2,426, MRO, CK USA 31-6H, Murphy Creek, t6/15; cum 169K 1/20;
29707,
29706,
29246,
29156,
29155,
29154,
28695,
28694,
28664,
28664, 1,921, MRO, Kerkhoff 14-8H, t7/15; cum 169K 1/20;
28422, PNC, OXY USA, Neal 2-33-28H-144-95,
28421, PNC, OXY USA, Twist 2-4-9H-143-95,
28243, loc, OXY USA, Rebsom 4-14-23H-143-95,
28242, loc, OXY USA, Rebsom 3-14-23H-143-95,
28241, loc, OXY USA, Harlan Rebsom 3-11-2H-143-95,
28240, loc, OXY USA, Harlan Rebsom 4-11-2H-143-95,
28024, 910, XTO, Bang 31X-29G, Murphy Creek, t10/14; cum 134K 12/19; off line 1/20;
28023, 1,161, XTO, Bang 31X-29D, Murphy Creek, t10/14; cum 199K 1/20;
27790, 1,815, XTO, Johnson 43X-27H, Murphy Creek, 2/15; cum 198K 1/20;
27789, 1,825, XTO, Johnson 43X-27C, Murphy Creek, t2/15; cum 183K 1/20;
27788, conf, XTO, Johnson 43X-27G,
27787, conf, XTO, Johnson 43X-27B,
27523, drl, OXY USA, State Kary 5-19-18H-144-96,
27370, drl, OXY USA, Federal Kubik Trust 4-19-18H-143-95,
2013
27359, conf, XTO, Franchuk 24X-19F,
27358, conf, XTO, Franchuk 24X-19B,
27357, conf, XTO, Franchuk 24X-19E,
27356, conf, XTO, Franchuk 24X-19A,
26925, 1,687, MRO, Irene Ell 11-1H, t3/14; cum 20K 4/14;
26748, conf, OXY USA, Wittinger 4-8-5H-143-95, producing,
26747, conf, OXY USA, Wittinger 3-8-5H-143-95, producing,
26746, conf, OXY USA, Emil Veverka 4-17-20H-143-95, producing,
26636, conf, OXY USA, Emil Veverka 3-17-20H-143-95, producing,
26289, 1,976, MRO, Adam Ell 44-33H, t2/14; cum 29K 41/4;
26288, 2,046, MRO, Ell 21-1H, t2/14; cum 27K 4/14;
26287, 1,934, MRO, Adam Ell 34-33H, cum 27K 4/14;
25761, 1,810, MRO, Kathryn Kukla 14-34H, t12/13; cum 42K 4/14;
25760, 1,757, MRO, William Kukla 24-34H, t12/13; cum 34K 4/14;
25710, 556, OXY USA, State Kary 3-19-18H-14496, t11/13; cum 45K 4/14;
25708, 711, OXY USA, State Kary 4-19-18H-144-96, t11/13; cum 52K 4/14;
25382, 1,415, MRO, Alice Darwin 34-35H, t9/13; cum 43K 4/14;
25329, 2,275, MRO, LBM Tuhy USA 41-4H, t9/13; cum 66K 4/14;
25328, 2,034, MRO, Judy Tuhy USA 31-4H, t9/13; cum 49K 4/14;
25300, 1,949, XTO, Franchuk 24X-20E, t9/13; cum 42K 4/14;
25299, 1,881, XTO, Franchuk 24X-20A, t8/13; cum 78K 4/14;
25256, 1,398, MRO, Michael Charchenko 24-21H, t8/13; cum 59K 4/14;
25113, 1,592, MRO, Glenn Scott 24-31H, t7/13; cum 63K 4/14;
25107, 1,824, MRO, Darcy Dirkach 44-12H, t12/13; cum 44K 4/14;
25106, 1,446, MRO, Darcy Dirkach 34-12H, t11/13; cum 50K 4/14;
24939, 603, OXY USA, Federal Adelbert Ames 1-19-18H-143-94, t10/13; cum 36K 4/14;
24938, loc, OXY USA, Mary Walker 1-30-31H-143-94,
24926, 282, OXY USA, Eleanor Twist 2-3-10H-143-95, t813; cum 29K 4/14;

Quick Update of Murphy Creek Oil Field

Updates

March 23, 2012: a couple of things -- Murphy Creek permits/wells are being updated a bit lower down in the original post. Today: six rigs on site in this large field. In addition, several more (six) rigs in other fields but right on the edge of Murphy Creek; three of the Murphy Creek rigs are at the far north end; three farther south. The north half is still the most active, but increasingly more activity in the south. 

January 13, 2011 

IPs and Production Excepted: Those May Be Updated

Activity seems to be picking up again in the Murphy Creek oil field, but that may be an illusion; it's a huge field, so one would expect a fair number of new permits in a large field. But here's a quick review to be added to the original posting below:

Over the past couple of days, there have been a few permits issued for Murphy Creek; it has had some good wells. 

This is a huge oil field in the Williston Basin.

It totals about ten (10) townships in all, south and west of the reservation. The town of Killdeer is located at the very north of the oil field and is in an active area of drilling. In fact, one can pretty much divide the Murphy Creek oil field in half.

The southern half (T142-R95, T142-R94, T143-$93, T143-R94, and T143-95) has practically no activity.

On the other hand, the northern half (T144-R04, T44-R95, T144-R96, and T145-R95) is very, very active.

North half; lots of activity; the major players by township:

• 145-95: Denbury/Encore, MRO, CLR
• 144-96: MRO, Encore
• 144-95: MRO
• 144-94: Hess/Tracker

South half; minimal activity; the major players by township:

• 143-95: OXY USA/Anschutz
• 142-94: OXY USA/Anschutz
• 143-93: Hess/Tracker
• 142-95: OXY USA/Anschutz, Encore
• 142-94: OXY USA/Anschutz

As noted: Encore is now part of  Denbury and Anschutz assets have been bought by Oxy.

Original Posting
The Murphy Creek Field 
New permits have been added since original post

The February 25, 2010, NDIC docket piqued my interest in the Murphy Creek field.

Case #12170 was submitted by Tracker Resource Development II LLC. Tracker requested that the Murphy Creek be expanded by a number of sections in two neighboring townships; that the spacing units be 1280 acres; that Tracker be permitted to drill in 75 of those 1280-acre spaced units; and, that they could drill as many as three horizontal drills in each spacing unit. If approved, Tracker would be given the go-ahead to begin the process to ultimately drill 225 more wells in the Murphy Creek field.

The Murphy Creek field is an extremely irregular field, and at 286 sections, is one of the larger fields in the Williston Basin. If NDIC agrees to expand it, it appears that about 40 more sections would be added in townships 143-92 and 143-93.

Right now, the bulk of the sections are in townships 145-95, 144-96, 144-95, 144-94, 143-94, 143-95, 142-95, and 142-94.  In addition, there are sections in townships 145-96, 143-93, and 143-96.

The town of Killdeer (population: 713 in 2000, Wikipedia; wanna bet it's a lot bigger now?) sits at the very north of this oil field. The field is not particularly active right now but is directly south of the Killdeer field, the Chimney Butte field, and the Bailey field, all much smaller, but all much more active.

A long line of wells, sections 25, 26, 35, 36 in 144-96

• 22260, 930, MRO, Landbloom 24-26H, t7/12; cum 82K 4/14;
• 22261, 1,188, MRO, Landbloom 14-26H, t7/12; cum 96K 4/14;
• 20082, 1,683, BR, Intervale 31-35H, t9/12; cum 82K 4/14;
• 17119, 315, MRO, Krenzel 34-26H, t9/08; cum 94K 4/14;
• 18106, 823, BR, Intervale 41-35H, t9/09; cum 86K 4/12;
• 17573, 327, MRO, Wm. and Agnes Scott 14-25H, t11/08; cum 121K 4/14;
• 20435, 1,545, BR, Scott 21-36MBH, t11/11; cum 92K 4/14;
• 20436, 1,277, BR, Scott 31-26MBH, t11/11; cum 79K 4/14;
• 17989, 725, BR, Scott 31-36H, t6/09; cum 141K 4/14;
• 16835, 334, MRO, Houghton 34-25H, t1/08; cum 140K 4/14;

A cluster of wells [added June 8, 2012]

• 20746, 678, CLR, Jack 2-9H, t2/12; cum 155K 4/14;
• 17702, 513, CLR/BR, Jack 14-9H, t5/09; cum 262K 4/14;
• 18074, 25, BR, Bartlet 21-16H, t9/09; cum 187K 4/14;
• 21487, 762, BR, Bartlett 11-16TFH, t9/12; cum35K 4/14;
• 21484, 1,483, BR, Bartlett 31-16TFH, t9/12; cum 52K 4/14;
• 21485, 1,283, BR, Bartlett 21-16MBH, t9/12; cum 46K 4/14;

There is an interesting line of wells running east-to-west, sections 7 - 18 in 144-95 and extending into section 7, 8, 17, and 18 in 144-94. (IPs in red). [Updated Oct 4, 2010.]

17774, 393, Hess/Tracker, Lemieux 17-1H; s6/11; t9/11; F; cum 115K 4/14;
17765, 885, Hess/Tracker,Fritz 18-1H; s1/09; t3/09; cum 184K 4/14;
18591, 463, Marathon, Joseph Schollmeyer 14-7H, t7/10; 103K 4/14;
18048, 1,214, Hess/Tracker, Larsen 13-1H, t2/10, 217K 4/14;
18453, 2,121, Hess/Tracker, Murphy 11-1H, t5/10, 250K 4/14;
18523, 1,447, Hess/Tracker, Kudrna 10-1H, t6/10; 156K 4/12;
17140, 291, Marathon, Kudrna 41-16H, Buck 44-21H, 236K 4/14;
18090, 384, Marathon, Kirkach 34-9H, cum 109K 4/14;
17942, 1,184, Marathon, Kovaloff 14-9H, s3/11; t10/11; F; cum 134K 4/14;
17891, 1,064, Marathon, Kovaloff 34-8H, s6/11; t11/11; F; cum 128K 4/14;
16987, 373, Marathon, Willard Kovaloff 21-17H, t6/08; cum 102K 4/14;
16995, 253, Marathon, Koberstine 14-8H, t7/08; cum 94K 4/14;
17160, 378, Marathon, Viola Koberstine 34-7H, t8/08; 123K 4/14;
17046, 306, Marathon, Irene Kovaloff 31-18Ht8/08; 91K 4/12;

There are many other examples of a string of wells all along one line; obviously they are right on a pipeline.

Permits in Murphy Creek (this section is being updated periodically):

• 18637, 501, Denbury/Encore, Franchuk 44-20SWH, s5/10; t5/11; F; cum 38K 1/12
• 18638, 2,184, Denbury/Encore, Franchuk 44-20NWH
• 18769, 1,722, CLR, Roadrunner 1-15H
• 18846, 971, Hess/Tracker, Dirkach 24-1H
• 18847, 353, Anschutz/OXY USA, Eleanor Twist 1-3-10H-143-95; t9/11; F; cum 15K 1/12;
• 19137, 2,928, Encore/Denbury Onshore, Franchuk 44-19NWH; s8/10; t1/11; cum 88K; 2/12;
• 19138, 2,616, Encore/Denbury Onshore, Franchuk 44-19SWH; s8/10; t1/1l; cum 83K; 2/12;
• 19206, 56, OXY USA/Anschutz, Nelson 1-12-1H-143-95; s10/10; t3/11; F; 56K 1/12
• 19284, 1,130, MRO, Edward Darwin 14-35H; s8/10; t7/11; F; cum 35K 1/12;
• 19374, 653, MRO, Darcy Dirach 14-12H, 31K in 3.3 months
• 19396, 82, MRO, Ernest Charchenko 34-33H
• 19608, DRY, OXY USA/Anschutz, Harlan Rebsom 1-2-11H-143-95
• 19642, 42, OXY USA/Anschutz, Darlene Dvorak 1-27-34H-143-9; 6K in January, 2012;
• 19728, 549, CLR, Dolezal 2-5H
• 19743, 1,002, MRO, Hartman 14-32H, s2/11; t7/11; F; cum 43K 1/12;
• 19792, PNC, Denbury Onshore/Encore, Wing 44-26NWH
• 19812, 332, Slawson, Turbo 1-21-16H
• 19914, 489,  OXY USA, Rebsom 1-23-14H-143-95; t4/12; cum 39K 10/12;
• 19924, 1,225, BR, Rifle Falls 31-25H, t 10/11; cum 22K 4/12;
• 19998, PNC, Tracker, Regeth 22-1H (new permit, same name, a few feet to the west)
• 20024, 486, Anschutz, Novasio State 1-16-21H-142-95, t6/11; cum 31K 4/12;
• 20081, 1,202, BR, Intervale 11-35H; s3/11; t8/11; F; cum 26K 1/12;
• 20082, 1,683, BR, Intervale 31-35H; t9/12; cum 41K 8/12;
• 20083, 25, OXY OXY/Anschutz, Richard Dvorak 1-33-28H-143-95; t9/11; cum 29K 4/12;
• 20161, 441, BR, Rifle Falls 41-25H; s6/11; t10/11; F; cum 11K 1/12
• 20194, 63, OXYUSA/Anschutz, Wannemacher 1-4-9H; s3/11; t9/11; F; cum 18K 1/12;
• 20279, PNC, Anschutz, State Jaeger 1-16-21H-142-94
• 20303, 763, MRO, Kovaloff 41-17H; s7/11; t10/11; F; cum 25K 1/12;
• 20304, 949, MRO, State Kovaloff 11-16H; s6/11; t11/11; F; cum 23K 1/12;
• 20411, 212, OXY USA/Anschutz, State Jaeger 1-21-16H-142-94; t11/11; cum 7K 4/12;
• 20435, 1,545, BR, Scott 21-36MBH, t11/11; cum 34K 8/12;
• 20436, 1,277, BR, Scott 31-36MBH, t11/11; cum 30K 8/12;
• 20453, 440, Hess/Tracker, Wallace 7-1H; s4/11; t9/11; cum 31K 1/12;
• 20472, PNC, OXY USA/Anschutz, Watkins State 1-35-36H-143-95
• 20473, PNC, OXY USA//Anschutz, George Miller 1-2-11H-142-95
• 20479, PNC, OXY USA/Anschutz, Tuhy State 1-36-25H-143-95
• 20480, PNC, OXY USA/Anschutz, Katie Heiser 1-1-12H-142-95
• 20765, 366, OXY USA, George Miller 1-11-2H-142-95, t6/12; cum 12K 10/12;
• 20750, DRL, OXY USA/Anschutz, Katie Heiser 1-1-12H-142-95; producing; no IP yet 8/12
• 20580, 540, OXY USA, Terry Dvorak 1-15-22H-142-95; t4/12; cum 12K 8/12;
• 20581, 65, OXY USA, Harland Rebsom 1-2-11H-143-95X; s3/11; t36K; F; cum 36K 1/12;
• 21263, 325, OXY USA, Wittinger 2-8-5H-143-95; 18 days in January, 2012 -- 14K;
• 21264, 509, OXY USA, Emil Veverka 2-17-20H-143-95; t1/12; cum 30K 8/12;
• 21285, 910, MRO, Person 24-35H, s10/11; t1/12; F; cum 19K 3/12;
• 21343, conf, MRO
• 21424, 939, Denbury, Johnson 43-27WNH, t5/12; cum 25K 8/12;
• 21461, 1,457, MRO, Ivan Hecker USA 41-6H 2, s9/11; t11/11; F; cum 46K 3/12;
• 21463, 1,039, Slawson, Turbo 2-21-16H, 10/11; t2/12; F; cum 14K; 2/12;
• 21484, 1,483, BR, Bartlett 31-16TFH, t9/12; cum 2K 10/12;
• 21485, 1,283, BR, Bartlett 21-16MBH, t9/12; cum 2K 10/12;
• 21486, 458, BR, Bartlett 21-16TFH, t9/12; cum 1K 10/12;
• 21487, 762, BR, Bartlett 11-16TFH, t9/12; cum 2K 10/12;
• 21493, 694, Hess, MC-Kudrna-144-95-1522H-1, s10/11; t2/12; F; cum 24K 2/12;
• 21505, 349, OXY USA, State Watkins 1-26-35H-143-95; t5/12; cum 25K 10/12;
• 21577, 1,186, MRO, Ernest Charchenko 14-33H, t5/12; cum 35K 8/12;
• 21583, 1.087, CLR, Roadrunner 3-15H, t7/12; cum 20K 8/12;
• 21584, 1,081, CLR, Clover 3-10H, t7/12; cum 39K 8/12;
• 21585, 1,210, CLR, Roadrunner 2-15H, t7/12; cum 24K 8/12;
• 21586, 1,345, CLR, Clover 2-10H, t7/12; cum 35K 8/12;
• 21635, 681, OXY USA, State Dukart 1-24-13H-143-95, t5/12; cum 23K 8/12;
• 21636, 581, OXY USA, State Tuhy 1-25-36H-143-95;
• 21674, 156, OXY USA, Annie Oakley 1-20-17H-142-94; t3/12; cum 10K 8/12;
• 21677, loc, OXY USA
• 21685, DRL --> loc, OXY USA; producing 21K in first month;
• 21686, 256, OXY USA, Kubik Trust 2-18-19H-143-5; t5/12; cum 67K 10/12;
• 21812, 1,291, MRO; Garry Sampson 34-32H; t4/12; cum 37K 8/12;
• 21813, 1,331, MRO; Garry Sampson 24-32H, t4/12; cum 45K 8/12;
• 21925, 401, Hess; MC-Heinert 144-94-2215H-1, t3/12; cum 21K 8/12;
• 22043, 332, Hess, MC-Steckler-143-9400805H-1, t4/12; cum 29K 8/12;
• 22133, DRL --> conf, OXY USA
• 22259, 1,262, MRO, Ernest Charchenko 24-33H, t5/12; cum 40K 10/12;
• 22260, 930, MRO, Landblom 24-26H, producing; t7/12; cum 28K 10/12;
• 22261, 1,188, MRO, Landblom 14-26H, t7/12; cum 36K 10/12;
• 22279, 1,108, OXY USA, State Kary 2-19-18H-144-96; t6/12; cum 44K 10/12;
• 22308, PNC, Hess
• 22369, 304, OXY USA, State Jablonsky B 1-36-25H-142-95; t5/12; cum 18K 10/12;
• 22442, 685, Hess, MC-Sickler-144-95-1423H-1, t8/12; cum 39K 10/12;
• 22444, loc --> drl, OXY USA
• 22449, loc, OXY USA
• 22478, 417, Hess, MC-Murphy 144-95-1102H-2, t8/12; cum 27K 10/12;
• 22567, dry, OXY USA, State Buffalo Bill 1-20-17H-143-94 OLD,

A small number of all the wells in Murphy Creek:

• 17094, 28, OXY USA, Sickler 22-1H, t7/08; cum 10K 10/12;
• 17785, PNC
• 17234, 308, OXY USA, Dvorak 10-1H, t7/08; cum 59K 10/12;
• 17708, PNC
• 17749, PNC
• 17802, PNC
• 18223, 354, Hess, Riemer 2-1H, t10/09; cum 71K 10/12;
• 17101, conf, Hess, Knutson 4-1H
• 17873, PNC
• 16769, 163, Hess, Hueske 12-1H, t2/08; cum 26K 10/12;
• 17525, 1,414, OXY USA, Twist 31-4H, t4/10; cum 124K 10/12;
• 18300, 1,562, OXY USA, Neal 1-33-28H-144-95, t2/10; cum 174K 10/12;
• 17448, 1,084, OXY USA, Wittinger 31-5H, t11/09; cum 132K 10/12;
• 17437, 583, OXY USA/Anschutz,Scott 34-7H, t8/09; cum 120K 10/12;
• 18353, 2,374, OXY USA, Kubik Trust 1-19-18H-143-95, t4/10; cum 256K 10/12;
• 18395, 2,207, OXY USA, Kathleen Stroh 1-20-17H-143-95, t6/10; cum 184K 10/12;
• 16740, PNC
• 16678, 315, Denbury Onshore, Truchan 11X-33H, t9/07; cum 93K 10/12;
• 16766, 252, Denbury Onshore, Rogne 44-34H, t12/07; cum 102K 10/12;
• 16765, 318, DenburyONshore, Rogne 11-35H, t1/08; cum 99K 10/12;
• 17971, 393, MRO, Isabelle Hartman 42-22H, t9/09; cum 80K 10/12;
• 17868, 1,248, BR, Catalina 11-23H, t5/09; cum 93K 10/12; 
• 17865, 259, MRO, Adam Ell 24-33H, t5/09; cum 91K 10/12;
• 16422, 293, MRO, Kukla 34-34H,t12/07; cum 96K 10/12;
• 17759, 160, MRO, Darwin 14-35H, okay well (LODGEPOLE); t2/09; cum 38K 10/12;
• 17712, 502, MRO, State Lazorenko 14-36H, t4/09; cum 112K 10/12;
• 17713, 427, MRO, State Lazorenko 34-26H, t4/09; cum 117K 10/12;

Crazy Numbers -- Bakken, North Dakota, USA

Update

I originally posted this blog a long time ago, when the general consensus was only one Bakken well per section (640 acres). At the time, I went again the general consensus and opined that one could see at least six horizontals in a spacing unit. That has come to pass. Denbury Onshore has requested as many as 7 wells in one spacing unit, regardless of whether it is a 640-acre spacing unit or a 1280-acre spacing unit. I rest my case. September 17, 2011.

Below, the original post follows. For a more recent commentary about crazy numbers, click here for data on NDGS estimates of original oil in place and estimated ultimate recovery.

Original Post

See also Crazy Numbers, Part 2: One well in this current boom will soon surpass one (1) million barrels oil produced, and five have passed the 500,000 barrel mark.

Take this all with a grain of salt. I have nothing better to do this morning than just some back of the envelope doodling.  But I have to run the numbers to explain why anyone would buy an acre of mineral rights for $8,000.

With current technology and/or based on what is being reported in "the Bakken," how much oil might be recovered from a single section in the Parshall oil field?

EOG estimates, and links can be found in numerous places, that the estimated ultimate recovery (EUR) of a single well in the Parshall is 700,000 barrels.

By definition, historically, one well targets one formation.

We now know that, at least in some places, there are two pay formations that are under discussion: the Bakken and the Three Forks Sanish. There is evidence that the Three Forks Sanish is as prolific as the Middle Bakken, at least in some places.

The more I read, and the more I follow the discussion groups concerning horizontal drilling in the Bakken suggests that the impact of fracking is measured in hundreds of feet. I'm willing to suggest that fracking may only impact out to 400 feet on either side of the lateral. Thus, one lateral impacts 800 feet. [CLR's dual-well test to determine whether the Bakken and the Three Forks Sanish communicate might support this supposition, but I don't understand a) the geology of Bakken shale; b) natural fractures; and, c) man-made fracture stimulation entirely.]

The laterals generally run diagonally across a section, so the math/geometry is a bit tougher to sort out, but let's say the laterals ran straight up and down (north-south) in a section. Using that geometry, one could conceivably put 6 laterals running north-south in each section in the Parshall (5,280 feet/800 feet = 6.6)

CLR has opined similarly, stating that dual laterals could increase the EUR by 400,000 barrels. A dual lateral, apparently, is one well, with two horizontals, one horizontal into one formation and one horizontal into another formation. However, folks are already asking why CLR hasn't raised the EUR with the higher IPs being reported; CLR/CEO says there is still not enough data to raise the EURs.

Again, EOG estimates that each well has a EUR of 700,000, not each section. But is CLR then suggesting that one well, with dual laterals, has a EUR of 1,100,000 barrels of oil?

Is is possible that there could be conservatively four horizontals in each section targeting the Bakken, each with a EUR of 700,000 barrels and another four horizontals in each section targeting the Three Forks Sanish, each with a EUR of 400,000 barrels.  That would be a staggering 4.4 million barrels from each section.

Is there 4.4 million barrels of recoverable oil in each section? It appears to be the industry consensus that using current technology only 1 - 3% of total Bakken oil is recoverable; there are suggestions that EOG is extracting 6 - 9% of the recoverable oil. Let's say, EOG is recovering an unheard-of 10% of the total oil. Remember, EOG opines EUR of 700,000 barrels per well. Currently, EOG generally drills one well in each section in the Parshall. 700,000 is 10% of 7 million barrels. [And, if EOG is only extracting 3% of the total oil reserves, then there would be 23 million barrels oil where EOG drills a well.]

So, yes, there is more than enough oil in each section to support four laterals per formation (the USGS survey considered the Bakken and the Three Forks Sanish one formation, and the NDIC is not yet separating the two formations in their reporting).

At $60/barrel, how much is 4.4 million barrels worth? That would be $264 million over the lifetime of the wells. Per section. The Parshall has about 210 sections.

Incidentally, if the fracking impacts 800 feet laterally, it obviously impacts 800 feet in all directions. The Middle Bakken and the Three Forks Sanish are separated by much less than 800 feet. But that is a story for a different day. Just remember that CLR's analysis suggests that nominally separating two wells targeting the two formations will not affect the other formation. That supports my supposition that fracking has significant impact out only so many hundreds of feet. A CLR press release, March 16, 2010, is very, very interesting along this point.

The Bice 1-29H was our [CLR] first Three Forks well completed in May 2008. The Bice 2-29H is particularly important because its initial productivity was so much stronger than the Bice 1-29H, which has been producing for almost two years. Despite almost 83,000 boe of production from the lower Three Forks zone, there was no pressure depletion in the Middle Bakken zone with the Bice 2-29H.

In its first 21 days of production, the Bice 2-29H produced a cumulative total of 16,318 boe, 70 percent more than the Bice 1-29H during its first 21 days of production.

Oh, one more thing: EOG is requesting permission from the NDIC to drill not one (1), not two (2), but three (3) wells in each of their sections in much of the Parshall, targeting not one (1), not two (2), but three (3) different formations: the Middle Bakken, the Upper Three Forks Sanish, and the Lower Three Forks Sanish. Something tells me my numbers may not be too far off the mark.

UPDATE: one day after posting the above "crazy numbers," a much more reliable, sedate, intelligent, reasonable Bakken analyst posted his numbers.  Yeah, maybe my numbers are not so crazy after all.



In the Flesh, Blondie

Stony Creek Update

News

2017 Permits (none as of January 18, 2017)

2016 Permits  
None.


2015 Permits
31929, conf, Zavanna, Mastiff 16-21 4TFH,
31928, conf, Zavanna, Mastiff 16-21 3H,
31927, conf, Zavanna, Mastiff 16-21 2TFH,
31926, conf, Zavanna, Mastiff 16-21 1H
31703, SI/NC, Statoil, Shorty 4-9F 8TFH,
31702, SI/NC, Statoil, Shorty 4-9F 7H,
31701, SI/NC, Statoil, Shorty 4-9F 6TFH,
31700, SI/NC, Statoil, Shorty 4-9F 5H,
31699, SI/NC, Statoil, Shorty 4-9F 4TFH,
31461, SI/NC, Statoil, Shorty 4-9F 2TFH,
31443, SI/NC, Statoil, Shorty 4-9F 3H,
31411, conf, Zavanna, Rover 9-21 1TFH,
31410, conf, Zavanna, Rover 9-21 2H,
30565, TATD, Statoil, Folvag 5-8 1H,
30379, TATD, Statoil, Folvag 5-8 7H,
30376, TATD, Statoil, Folvag 5-8 2TFH,
30373, TATD, Statoil, Folvag 5-8 8TFH,


2014 Permits (list is complete)
30143, 3,202, Statoil, Folvag 5-8 XE 1H, 33 stages, 5.9 million lbs, t6/15; cum 173K 11/16;
29510, 48, Zavanna, Shepherd 3-11 4TFH, t1/17; cum --
29509, 125, Zavanna, Shepherd 3-11 3H, t11/16; cum --
29508, 139, Zavanna, Shepherd 3-11 2TFH, t12/16; cum -- 
29507, 160, Zavanna, Shepherd 3-11 1H, t1/17; cum --
29320, 2,427, Statoil, Folvag 5-8 6TFH, t6/15; cum 109K 11/16;
29318, 2,315, Statoil, Folvag 5-8 5H, t6/15; cum 133K 11/6;
29052, 836, CLR, Robert 1-13H, t11/14; cum 67K 4/15;  choked back;
29013, 953, CLR, Debra 1-2H, t12/14; cum 60K 4/15;
28970, 2,690, Statoil, Syverson 1-12 8H-R, t11/14; cum 54K 4/15;  choked back;
28869, PNC, Zavanna, Labrador 27-34 5TFH, 
28868, PNC, Zavanna, Labrador 27-35 4H,
28867, PNC, Zavanna, Labrador 27-35 3TFH,
28866, PNC, Zavanna, Labrador 27-35H,
28865, PNC, Zavanna, Labrador 27-35 1TFH,
28745, dry, Statoil, Syverson 1-12 8H,
27714, 2,439, Statoil, Syverson 1-12 5TFH, t12/14; cum 126K 11/16;
27713, 2,980, Statoil, Syverson 1-12 6H, t12/14; cum 144K 11/16;
27712, 1,896, Statoil, Syverson 1-12 7TFH, t12/14; cum 131K 11/16;

2013 Permits

• None

2012 Permits

• 24183, 1,949, Statoil/BEXP, Folvag 5-8 4TFH, Stony Creek, t5/14; cum 46K 4/15; choked way back; off line almost every day since December, 2014;
• 24181, 3,012, Statoil/BEXP, Folvag 5-8 3H, Stony Creek, t8/13; cum 156K; choked way back; off line often since February, 2014;
• 24002, 2,490, Statoil/BEXP, Syverson 1-12 4H, Stony Creek, s2/14; t12/14; cum 43K 4/15;
• 24001, 1,670, Statoil/BEXP, Syverson 1-12 3TFH, Stony Creek, s2/14; t12/14; cum 28K 4/15;
• 23972, 3,249, Statoil/BEXP, State 36-1 4TFH, Stony Creek, t8/13; cum 168K 4/15;
• 22922, 2.907, Statoil/BEXP, Syverson 1-12 2TFH, t12/12; ccum 148K 4/15; off-line much of autumn, 2014; operational?
• 22553, 527, Zavanna, Sabertooth 1-24H, Stony Creek, t8/12; cum 209K 4/15; choked way back 4/15 (operational?)

June 22, 2011: The wells in Stony Creek, as of today:

• 22136, 2,776, Statoil/BEXP, Syverson 1-12 1H,  t12/12; cum 152K 4/15;  choked back;
• 21873, 640, Zavanna, Bengal 1-2H, t7/12; cum 179K 4/15;  choked back;
• 21874, 540, Zavanna, Tony 1-3H, t8/12; cum 201K 4/15;  
• 21907, 3,779, Statoil/BEXP, Shorty 4-9 1H, t6/12; cum 250K 11/16;
• 21226, 996, Zavanna, Panther 16-21 1H, t4/12; cum 344K 11/16;
• 21227, 909, Zavanna Leopard 20-17 1H, t7/12; cum 280K 11/16;
• 22553, 527, Zavanna, Sabertooth 1-24H, t8/12; cum 254K 11/16;
• 18092: PNC, Zavanna, Serval 1-9H, 3/12;
• 18063: 1,034, Zavanna, Ocelot 1-15H; t4/12; cum 257K 11/1;6
• 18067: 803, Zavanna, Lion 1-14H; t5/12; cum 169K 10/14;
• 20111: 718, Zavanna, Wildcat 1-11H; t8/11; cum 172K 10/14;
• 18133: PNC, Zavanna, Panther 1-16H
• 18070: PNC, Zavanna, Leopard 1-20H
• 18064: 1,085, Zavanna, Cougar 1-35H, t8/11; cum 198K 10/14;
• 18069: 783, Zavanna, Tiger 1-23H (Bakken); t6/10; cum 145K 10/14;
• 17453: 225, Zavanna, Puma 1-26H (Bakken); t2/09; cum 100K 10/14;
• 18014: 1,075, Zavanna, Bobcat 1-25H (Bakken), t1/10; cum 152K 10/14;
• 18307: 3,236, Statoil/BEXP, State 36-1 1H (Bakken) (see below), t1/10; cum 300K 10/14;
• 19215: 1,872, Statoil/BEXP, State 36-1 2H (Bakken), t9/10; cum 188K 10/14;
• 19216: 3,442, Statoil/BEXP, State 36-1 3H, t6/12; cum 197K 10/14;
• 12186 (vertical): 347, Citation Oil and Gas, State 23-36, a Madison well; t12/87, cum 368,469 bbls 10/14;
• 13323 (vertical): DRY, Brooks Exploration, Corpron 1-9, Madison, drilled 1992
• 12320 (vertical): 116, Citation Oil and Gas, Barton 41-1, a Madison well;  t2/98, cum 65,215 bbls 10/14;
  

April 22, 2010: Statoil/BEXP announces a good well -- #18307, State 36-1 1-H, 3,236 bopd; t1/10; cum 341K 11/16;

Original Post

Stony Creek is one of the smaller fields in the Williston Basin. It is all of 17 sections. It averages three sections wide (E-W) and six sections north to south. It is located northeast of Williston, and one mile west of the small hamlet of Spring Brook, population, 26 (according to Wikipedia).

One can reach the field by driving east of Williston on 1806, about four miles after crossing the Little Muddy Creek/River bridge. Just before seeing a huge oil well on your left (north of State 1806), there is a county road going north. Drive north about three miles and Stony Creek will be on your right. By the way, that "huge well" on State Highway 1806 next to the county road is BEXP's Knoshaug 14-11 1H, which had an IP of 3,761 on 1/30/11 (no pump yet; as of 1/27/11); cumulative through April, 2011: 69,000 bbls of oil. (In the Avoca oil field.)

Zavanna has most of the permits/wells in Stony Creek: there are currently ten (10) wells on the confidential list and one well that is producing: Puma 1-26H, #17453, 225 bopd (IP), section 26, T155N-100W. According to a press release, this is probably why Zavanna is so interested in Stony Brook:

18014, Zavanna, Bobcat 1-25H, 2,303, section 24 (still on confidential list) -- see above

In three sections, Zavanna has placed two wells right next to each other. On the surface, the wells are 210 feet apart.

The wells are located on my "wells to watch" page.

Last update: June 22, 2011.