One Of The Original Bakken Wells Goes Over 500K Bbls Crude Oil -- March 19, 2022

This was one of the "original Bakken" wells. Wow, those were exciting days. I'm glad I was able to be there to watch this all play out.

The well:

• 18628, 4,357, Grayson Mill / Equinor / Staoil / BEXP, Jack Cvancara 19-18 1H, Alger, t5/10; cum 425K 9/16; cum 534K 1/22; recent production:
  

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	1-2022	31	1268	972	1220	2874	2735	15
BAKKEN	12-2021	30	1209	1533	1056	3073	2900	53
BAKKEN	11-2021	30	1652	1959	1542	3944	3807	17
BAKKEN	10-2021	31	1679	1402	1666	4087	3943	20
BAKKEN	9-2021	30	1633	1526	1469	4187	4019	48
BAKKEN	8-2021	31	1694	1497	1602	4009	3861	24
BAKKEN	7-2021	31	1713	1900	1516	3880	3731	25
BAKKEN	6-2021	30	1653	1430	1489	3782	3640	22

Initial production back in 2010:

BAKKEN	12-2010	31	9794	8573	4496	7454	5625	1413
BAKKEN	11-2010	30	8552	8933	4330	7360	6574	5
BAKKEN	10-2010	25	9539	9418	3918	7599	1858	5371
BAKKEN	9-2010	29	14256	14115	5479	13691	10063	1835
BAKKEN	8-2010	31	16036	17149	6550	15473	10393	2603
BAKKEN	7-2010	31	17396	16290	6999	16816	13909	0
BAKKEN	6-2010	30	25690	26168	10890	25647	18614	3082
BAKKEN	5-2010	28	42919	41254	49679	26176	15835	8124

Flashback: Harold Hamm's "Advice" To President Obama In 2011 -- Five Years Later

This was posted September 30, 2011:

Link here.

This is the WSJ's weekend interview; a big thank you to Chris for alerting me to it.

Harold Hamm, the Oklahoma-based founder and CEO of Continental Resources, the 14th-largest oil company in America, is a man who thinks big. He came to Washington last month to spread a needed message of economic optimism: With the right set of national energy policies, the United States could be "completely energy independent by the end of the decade. We can be the Saudi Arabia of oil and natural gas in the 21st century."

"President Obama is riding the wrong horse on energy," he adds. We can't come anywhere near the scale of energy production to achieve energy independence by pouring tax dollars into "green energy" sources like wind and solar, he argues. It has to come from oil and gas. 

Not only riding the wrong horse, he's riding with the wrong posse. 

How much oil in the Bakken?

How much oil does Bakken have? The official estimate of the U.S. Geological Survey a few years ago was between four and five billion barrels. Mr. Hamm disagrees: "No way. We estimate that the entire field, fully developed, in Bakken is 24 billion barrels."

If he's right, that will double America's proven oil reserves.

"Bakken is almost twice as big as the oil reserve in Prudhoe Bay, Alaska," he continues. According to Department of Energy data, North Dakota is on pace to surpass California in oil production in the next few years. Mr. Hamm explains over lunch in Washington, D.C., that the more his company drills, the more oil it finds. Continental Resources has seen its "proved reserves" of oil and natural gas (mostly in North Dakota) skyrocket to 421 million barrels this summer from 118 million barrels in 2006.

The president's reaction:

When it was Mr. Hamm's turn to talk briefly with President Obama, "I told him of the revolution in the oil and gas industry and how we have the capacity to produce enough oil to enable America to replace OPEC. I wanted to make sure he knew about this."

The president's reaction?

"[President Obama] turned to me and said,

'Oil and gas will be important for the next few years. But we need to go on to green and alternative energy. [Energy] Secretary [Steven] Chu has assured me that within five years, we can have a battery developed that will make a car with the equivalent of 130 miles per gallon.'"

Mr. Hamm holds his head in his hands and says, "Even if you believed that, why would you want to stop oil and gas development? It was pretty disappointing."

I've tagged this update to look at it again five years from now.

Memo To Self: Lindahl Wind Farm -- February 6, 2016

Updates

May 7, 2017: the wind farm is now up and running. Additional data points:

• owned by Enel Green Power North America, an Italian company specializing in renewable energy
• capable of eliminating 450,000 tons of carbon dioxide each year (that's theoretical; of course it will never come close)
• now said to be a $220 million "facility"
• developers now given approval for feasibility study for an adjacent wind farm, to be called Another Scam the Aurora Wind Project

Original Post 

This post will eventually help me understand data points regarding wind farms. Note the data points below. This wind farm is "rated at 150 MW." It will have a mix of 75 wind turbines; some will be 2 MW; some will be 3.3 MW.

If all 75 wind turbines were rated at 2 MW, this wind farm would be rated at 150 MW, I suppose.

If all 75 wind turbines were rated at 3.3 MW, this wind farm would be rated at 250 MW, I suppose.

But the wind farm is said to be a "150-MW-wind farm" with a mix of 2-MW and 3.3 MW wind turbines with 75 wind turbines. I'm sure there is a simple explanation.

The best data point will be the actual wind energy output posted on an annual basis. Let's see if that data is forthcoming three years from now. 

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

Keep your eye on this project. I will write about it at a later date, the wind farm north of Tioga, the Lindahl wind farm.

Data points:

• 75 wind turbines; 2 to 3.3 MW each
• 150 MW
• approved December, 2015
• four (4) miles north of Tioga
• 13,000 acres
• there are no bald eagle nests within 20 miles of the wind farm
• Tradewind Energy; wind farm will be sold to Basin Electric Power Cooperative
• construction will start in early 2016 and will be completed by the end of the year
• estimated cost: $248.5 million 
• $248.5 million / 150 MW = $1.7 million / MW

Related links:

• http://www.prairiebizmag.com/event/article/id/13067/.
• http://www.inforum.com/content/grand-forks-wind-turbine-plant-make-larger-blades.
• https://jobs.livecareer.com/l/production-technicians-lm-wind-power-kelly-services-891f92243b127eb338ceeb14673e238f.

Nine (9) New Permits; Active Rigs Up To 188; BEXP With An Unconfirmed Gusher; A Look At Jack Cvancara and Domaskin Wells

Bakken Operations

Active rigs: 188 (steady, but melting up from intra-boom low of 180 -- I reported earlier an intra-boom low of 181, but my records show it was actually 180; sorry for the error).

Nine (9) new permits --

• Operators: CLR (3), Whiting (3), Triangle (2), Petro-Sentinel
• Fields: Hamlet (Divide), North Creek (Stark), Antelope Creek (McKenzie)
• Comments: Petro-Sentinel has a permit for a wildcat in Bottineau County; this is the first permit for Petro-Sentinel in North Dakota

Wells coming off confidential list were reported earlier; see sidebar at the right.

Triangle canceled two permits:

• 24026, Dwyer .... 2-11-4H
• 24028, Dwyer .... 2-11-2H

Three producing wells completed:

• 22697, 1,875, Grayson Mill / Equinor /Statoil / BEXP, Hospital 31-36 2TFH, Alger, t11/12; cum 159K 91/6; cum 253K 1/22;
  
• 22646, 1,947, Grayson Mill / Equinor /Statoil / BEXP, Jerome Anderson 10-15 4H, Alger, t11/12; cum 156K 9/16; cum 256K 1/22;
  
• 21770, 4,790, Grayson Mill / Equinor /Statoil / BEXP, Domaskin 30-31 2H, Alger, t11/12; cum 265K 9/16; cum 314K 1/22;
  

More on the Statoil/BEXP Domaskin well with a reported 4,790-bbl IP:

• spud February 21, 2012; curve section began on April 28, 2012
• total measured depth (TMD) reached May 13, 2012
• target: Bakken Shale formation, measured depth of 10,252 feet; true vertical depth of 10,182 feet
• Middle Bakken: 10,286 feet; true vertical depth, 10,198 feet
• gas levels were low throughout the first section of the lateral
• at measured death (10,641 feet), a trip gas of 855 units and again at 18,538 feet trip gas of 6,461 was observed
• a flare of 1 - 2 feet seen throughout the later stages

If the sundry forms reporting the completion details (frack stages, proppants, IP) were posted at the NDIC website, I missed them. I did not see the report, and cannot verify the IP of 4,790 as noted. There have been typos on the daily activity report, but BEXP is known for high IPs, so we will see.

There are currently six Domaskin wells; three of them are Fidelity wells in the Sanish field to the south; and three are BEXP wells in Alger oil field one township to the north:

• 17056, 419, Whiting / Kaiser-Francis Oil / Fidelity, Domaskin 11-29H, Sanish, section 29-154-92, t8/08; cum 158K 9/16; cum 179K 1/22;
  
• 17098, 516, Whiting / Kaiser-Francis Oil / Fidelity, Domaskin 11-20H, Sanish, section 20-154-92, t9/08; cum 202K 9/16; cum 242K 1/22;
  
• 19080, 877, Whiting / Kaiser-Francis Oil / Fidelity, Domaskin 19-20-29H, Sanish, 2560-acre; section 19-154-92, t10/10; cum 214K 9/16; cum 264K 1/22;
  

• 21769, 3,603, Whiting / Kaiser-Francis Oil / Fidelity, Domaskin 30-31 3H, Alger, section 30-155-92; t10/12; cum 211 K 9/16; cum 283K 1/22;
  
• 19057, AB/4,106, Grayson Mill / Equinor / Staoil / BEXP, Domaskin 30-31 1H, Alger, section 30-155-92, t10/10; cum 413 K 9/16; cum 473K 6/19;
  
• 21770, 4,790, Grayson Mill / Equinor / Staoil / BEXP, Domaskin 30-31 2H, Alger, section 30-155-92, t11/12; cum 265 K 9/16; cum 341K 1/22;
  

Now, 21770, is the last of four wells on a 4-well pad:

• 21769, see above
• 21772, 2,994, Grayson Mill / Equinor / Staoil / BEXP, Jack Cvancara 19-18 3TFH, Alger, t10/12; cum 226K 9/16; cum 303K 1/22;
  
• 21771, 3,080, Grayson Mill / Equinor / Staoil / BEXP, Jack Cvancara 19-18 2H, Alger, t10/12; cum 254K 9/16; cum 335K 1/22;
  

To complete the story, another Jack Cvancara well in the immediate area, in the next section north:

• 18628, 4,357, Grayson Mill / Equinor / Staoil / BEXP, Jack Cvancara 19-18 1H, Alger, t5/10; cum 425K 9/16; cum 534K 1/22;
  

The Arvid Anderson Wells -- The Very, Very Busy Alger Field -- The Bakken, North Dakota, USA

Elsewhere they are talking about the Arvid Anderson wells. This gives newbies some idea of the infill / development of the Bakken.

• 19198, 2,834, Grayson Mill / Equinor / Statoil / BEXP, Arvid Anderson 14-11 1H, Alger, t11/10; cum 408K 10/16; cum 494K 1/22;
• 22291, 2,650, Grayson Mill / Equinor / Statoil / BEXP, Arvid Anderson 14-11 3H, Alger, t9/12; cum 190K 10/16; cum 263K 1/22;
  
• 22292, 1,754, Grayson Mill / Equinor / Statoil / BEXP, Arvid Anderson 14-11 2H, Alger, t9/12; cum 139K 10/16; cum 184K 1/22;
  
• 22317, IA/1,181, Grayson Mill / Equinor / Statoil / BEXP, Arvid Anderson 14-11 4H, Alger, t6/12; cum 167K 10/16; cum 205K 11/21;
  

Speaking of the Alger, talk about a busy, busy field. Some of the Bakken wells with the highest IPs are located in the Alger field. The following wells are all being drilled, on confidential status, and run in a west-to-east line, no more than about six miles long. They are all multi-well pads, in sections that already have producing wells. Of the six multi-well pads noted below, five have rigs on site (ros).

• 21769, 3,603, Grayson Mill / Equinor / Statoil / BEXP, Domaskin 30-31 3H, Alger, t10/12; cum 212K 10/16; cum 282K 1/22;
  
• 21770, 4,790, Grayson Mill / Equinor / Statoil / BEXP, Domaskin 30-31 2H, Alger, t11/12; cum 266K 10/16; cum 341K 1/22;
  
• 21771, 3,080, Grayson Mill / Equinor / Statoil / BEXP, Jack Cvancara 19 18 2H, Alger, t11/13; cum 256K 10/16; cum 335K 1/22;
  
• 21772, 2,994, Grayson Mill / Equinor / Statoil / BEXP, Jack Cvancara 19 18 3TFH, Alger, t10/12; cum 228K 10/16; cum 303K 1/21;

• 21952, 4,293, Statoil/BEXP, Sorenson 29-32 3H, Alger, t9/12; cum 297K 10/16;
• 21953, 2,790, Statoil/BEXP, Cvancara 20-17 2TFH, Alger, t9/12; cum 195K 10/16;
• 21954, 3,078, Statoil/BEXP, Sorenson 29-32 4H, Alger, t9/12; cum 259K 10/16;
• 21955, 2,972, Statoil/BEXP, Cvancara 20-17 3H, Alger, t9/12; cum 237K 10/16;
• 21957, 1,779, Statoil/BEXP, Cvancara 20-17 4TFH, Alger, t7/14; cum 116K 10/16;

• 22061, 1,837, Statoil/BEXP, Anderson 28-33 2TFH, Alger, t6/12; cum 198K 10/16;
• 22062, 3,371, BStatoil/EXP, Anderson 28-33 3H, Alger, t6/12; cum 276K 10/16;

• 22007, 2,700, Statoil/BEXP, Panzer 22-23 1H, Alger, t6/12; cum 209K 10/16;
• 22266, 1,207, Statoil/BEXP, Panzer 22-23 2H, Alger, t1/13;cum 129K 10/16;

• 21621, 2,551, Statoil/BEXP, Strobeck 27-34 6H, Alger, t7/12; cum 255K 10/16;
• 21623, 2.071, Statoil/BEXP, Strobeck 27-34 8TFH, Alger, t7/12; cum 177K 10/16;

• 22034, 2,944, Grayson Mill / Equinor / Statoil / BEXP, Strobeck 27-34 2H, Alger, t7/12; cum 228K 10/16; cum 284K 1/22;
  
• 22035, 1,962, Statoil/BEXP, Strobeck 27-34 3TFH, Alger, t7/12; cum 146K 10/16;
• 22036, 1,904, Statoil/BEXP, Strobeck 27-34 4H, Alger, t8/12;cum 199K 10/16;
• 22037, 2,026, Statoil/BEXP, Strobeck 27-34 5TFH, Alger, t7/12; cum 176K 10/16;

Horizontals Targeting the Red River Formation -- The Red River, North Dakota, USA

Hoot Owl --> think Red River --> Whiting.

Hoot Owl oil field is in the southwest part of the state, not the far southwest, but about a third of the way between South Dakota and the Canadian border just two miles east of the Montana border; it is about five miles northeast of Camel Hump oil field.

This is a key prospective Whiting field for the Red River formation.

[Some of this is a "cut and paste" from an earlier posting but some folks may have missed it.]

Someone noted that Whiting was requesting to drill a horizontal targeting the Red River formation and wondering if this had been done before. The full story is presented at the sidebar at the right: scroll to "Formations" and then click on "Red River."

Hundreds (?) of horizontal wells (as many as 5 wells per section) have been drilled into the Red River, particularly in southwestern North Dakota.  Eric Fox, earlier this year, wrote:

Although the Red River formation is relatively unknown to investors, the play was discovered in 1967 and first developed with vertical wells. In 1994, horizontal drilling was used to develop the Red River B play. While not many operators are active in the Red River formation, the play still accounted for approximately 10.5% of total oil production in North Dakota in 2010.

Specifically, case 16605:

Application of Whiting Oil & Gas Corp., to establish a 960-acre drilling or spacing unit consisting of all of Section 10 and the N/2 of Section 15, T.141N., R.105W., Golden Valley County, ND, for the purpose of drilling a horizontal well in the Red River Formation, and such other relief as is appropriate. --> Oil and gas permit #22956.

This area is pretty void of activity. The few wells/permitted locations are these (originally only about five wells were noted at time of original post; since then new permits have been posted):

• 19917, 273, Foundation Energy/Whiting, Maus 23-22, wildcat/Camel Hump, "directional" but on the GIS map seen as a vertical, t7/11; cum 141K 10/16; cum 196K 1/22;
  
• 19921, PA/IA/55, Foundatioin Energy/Whiting, Brookhart 11-14, Red River well, wildcat/Hoot Owl, t2/12; cum 11K 10/16; went inactive in 10/16;
  
• 20043, 200, Foundation Energy/Whiting, Peplinski 34-9, Red River well; wildcat/Hoot Owl, t11/11; cum 37K 10/16; cum 464K 1/22;
  
• 20969, A/IA, Foundation Energy/Whiting, Nistler 21-25H, wildcat/Delhi oil field (southeast of Hoot Owl); Three Forks, dry; now a salt water disposal well, that's why it's considered still active, 1/22;
  
• 22569, IA/272, Foundation Energy/Whiting, Stecker 23-3, Hoot Owl, a Red River well; t7/12; cum 53K 10/16; cum 76K 1/21;
  
• 22775, PA/295, Foundation Energy/Whiting, Ross 13-2, Hoot Owl, t8/12; cum 50K 10/16; a Red River well;
• 22956, PA, Foundation Energy/Whiting, Schaal 22-15H, Hoot Owl;
• 23847, 296, Foundation Energy/Whiting, Stecker 32-9, Hoot Owl;a Red River well, t2/13; cum 37K 10/16;
• 23936, PA, Foundation Energy/Whiting, Faiman 32-14; Hoot Owl;

Big Stick Oil Field -- Whiting Madison Wells in One Section, Billings County, Williston Basin, North Dakota, USA

Updates

Permits 

2014 (list complete)
29372,  PNC, Whiting, BSMU 0706, Big Stick,
28160, PNC, White Rock / Whiting, BSMU 1306, Big Stick, Madison

2013 (list complete)
26311, 21 (no typo), Whiting, BSMU 1910, Big Stick, a Madison well, t3/14; cum 12K 1/7;
26310, IA/PNC, Whiting, BSMU 1808, Big Stick, cum 16K 6/21;
25532, PNC, Whiting, BSMU 3603X, Big Stick,
25224, 110, White Rock / Whiting, BSMU 3007, Big Stick, t8/13; cum 72K1 /17; cum 147K 1/22;

2012
23247, 401, Whiting, BSMU 1806, Big Stick, Madison, vertical, 9,554 feet; t1/13; cum 97K 1/17;
22634, 204, Whiting, BSMU 3108, Big Stick, Madison, t1/13; cum 53K 1/17;
22637, TA, Whiting, BSMU 2410, Big Stick, no IP; no oil production in almost two years;
22694, 330, Whiting, BSMU 3006, Big Stick, Madison, t12/12; cum 85K 1/17;

From 2011, forward, not including ones already posted below
22059, TA, Whiting, BSMU 2304, Big Stick, cum 19 bbls;
21547, A, Whiting, Teddy 11-20TFH, Big Stick, no IP; cum 42K 1/7;

Original Post

Big Stick Oil Field is an older oil field in the Williston Basin, comprising just less than one township, T142N-R101W, with a few sections in the township to the south. If one looks at the GIS map server it is peppered with vertical wells, most (all?) of which are Madison wells drilled back in the very late 70's and 80's. The center of the field is about 20 miles northwest of Belfield, and explains the increased emphasis on CBR oil-loading facilities in the southwestern part of the state (Zap, Dickinson, and Fryburg).

There are some huge Madison wells there, as noted below.

At the time of the posting, the area is "owned" by Whiting and is part of their Lewis and Clark prospect.

It appears that drillers will be interested in two formations: vertical wells into the Madison and horizontal wells into the Three Forks formation. Today, these wells are on the confidential list (updated over time):

• 21075, 450, Whiting, BSMU 1807, Madison, t6/12; cum 195K 1/17; vertical, 9,463 feet;
• 21077, IA, Whiting, BSMU 1707, Madison
• 21127, PNC, Whiting, BSMU 1706, Madison
• 21074, PNC, Whiting, BSMU 1705, Madison
• 19370, 17, Whiting, BSMU 2905, Madison, t4/12; cum 227 bbls 1/17 -- (no typo -- brand new well); no production since testing);
• 18652, A, White Rock/Whiting, BSMU 3107, Madison, EOR water injected; nothing after first 15 days of production; tN/D; cum --
• 19294, PNC, Whiting, BSMU 3605, Madison
• 19417, 777, Whiting, Teddy State 21-36TFH, Three Forks; 26 stages; 1.8 million lbs sand; t1/13; cum 72K 1/17;

Remember the Whiting Madison well posted earlier?

That well is in section 36-T142N-R101W in northern Billings County, in southwestern North Dakota, in Whiting's Lewis and Clark prospect.

That Madison well produced 110,000 bbls in the first year, comparable to any Bakken well. I was curious what the other wells in that section did:

• 6995, 569, Whiting, BSMU 3610, Big Stick field, s1979; t 1979; cum 668K 1/17; still producing (34 years)
• 7123, 450, Whiting, BSMU 3603, Big Stick field, s1980; t1980; cum 1.9435 million bbls/ 1/17;
• 7124, 115, Whiting, BSMU 3612, Big Stick field, s1983; t1983; cum 116K 1/17;
• 7125, 311/PA, Whiting, BSMU 3602, Big Stick field, s1979; t1979; cum 792,016 8/90; PNA
• 15445, 224, Whiting, BSMU 2506, Big Stick field, s2003; t2003; cum 192K 1/17;
  
• 18625, 368, Whiting, BSMU 3604, Big Stick field, s10;t10; cum 268K 1/17;

In the neighboring section,

• 7295, 1,711, Whiting, BSMU 3503, Big Stick Field, s81;t81; cum 1.42 million bbls 1/17;

Comments on this later. But except for the new wells drilled in the last year or so, these are all 30-year-old wells and all are still producing, except for one or two. 

The IPs are respectable for Bakken wells, but for Madison wells they are huge. And then look at the Madison well with an IP of 1,711. Pretty interesting.

By the way, earlier this year, Sagebrush reported a great Madison well in Renville County, northern North Dakota.

• 19315, 1,038/AB, PetroHarvester/Sagebrush, Rice 11, Renville, Madison (not a Bakken), s7/10; 8/10; cum 130K 7/15(4/12); the drop off in production was severe after the first two months, but it is producing 2,500 bbls/month a year later

Wells to Watch, Part I

Locator: 10001WTW.

 

I am no longer adding new wells to this page (posted January 17, 2011).  I do continue, periodically, to update IPs and total oil produced.

I have started a second "wells to watch" page.   This page simply got too long and unwieldy. I started the page early on in the Bakken to get a feel for what the wells are doing.  I now have a very good feel for Bakken wells.

This list is not always up to date. If the well you are looking at does not have an IP, search the entire blog using a search application at the blog site, or search at the Bakken Shale Discussion Group.

NOTE: effective March 1, 2010, CLR will change the way it determines IP. CLR used to do 7-day averages. Stating that pipeline capacity over seven days can be a challenge, CLR is now going to "peak 24-hour rates." 

Using your browser's search tool, this page will be easier to navigate.

Permit number / Producer / IP / Well Name / Comments

Note: if you were brought here looking for information on Zavanna, you should read this first.

Stony Creek (T155N-100W: northeast of Williston; one mile west of Spring Brook)

17453, Zavanna, Puma 1-26H, 225, Stony Creek, section 26, t2/09; cum 118K 9/17 (candidate for re-frack); cum 142K 3/23;
17979, Zavanna, Lynx 1-27H, 706, Stony Creek, section 27, t7/11; cum 228K 9/17 (candidate for re-frack); cum 286K 3/23;
18014, Zavanna, Bobcat 1-25H, 2,303, Stony Creek, section 24, t1/10; cum 152K 11/14; cum 221K 3/23;
18063, Zavanna, Ocelot 1-15H, 1,034, t4/12; cum 205K 11/14; cum 368K 3/23;
18064, Zavanna, Cougar 1-35H, 1,085, Stony Creek, section 35, t7/11; cum 198K 11/14; cum 329K 11/22; off line but still "A";
18067, Zavanna, Lion 1-14H, 803, Stony Creek, t5/12; cum 169K 11/14; cum 312K 2/23; off line but still "A";
18069, Zavanna, Tiger 1-23H, wildcat; 783, t6/10; cum 145K 11/14; cum 253K 3/23;
18070, Zavanna, Leopard 1-20H, PNC,
18071, Zavanna, Cheetah 1-10H, conf; t5/12; cum 169K 11/14; cum 340K 3/23;
******18075, Zavanna, Jaguar 1-22H, 764, t3/12; cum 213K 11/14; cum 381K 3/23;
18092, Zavanna, Serval 1-9H, loc -->PNC
18133, Zavanna, Panther 1-16H, PNC
18307, Grayson Mill/Statoil/BEXP, State 36-1 1-H, 3,236, s10/09; t1/10; cum 302K 11/14; cum 438K 3/23;

Note: Zavanna also has 5 wells east of Williston, T154N-99W, Stockyard Creek
19032, 604, Hanson 28-33 1-H, Stockyard Creek, t11/10; cum 121K 11/14;
18009, Zavanna, Gene 1-22H, 1,128, Stockyard Creek, t4/10; cum 181K 11/14;

(Zavanna has two active rigs in the Bakken. A third one is drilling a SWD -- Aug 1, 2011)

West (and now, north) of Williston

Comment: activity just west of Williston was practically nonexistent prior to mid-2009. Two BEXP wells (the Olson and the Brad Olson) had a lot of interest during summer, 2009; BEXP with 24- / 28-stage fracture stimulation. BCD Farms most remote of all; far northwest of Williston; at extreme edge of BEXP's holdings; another 28-stage fracture. The Oasis well (Sandaker) is about 11 miles NNW of Williston; true wildcat.  The Jackson, the State, and the Williston are part of the initial 6-well partnership package with USEG.  This is extremely exciting, and occurring just after the record North Dakota land lease auction, November 3, 2009. Updated April 27, 2010.

15822, Zenergy, PERMIT CANCELED, Anderson 1-13H, ~ 3 miles SW of Olson / Brad Olson
15878, 72, 48K as of December 31, 2010, Bakken horizontal well, Squires oil field
16052, 77, 37K as of December 31, 2010, Madison well, Rosebud oil field
16173, BEXP, 141, Field 18-19 1H
16259, Zenergy, PNC, Steiner 1-28H, 7 m w of ISN, 1200 feet south of US-2, PNC=canceled
17513, BEXP, 1,160, Olson 10-15H 1-H, at 13 months = 100,000 bbls cumulative
18175, BEXP, 2,125, Brad Olson 9-16 1-H
18204, BEXP, 1,553, BCD Farms, Bull Butte oil field, 78K as of December 31, 2010
18256, BEXP, 1,341, Lee 16-21 1-H, 88K as of December 31, 2010

18257, EOG, 267, Round Prairie 1-17H, t1/10; cum 112K 11/14;
This well is about 100 feet east of acreage of interest. Round Prairie 1-17H is in section 17. Interest has acreage in section 18. Round Prairie is practically on the section line of 17/18 on the north line. NWNW 17-154N-103W (wildcat). 

18282, BEXP, 1,947, Strand 16-9 1-H, 26-stage frac, t11/09; cum 171K 11/14;
18307, BEXP, 3,236, State 36-1 1-H, 30-stage hydraulic fracking, t1/10; cum 302K 11/14;
18324, BEXP, 2,215, Owan-Nehring 27-34 1-H, 30-stage frac, Feb 2, 2010, NDIC, t1/10; cum 221K 11/14;
18369, BEXP, 3,064, Jackson 35-34 1-H, 30-stage frac, Feb 2, 2010
18418, Oasis, 1,128, Sandaker 5602 11-13H, permit, Nov 09

18439, BEXP, 2,323, Jack Erickson 6-31 1-H, 30 fracs, Apr 10
18443, BEXP, 2,302 - April, 2010, Owan 29-32 1-H, Rough Rider Prospect
18456, BEXP, 1,586, Kalil 25-36H,Bull Butte field, PR

18506, BEXP, 1,339, Arnson 13-24 1-H, permit, Squires field, Dec 09
18509, EOG, 892, Hardscrabble 1-16H, Hardscrabble field, Dec 09
18534, BEXP, 2,134, Mortenson 5-32 1-H, Painted Woods, Dec 09
18498, CLR, 896, Obert 1-13H
18791, BEXP, 1,578, Abe 30-31 1-H
18796, BEXP, 1,983, Abe Owan 21-16 1-H, Painted Woods, Mar 10
18906, BEXP, 2,640, Michael Owan 26-35 1-H, Painted Woods, Apr 10

19085, BEXP, 2,172, Brad Olson 9-16 3H, Painted Woods

19086, BEXP, 2,472, Brad Olson 9-16 2H, Painted Woods

The Kalil (18456, IP - 1,334) is in same township oil field as the BCD Farms (18204, IP - 1,553) and one section away from an old dry well (with the same family name) drilled decades ago. This was an area with lots of dry holes decades ago; horizontals to the Bakken seem to be making the difference. Drilling in Jan 10. I have seen a family name "Kahlil" in Williston; I wonder if "Kalil" was misspelled?
18204, 1,553, Statoil/BEXP, BCD Farms 16-21 1H, Bull Butte, t10/09; cum 142K 11/14;
18456, 1,334, Statoil/BEXP, Kalil 25-36 1561H, Bull Butte, t2/10; cum 130K 11/14;

18538, EOG, 885, Round Prairie 9-36H, permit, Dec 09 (section 36), 9K in first 10 days
18567, Oasis, 1,835, Njos Federal 5602 11-13H, Wildcat, Dec 09 (section 13) (note 18418)
18618, EOG, PNC, Mont 3-34H, 34-155N-102W, Wildcat,
18622, EOG, 680, Mont 1-28H, 28-155N-102W, Wildcat,
18623, Oasis, 1,049, Odin Jorgenson 5502 44-8H, 8-155N-102W,
18629, EOG, PNC, Round Prairie 04-08H, wildcat; PNC = permanently canceled
18630, EOG, 358, Round Prairie 04-08H, 8-154N-103W,
18643, EOG, PNC, Judson 1-30H, Lot 4 3-154N-102W, wildcat,
18646, CLR, 572, Anseth 1-29H, 29-155N-03W,
18668, EOG, 491, Round Prairie 2-20H, Wildcat,
18771, Zenergy, 683, Johnson 29-30H, Squires,
18799, Oasis, 1,197, Stowers 5502 43-8H, Squires,
18801, Oasis, 1,481, Contreras 5502 42-7H, Squires,
18802, Oasis, 1,193, Vuki 5502 42-7H, Squires,
18817, Oasis, 1,099, Kjos 5502 44-24H, Squires,
18891, BEXP, 2,631, Larson 3-10 1-H, Williston,
18964, CLR, 145, Fasching 1-22H, Hebron,
18966, CLR, 148, Milloy 1-15H, Hebron, new permit, Apr 28
18992, Slawson, 826, Stampede 1-36-25H, new permit May 5
19030, Oasis, 2,707, Kjorstad 5300 24-22H, wildcat
19031, BEXP, 1,773, Boots 13-24 1-H, Painted Woods,
19044, CLR, 1,866, Goodman 1-36H
19045, Oasis, 53, McFarland 5502 44-12H, not a typo; workover? new IP - 572, May 11
19085, BEXP, 2,172, Brad Olson 9-16 3H, new permit 1 Jun
19086, BEXP, 2.472, Brad Olson 9-16 2H, new permit 1 Jun

Hebron Field (northwest of Williston) (10 sections)

• 18498, 467, CLR, Obert 1-13H
• 18614, 880, CLR, Stedman 1-24H
• 18901, 640, CLR, Horob 1-14H
• 18897, 584, CLR, Panasuk 1-23H
• 18966, 148, CLR, Milloy 1-15H
• 18964, 415, CLR, Fasching 1-22H

Williston City Limits

18311, BEXP, 3,394, Williston 25-36 1-H; almost inside city limits; near old packing plant; generating lots of local interest; a planned 32-stage hydraulic fracturing; December 14, 2009; cum 179K 2/12;

Williston, miscellaneous

18050, AEZ, 1,421, Tong Trust 1-20H; Ray field, 6 tanks on pad, good flare; importance of well: would open up a new area that is currently not very active; also see AEZ, when you get there, scroll down to item #6; cum 73K 2/12;

Miscellaneous

18276, Tracker, 962, Obrigewitch 4-1H, near Killdeer
18227, Tracker, 116, Obrigewitch, 34-1H, near Killdeer

Grenora Area

Comment: new area of interest, summer, 2009; Newfield's 17946 was first well in the area; 1.6 miles NE of Grenora; confidential; said to be a "barnburner"

17946, Newfield, 86, Trigger 1-31H -- not much of a barnburner; turns out to be a bust --- wow, this is bad news, posted Feb 4, 2010.  (Cumulative: 19K after 15 months); cum 26K 2/12;

CLR

17877, Traxel 1-31H, dry (Bakken); produced 71 boepd in the Scallion (lower Lodgepole), immediately above the Bakken; January 2010 (technically, the IP was 84); CLR keeps this well going; as of June, 2010, the well continues to produce about 150 bbls/month; as of February, 2012, 100 bbs/month; produces 10 days/month
Comment: in Mercer County, a wildcat; about as far east as Bakken goes. Lots of folks are interested in this one due to how far east it is. Current press release; discussion regarding Traxel, November, 2009.

These were all reported in a CLR August 6, 2009, press release. These are nine (9) initial test wells targeted to the TFS formation. CLR is operator or has working interest in all nine of these wells:

17398, Kukla 1-21H, 1,429 (best well in the TFS to date for CLR as of Aug 6, 2009)
17558, McGregor 1-15H, 1,101
17471, Merton 1-3H, 911
17226, Lokken 1-2H, 854
17635, George 1-18H, 872
17742, Wiley 1-25H, 816
17889, Olson 1-8H, 735 (wildcat)
17451, Thorvald 1-6H, 603
16672, Lila 1-36H, 563

Dual-reservoir development (Bakken/TFS)

17884, Bice 2-29H (first of two), 1,429*; cum 153K 2/12;
18352, Omar 2-1H (second of two), 694; cum 123K 2/12; no pump;

(Omar 1-1H, #17282, completed in 3rd quarter of 2008, had produced a cumulative 147,510 boe at year-end 2010. At $60/bbl = $8.9 million; cum 172K 2/12)  Omar 1 and Omar 2 were drilled by CLR as a test to see if the Bakken and the TFS were separate formations. The fact that Omar 1 produced a cumulative 147,510 boe even though Omar 2 was drilled parallel to and offset from Omar 1, suggests to some that the two formations, at least in this locality, are separate.) Bice 1-29H (#16943) had an IP of 516.

CLR -- 4th quarter, 2009, all targeting the TFS 

18224, Hendrickson 1-36H, 1,990 (Antelope, west of Four Bears, west of Sanish, west of river), Harold Hamm comments on IP of the Hendrickson
18138, Simmental 1-21H, 1,271 (near Hendrickson 1-36H, Elm Tree field)17530, Hartman 1-28H, 1,225 (Chimney Butte, NW of Killdeer)17819, Tande 1-23H, 1,148 (Lindahl, north of Tioga)18259, Schroeder 1-34H, 915 (Stoneview, north of Tioga)17560, Cuskelly 1-7H, 901 (Rattlesnake Point, NW of Killdeer)

Hess

18228, 225, EN-Uran-154-93-1213H-1. Producing, Jan 12, 2010.
Comment: this is a Bakken/TFS stacked lateral. See Hess. Not all that good for a stacked lateral. This is a stacked lateral: the vertical well will go down to about 9,847 feet where the kick-off point (KOP) begins (starts to go horizontal. The Three Forks horizontal will be extend below the Middle Bakken horizontal.

18602 - 18607 (six wells); RS-Nelson Farms (3) and RS-Shuhart (3). This is interesting, T156N-90W. In the daily activity report dated January 12, 2010, there were six (6) new permits granted. All six permits went to Hess and they were all "development" wells in the Ross oil field. [For update, click here.] This is an average size oil field in the middle of the Bakken. These six permits are all in one section: section 27. All six are offset from the west line by 542 feet, and they are offset from the south line, respectively: 2201 feet, 2151 feet, 2101 feet, 2051 feet, 2001 feet, and 1951 feet. They will be going to the following total depths, again respectively, 19,603 feet; 19,251 feet; 18,976 feet; 18,231 feet; 19,089 feet; and 18,491 feet.  This would make them all long laterals (1280-acre; two sections). January 12, 2010.  [18602: 207; 18603: 154; 18604: 366; 18605: 339; 18606: 117; 18607: 120]

Hess, NDIC docket, January 13, 2010, case no. 11991: T156N-90W, two (2) 2560-acre spacing units: one spacing unit -- sections 20, 21, 22, and 23; the other spacing unit: sections 26, 27, 28, 29.

18775 - 18780 (six wells); EN-Fisher (3) and EN-Dolan (3). section 21- T157N-94W. In the daily activity report dated March 5, 2010, there were six (6) new permits granted to Hess. [For update, click here.]These wells will be the same as above: my hunch -- three long laterals going north, targeting the Upper TFS, the Lower TFS, and the Middle Bakken; and, three long laterals going south targeting the same formations. March 5, 2010.[18775: 511; 18776: 376; 18777: 176; 18778: 182; 18779: 321; 18780: 236]

 Stetson

18212: Dry. MHA 1-11H-148-90; Reported 10/16/09. One of the very few dry wells in current boom. [Operational update, Feb 18, 2010: a pump was put on this well; they are sure they are in the Bakken; 1,470 bbls of oil to date, as well as 34,000 bbls of water. Remember it takes trucks, personnel and money to transport water away from a well. It appears this well is not economic. (1,470 * $60 = $88,000 after four months for a well that cost $6 million to drill.)] On March 5, 2010, reported 50 bopd after workover -- still not all that great. No production since June, 2010; probably shut in.

Wells targeting the Three Forks Sanish

18233, Whiting, Ogden 11-3TFH, 1,479, 24-stage fracture stimulation
18294, Encore, Werre Trust 44-34H, offset to the Werre Trust 21-3H, 341

Comment: these are important wells to watch for at least two reasons. First, they are targeting the Three Forks Sanish. Producers are still trying to define what they have. Second, they are multiple-stage fracs. Whiting, a 24-stage frac. But more interesting, the Encore well. The "original" Weere Trust well was a single-stage frac. Now they will do a 24-stage frac on an offset to compare economics. The offset is 0.45 miles to the northwest. [Update: after the 24-stage frac -- 26K in one month; fast decline; cumulative 104,875 by Dec 31, 2010 -- a very good well; no production in December; winter conditions?]

Wells targeting the Lodgepole formation

Comment: the Lodgepole had been targeted before the current boom. However, with the conventional well Armstrong hit almost inside Dickinson city limits, it is now getting more attention. In addition, Teegue has opined that it may be the third "horizontal" play in the Williston Basin.

18190, Armstrong, 463, Laurine Engel 1, Dickinson, conventional, 170K Dec 31, 2010
18496, Armstrong, 474, Gruman 18-3, Dickinson, conventional, Patterson Lake, Lodgepole, 89K Dec 31, 2010
17759, Marathon, 160, Darwin 14-35, horizontal, Dunn County
17967, Marathon, DRY, Ivan Hecker USA 41-6H, Dunn County
17903, Marathon, 17, Casey Kukla USA 21-6H/Wind Cave 1-30H, Dunn Couny
16416, Baldwin, DRY, Aadnes 34-32, 9802', Mountrail County, Madison

Wells in the FBIR (Fort Berthold Indian Reservation)
EOG wells, Parshall field, TWP 152-90

16497, 1,678, 318K as of Dec 31, 2010
16635, 1,510, 180K as of Dec 31, 2010
16747, 317 (TWP 152-89) Note: #18097 is in same twp, confidential)
16846, 1,721, 295K as of Dec 31, 2010
16931, 1,158, 215K as of Dec 31, 2010
16936, 1,285
16971, 1,148
17005, 1,121
17011, 1,663
17034, 1,167
17294, 1,718
17237, 1,086
17295, 943, Parshall 12-27H, 53,536 bbls in 140 days. 1 sec.; 150K in first 19 months
17522, 843, Parshall 9-30H, 198K in first 24 months
17580, 933, Parshall 18-34H, 62,827 bbls in 130 days, 1 sec
17621, 1,117, Parshall 17-33H, 44,231 bbls in 124 days, 1 sec
17727, 975, Fertile 5-04H, 26,352 bbls in 101 days. 1 sec. (T151N-90W)
17754, 597, Fertile 10-09H, 30,000 bbls in 124 days, 1 sec
17828, 1,134, Parshall 19-35H, 77K as of Dec 31, 2010
17851, 890, Fertile 9-08H, 34,000 bbls in 115 days, 1 sec
17870, 796, Fertile 7-06H, 56,000 bbls in 107 days, 1 sec
17913, 132, Fertile 2-01H

17933, 461, Parshall 10-29H, 47,000 bbls in 110 days. 1 section.
17934, 718, Parshall 16-32H, 51,000 bbls in 105 days, 1 sec
17972, 1,695, Parshall 15-31H. 50761 bbls in 110 days. 1 section. Comment: this well sits right on the Van Hook/Parshall field line (Slawson "owns" Van Hook/Big Bend).
18061, 725, Roberta 1-16H, IP not reported, only1500 bbls first month (fracked?)
18097, 441, Model 10-07H

18157, 1,153, Fertile 13-18H, 44k in first five months; 4,500 bbls/22 days

18178, PNC,  Fertile 8-07H

18376: 171, Parshall 100-22H -- Comment -- this is notable. This is the first well that is being drilled in a section in this township that already has a producing well, #16936 which had a very nice IP (1285 bopd). 18376 sits between 16936 (section 22) and 17005 (section 21). Parshall 100-2H targets the TFS.
18398: 179 (not a typo) Comment -- this is also notable. This well will be drilled in a section that already has a producing well, # 17727 which had a very nice IP (975 bopd). (T152N-90W).


Wildcats, just below the Parshall, inside FBIR, T151N-90W
18121, EOG, 551, Fertile 17-21H, producing as of July 30, 2010
18147, EOG, 952, Fertile 16-20H, producing as of July 30, 2010
18172, EOG, 112, (has EOG lost its touch? February 24, 2010)
18181, EOG, 753, Fertile 19-29H, s6/10; t6/11; F: 32K 11/11
18203, EOG, 1,154, Fertile 34-31H, 75K after 7 months
18208, EOG, PNC, Fertile 22-13H
18289, EOG, 490, Fertile 30-28H
18338, EOG, Shut-In, Fertile 28-26H
18412, EOG, 68, Fertile 29-27H, producing as of Oct 28, 2010
18438, EOG, 285, Fertile 32-33H, 33K after 7 months
18459, EOG, LOC, Fertile 25-32H
18473, EOG, 1,045, 18-30H, 76K after 7 months


Wildcats, just below Parshall, inside FBIR, T150N-90W
16996, EXP, Ryan Exploration, Spotted Bear 11-23 (permit expired)
17929, 546, Questar, Rupple 1-4H-150-90
17990, EXP, Cirque, Nut Brown 10-16H (permit expired)
18029, EXP, Cirque, Roustabout Stout 1-3H (permit expired)
18031, EXP, Cirque, Harpoon Harvest 14-4H (permit expired)
18266, 16, Marathon, Spotted bear USA 21-11H,

EOG wells, Van Hook field 

17280, 1,080, Van Hook 5-11H. 20,123 bbls in first 27 days. 1 sec.
17463, 825, Van Hook 3-25H. 66,786 bbls in 131 days. 1 sec.
17613, 690, Van Hook 2-24H. 78,562 bbls in 134 days. 1 sec.
17619, 1,571, Van Hook 6-14H
17938, PNC, Van Hook 9-22H
17992, 711, Liberty 4-13H (wildcat)
18065, 369, Liberty 100-26H (wildcat)
18066, 515, Liberty 101-12H (Parshall),
18101, Liberty 2-11H, 209, Parshall. 78K in first full year
18504, 2,195, (taken from Slawson's canceled permit); 200K in 7 months!
18825, 951, Van Hook 8-36H, 105K in 5 months
18827, 732,  Liberty 10-36H, 
18828, 1,066, Liberty LR 16-36H,
18884, 625, Liberty 23-12H, 
18971, 894,  Liberty 09-23H, 
18319, 1.565, Van Hook 11-02H,150K in 10 months

Other wells, Van Hook field (see also Slawson/Big Bend or Van Hook) 
16855, Slawson, 952, Prowler 1-16H
16872, Slawson, Nightcrawler 1-17H, 514, spudded 11/09; tested 5/09; 123K
16997, Whiting, 2,625 
17349, Marathon, 929, Voyager 1-28
17459, Slawson, Bandit 1-29H
17504, Slawson, 825 Hoist 1-33H
17505, Slawson, 309, Wolf 1-4H
17710, Hess, 206 EN-Ritzke-158-93-1522H-1
17736, Ballantyne, 0 (dry), Heller 8-31
18119, Slawson, 1,274, Tempest 1-14H
18153, Marathon, 647, Brodahl 31-25H, 2 sec
18170, Slawson, 1,382, Cannonball 1-27H
18188, Slawson, 1,106, Genesis 1-13H, 1 sec 
18251, EOG, 1,585, 60k in less than 3 mos, TFS, Van Hook 100-15H
18327, Slawson, 898, Tarantula 1-16H
18331, Slawson (Questar), 1,575, Fed 1-34-35H-152-92
18504, EOG/Slawson, 2,195, permit canceled; taken by EOG, Van Hook 7-23H, 289,091 bbls in first year!
18735, Dakota-3/Zenergy, 1,936, Dakota-3 State of ND 10-3H
18737, Dakota-3/Zenergy, 1,034, Dakota-3 Mason 2-11H, 1,034,
18749, Slawson, 502, Osprey Federal 1-26-35-30H, 75K in 8 months
18750, Slawson, permit 24 Feb 10, Shad Rap Federal 1-2-3H, 439,(1,546 - 24-hour flowback); 73K in 8 months
18754, Dakota-3/Zenergy, 2,756, Van Hook, Dakota-3 Olson 1-12H, 54K in 5 months
18794, Dakota-3/Zenergy, Van Hook, Dakota-3 Elk 16-21H
18825, EOG, Van Hook 8-36H, 951, spudded 5/10; tested 7/10; 200K in less than a year; 951
18827, EOG, Van Hook, Liberty 10-36, 732, 17K in February, 2011
18828, EOG, Van Hook, Liberty LR 16-36H, 1,066, 85K in 5 months
18877, EOG, Van Hook, Liberty 103-13H, 541,
18884, EOG, Van Hook, Liberty 23-12H, 625,
18924, Slawson, Van Hook, Vixen Federal 1-19-30H, 1,361, 60K in 4 months
18925, Slawson, Van Hook, Phoenix 1-18H, 1,521
18955, Slawson, Van Hook, Nightcrawler 2-17H, 2,278,
18970, Slawson, Van Hook, Pike Federal 1-3-2H, 1,594, 134K in 8 months
18971, EOG, Van Hook, Liberty 09-23H, 894,
18979, EOG, Van Hook, Liberty LR XX-23H. According to this message board, Liberty LR 14-23H is on a 1600-acre spacing unit. This will require a 2.5 mile horizontal lateral. It looks like it will be spudded in late summer/autumn, 2010. PNC
19010, Slawson, Van Hook, Armada Federal 1-14-13H, 847, 95K in 6 months
19018, EOG, Van Hook, Van Hook 15-15H, 927, 139K in 9 months
19047, Slawson, Van Hook, Revolver 1-35H, 1,770,

KOG wells, many in Van Hook field; some wildcats
50% working interest; partner: XTO
17981, 1,661, Two Shields Butte 16-8H; 144K in first 18 months

18022, 711, Two Shields Butte 16-8-16H; 76K in first 18 months
18051, 1,309, Two Shields Butte 14-33-28H, Dec 7, 2009; 130K in first 16 months
18107, 903, Two Shields Butte 14-33-6H, Dec 11, 2009; 64K in first 15 months
18517, 1,595, Two Shields Butte 2-24-12H, Dec 14, 2009, wildcat
18518, conf, Two Shields Butte 3-24-12H, Dec 15, 2009, wildcat

Moccasin series, KOG
60% working interest; partner: a private company
17706, 604, Moccasin Creek 16-34-2H, 54K in first 20 months
17847, 1,274, Moccasin Creek 16-34H, 101K at 2 years
18261, 1,260, Moccasin Creek 16-3H, 72K in first 9 months
18295, 1,419, Moccasin Creek 16-3-11H, 132K in 18 months
18344, 1,370, Moccasin Creek 13-34-3H; 56K in first 6 months
18656, 2,035, Moccasin Creek 13-34-28H, 144K in 10 months
18707, 1,713, Moccasin Creek 13-34-28-1H; 92K in first 15 months


Other Moccasin Creek, non-KOG
18753, 1,594, Enerplus/Zenergy, Henry Bad Gun 8D-5-1H, 134K in first 5 months
18752, 2,194, Enerplus/Zenergy, Henry Bad Gun 17A-20-1H, 124K in first 5 months


These three wells, Tall Bear series, all wildcats

17547, Permit expired
17495, Permit expired
17003, Tall Bear 16-15-16H, Not Economic, Dec 18, 2009 
Comment: the Tall Bear 16-15-16H, permit 17003, was a wildcat drilled to explore eastern edge of KOGs acreage; it's IP was 100, but considered not economic.

Charging Eagle series

17764, 769, Charging Eagle 1-22-23H,  short lateral,55K in first 14 months
17600, 1,187, Charging Eagle 1-22-10H, long lateral, 84K in first 14 months
The wells are both spudded in section 22, but the short lateral goes east to section 23; and the long lateral (17600) goes north through sections 15 and 10. These wells are on same pad: they are 50' from each other.

Whiting Lateral Targeting the TFS (from an uncompleted Bakken well)

16387, 376, Ron Olson 31-1HCE, 1-155N-97W, Williams County; 25K in first 7 months

Comment: this is an interesting one. On December 2, 2009, NDIC reported that this well was renamed (previously: Ron Olson 31-1H. This well apparently was never completed by Marathon. Whiting has it now and the it has been suggested that the "CE" stands for "casing exit." It is being said that the "casing exit" will target the TFS, and that the work will begin January 2, 2010.  The well is about 4.5 miles southeast of Ray, Williams County. 

T154N-91W / Sanish ("owned" by Murex and Whiting) (cumulative as of 1/11)

Reason to watch this township: WLL reports biggest IP to date: 4,761 boepd (section 27)
Murex has monster well in this section: 35,000 bbls/month for one year; incredible!

16839, Murex, section 36, 864 bopd (spudded Nov 07; cumulative 253K bbls; $20.5 million as of Sep 09); Jacob Daniel, update March, 2010;
17022, Murex, section 3, 123 bopd, 162K in 3 years
17080, Whiting, Niemi 44-22H, section 22, 2,201, smack dab between two monster wells
17081, Whiting, section 14, 3,311 bopd, 448K in 30 months; s8/08; t10/08; cum 491K 11/11
17092, Whiting, section 34, 3,027 bopd, 719K in 30 months
17154, Murex, section 11, 221 bopd, Shannon Duane 11-2H, 270K in 30 months
17263, Murex, section 25, 3,124 bopd (monster well; 35,000 bbls/month): Chandler James 25-36H; s7/08; t10/08; cum 802K 11/11

17338, Fidelity, section 24, 352 bopd, 217K in 18 months
17612, Whiting, Maki - 11-27H, section 27, 4,761 bopd -- record IP -- Maki; 423K in first 14 months (at $50/bbl = $21 million in  first year); s8/09; t10/09; cum 880K 9/19;
17841, Murex, section 1, Clifford Gene 1-12H, 602, 344K in 2 yrs; cum 675
K 9/19;
17872, Whiting, section 34, Littlefield 12-34H, 1,814, 246K in 1 year, Sanish; cum 719K 9/19;
18006, PNC, Whiting, section 17, Braaten 11-17H,
18085, Whiting, Jones 11-8H, section 8, 1,370, spudded 8/09; tested 10/09; cum 394K 9/19;
18176, Whiting, section 4, TTT Ranch 43-4H, 1,731, spudded 11/09; tested 2/10; cum 405K 9/19;
18200, 1,658, Kraken/Fidelity, section 24, Kinnion 24-13H, t9/10; cum 693K 9/19; next to Murex monster well, #17263;

 17263; Murex, CHandler James 25-36H; spudded 6/10; tested 9/10; 154K; cum 1.151096 million bbls 9/19;

18209, Murex, 1,380; spudded 8/09; tested 11/09; 237K; still producing 6K/month 1/11; cum 637K 9/19;
18213, Whiting, section 28, Platt 44-28H, 3,609, 254K in 18 months; s9/09; t12/09; cum 567K 9/19;
18238, Murex, section 2, Grace 2-11H, 641 (323); cum 527K 9/19;
18244, Whiting, section 21, Ness 44-21H, 3,014, 176K in first full year; 11/09; t1/10; cum 555K 9/19;
18247, Whiting, section 16, Sikes State 44-16H, 2,140, 175K in first full year; cum 567
K 9/19;
**18298, Whiting, section 33, Kannianen 44-33H, 3,422, spudded 11/09; tested 1/10; 316K in 18 months; cum 702K 9/19;


18373, Murex, section 3, Joyce 3-10H, 887, 136K in 14 months; 397K 9/19;
***18408, Murex, section 25, Amber Renee 25-36H, 1,945, right next to Jacob Daniel (#16839) above, 476K as of Jun 30, 2011; 821K 11/13; TA

**18409, Whiting, section 14, Kinnoin 21-14H, infill, 2-sec, 2,559, 287K in 15 months; cum 628K 9/19;