Price Paid for North Dakota Oil: Good News

Are you curious about the price paid for North Dakota oil compared to that paid for the "gold standard," west Texas crude? If you are curious, click here. It sounds like North Dakota oil is priced about the same as west Texas crude (see "spot price of oil" in the sidebar to the right); the only difference appears to be the cost to ship the oil to Cushing, Oklahoma.

The shipping cost for North Dakota oil should go down this year based on improved capacity, but I doubt this will last long if more pipelines are not put in. Production and transport capacity should balance out this year at about 400,000 barrels/day.

The New York Mercantile Exchange (NYMEX) contract for oil is based on the price of west Texas crude.

Continued Confusion: Bakken and Three Forks Sanish -- the Definitive Answer -- February 17, 2010

Summary

The "Bakken Pool" is an administrative term that includes the Bakken formation and the Three Forks Sanish formation.

The NDIC website shows the accumulated totals of oil production from the "Bakken" and the "Bakken/TFS."  I assume the Bakken is limited to the Bakken formation in the "Bakken Pool"; and, the "Bakken/TFS" is limited to the TFS formation in the "Bakken Pool."

Geo News, July, 2010: the Bakken potential.

The Original Post

I have posted this several times: there is confusion over "Bakken" vs "Three Forks Sanish." This is the best answer I have seen: the NDIC and the USGS consider the oil coming from the "Bakken" and the "Three Forks Sanish" to be coming from the "Bakken Pool." That's why on the daily activity report, the pool is always listed as "Bakken" when the well targets the Bakken formation or the TFS formation. [Update, October 14, 2010: click here to see an exception. Is this new, evolving, or did I miss similar wells earlier?]

And that's the key: "formation." The Bakken formation is composed of the Upper, Middle, and Lower Bakken members/units, all separate strata. Likewise, the Upper TFS and the Lower TFS are separate strata.

Formations, members/units, and strata are all geologic terms.

On the other hand, "Bakken Pool" is an administrative term. The USGS and the NDIC prefer to lump these five (5) formations together as one pool (see below -- it makes sense).

The five formations can be very, very thin in some areas, and it is very possible a) the geologist is not 100% sure which formation the tip of the drill is in; b) a long lateral may pierce more than one formation; and/or, c) the administrative paperwork to date may not always be "perfect," and it might be difficult, expensive, and even unnecessary to sort out exactly what formation the lateral is in, especially when the formations may communicate in some localities.

The NDIC defines the Bakken Pool as 50 feet above the upper Bakken limit and 50 feet below the lower Bakken formation line. One needs to see the "completion report" to see which formation(s) was (were) targeted. Most of the reports linked at my site do not include the completion report, but the report that is provided after the well comes off the confidential list. [Update, July 6, 2013: for the past year, operators have been requesting, and NDIC has been granting alterations to the definition of the stratigraphic limits of the Bakken/Three Forks.]

*****

The Geology

The stratigraphic nomenclature varies, for example:

Southeastern Saskatchewan

Periods: Mississippian and Devonian

Groups: Three Forks and Saskatchewan

Formations: Bakken, Big Valley, Torquay (the Three Forks group)

Formation: Birdbear (the Saskatchewan group)

North Dakota

Periods: Mississippian and Devonian

Groups: "Bakken Pool" and Jefferson

Formations: Bakken and Three Forks (the "Bakken Pool" group)

Formation: Birdbear (the only formation in the Jefferson group)

*****

Of course, the next question that arises is this: at the NDIC website, cumulative oil production is broken down by "formation" on one of the pages. The NDIC has broken out two "formations" as 1) the Bakken; and 2) the Bakken/TFS.  It appears for North Dakota this is logical: as noted above, the "Bakken Pool" group is composed of the Bakken formation and the Three Forks Formation. But it is confusing that they label it as the "Bakken/TFS." They don't do that with other formations, such as the Red River which is part of the Madison Group. 

*****

Here's another recent discussion regarding this issue; the discussion begins well down into the thread once you get there. 

I have recently posted that EOG may be planning to drill three wells from one pad (in the Parshall), the wells targeting, respectively, the Middle Bakken, the Upper Three Forks Sanish, and the Lower Three Forks Sanish.

Interestingly enough, the 1990 boom in North Dakota targeted the Upper Bakken.

So, there you have it. Within the "Bakken," it sounds like there could be five formations: Upper, Middle, and Lower Bakken; and, the Upper and Lower Three Forks Sanish (more correctly referred to as unit 1- 6).

*****

Note: one of the pioneers in the Bakken, Marathon Oil (MRO), considers the "Bakken" to be composed of five distinct units: the Lodgepole; the upper, middle and lower Bakken; and, the Three Forks (Sanish).

*****

On another note, the Spearfish/Madison Pool lies directly above the Bakken Pool. The Spearfish/Madison Pool is much thicker, extending from the shallower Spearfish, all the way down to the Madison, which lies directly above the Bakken formations. Back in 2006, Julie LeFever published an article which included data to suggest that the Madison Pool does not "leak" oil into the underlying Bakken. [October 31, 2017: that link is now broken. This PDF discusses the Bakken as "we" knew it back in 2005. The html is at this link.]

*****

According to a research paper by Roy Neset, Jr., Department of Geosciences, Fall, 2009, the source rocks for the middle Bakken member are the upper Bakken shale and the lower Bakken Shale; the source rock for the Three Forks Sanish member is the lower Bakken shale. Neset provides data to suggest that the lower Lodgepole Formation, which overlies the upper Bakken shale source rock, could be an economically viable oil-producing zone. An abbreviated synopsis of that research can be found here.

Too Many To Keep Track Of: This One -- Shell 3-05H

This is just one of many wells that keep getting reported. Too many great wells to keep track of. But I link what I can on my "new wells reporting" and "wells to watch" page.

This one:  Shell 3-05H (51-153-89) -- $5 million at the wellhead in five months. And this is just one well among hundreds.

Rollefstad 1-3H, Antelope Field, #18159, 16 days, 16 frac stages

The Rollefstad 1-3H has generated a lot of interest. "Rollefstad" is currently the number one item searched on Google regarding the Bakken by those who come to this website. That's cool.

But unbeknownst to me was something else that popped up regarding the Rollefstad 1-3H. While updating the Charlson oil field, I noted that the Rollefstad was in the top ten oil wells that targeted the Three Forks Sanish with regard to cumulative oil production over time. In the first three months, this well produced a cumulative 50,000 barrels ($60/bbl = $3 million). At this rate, the well should be paid for in a couple more months. (Disclaimer: past production results do not predict future production results.)

Just out of curiosity, I went back and looked at its IP. The IP for this very good well was a mediocre (by current standards) 754 bopd. Especially considering it was a CLR well. This is from the CLR press release (Sept 10, 2009): "The Company noted that the Rollefstad 1-3H was drilled to total depth of 20,904 feet in 16 days and was stimulated in 16 stages using the "perf and plug" technique. Final completed well cost is expected to be less than $5 million."

And not only that, this IP was from a "long lateral." Long laterals with IPs less than a 1,000 bopd just don't capture anyone's attention any more.

As long as I'm rambling, this well was spudded July 17, 2009, and it was completed August 30, 2009, according to the NDIC document. I don't think it took 44 days to complete drilling. I think the date to completion included the time to complete fracture stimulation.

The NDIC document also noted that the well targeted the "Sanish" pool, which I assume is the Three Forks Sanish. It does not state whether it was the "upper TFS" or the "lower TFS," formations that are being separated out by other producers. 

Okay, some more rambling. Look at the GIS map.

18159, CLR, Rollefstad 1-3H, Antelope Field, 754, TFS pool
18224, CLR, Hendrickson 1-36H, Elm Tree Field, 1,990, TFS pool, just a 1/2 mile from the Rollefstad
17609, Hess, AN-Norby-152-94-0409H, Antelope, 504, TFS pool, just 1900 ft west of the Rollefstad

I've opined about the IPs being reported by Hess in the past, although the cumulative amount of oil produced by the Norby well looks pretty good.

Charlson Field Update

On every post on the Million Dollar Way, and especially as the notes get longer, there will be typographical errors and factual errors. I depend on readers to notify me of errors. If the information is important to you, go to the original source. I do not update/revise/edit "original posts" (except for spelling errors and obvious typographical errors) so they may be in error; I was learning as I went along; the Bakken is dynamic. One exception: I often update production data for wells noted in the "original post."

Sources:

• bakkenshale.com: http://bakkenshale.blogspot.com/2007/11/hunts-unconventional-hidden-gem-at.html. 

Updates

October 12, 2014: file report for #26228 provides nice discussion of how oil is commingled/measured/sold and for natural gas about how it is measured, sold, flared.

August 24, 2012: BR reports another huge well in the Charlson, a middle Bakken well, a short lateral; only 11 stages:

• 20636, 1,363, BR, Brazos 24-34H, middle Bakken, Charlson, short lateral, t6/12; cum 5K 6/12; the horizontal leg was drilled in four days; 10 stages; 1 million pounds sand; half-million pounds ceramic;  the hole was spud 11/7/11 but no drilling was done between 11/17/11 and 11/29/11; they reached vertical depth on 11/29/11; the horizontal total depth was reached in four days; this is essentially an 8-day well; t6/12; cum 167K 5/17;

July 2, 2011: Michael Filloon talked about the Eagle Ford (South Texas) commanding higher lease bonuses due to multiple payzones, it is interesting to look at multiple payzones in the Williston Basin. For example, a Madison well:

• 1171, PA/333, Petro-Hunt, CMNU B-205, spudded 8/25/1956; 754,319 bbls (no production since September, 2010, and now inactive. Interestingly enough, it appears that it was still producing about 300 bbls/month for years when it was taken off-line; something tells me we will see this well active again -- perhaps as a Bakken), a Madison well
• One should also look at the Silurian formation in the Charlson field
  

May 4, 2011: 18487, 2,280, DNR, Thompson 31-11NWH, Charlson, Bakken, t3/11; cum 165K 5/17;

January 21, 2011: 18814, 1,754, SM, Wilson 8-20H, Charlson, Bakken, t10/10; cum 260K 5/17;

March 16, 2010:  St Mary granted three permits (18814, 18815, 18816; Wilson 8-20H, Norby 9-20H, Norby 16-20H) -- all three in section 20-153N-95W.  The three permits are in an unusual configuration; too far away to be on same pad but all aligned perfectly north-south along the eastern section line:

• 18814, 1,754, Oasis/St Mary, Wilson 8-20H, t10/10; cum 260K 5/17;
• 18815, 853, Oasis/St Mary, Norby 9-20H, t10/10; cum 301K 5/17;
• 18816, 1,415, Oasis/St Mary, Norby 16-20H, t10/10; cum 251K 5/17;

Permits

2017 (none as of February 26)
33817, loc, USA 153-95-23D-14-1HS,
33814, loc, USA 153-95-23D-14-1H,
33813, loc, USA 153-95-23D-14-2H,
33812, loc, USA 153-95-23D-14-3H,


2016 (the list is complete)
33142, conf, Petro-Hunt, Thompson
33141, conf, Petro-Hunt, Thompson
32696, conf, Petro-Hunt, USA
32533, conf, Petro-Hunt, USA
32532, conf, Petro-Hunt, USA
32531, conf, Petro-Hunt, USA
32530, conf, Petro-Hunt, USA
32529, conf, Petro-Hunt, USA

2015 (the list is complete)
32165, conf, Petro-Hunt, USA
31968, conf, Petro-Hunt, Klevmoen Trust
31967, conf, Petro-Hunt, Klevmoen Trust
31794, conf, Petro-Hunt, USA
31793, conf, Petro-Hunt, USA
31792, conf, Petro-Hunt, USA
31791, conf, Petro-Hunt, Phelps
31790, conf, Petro-Hunt, USA
31789, conf, Petro-Hunt, USA
31500, conf, Petro-Hunt, USA
31499, conf, Petro-Hunt, USA
31498, conf, Petro-Hunt, USA
31497, conf, Petro-Hunt, USA
31493, conf, Petro-Hunt, USA
31492, conf, Petro-Hunt, USA
31491, conf, Petro-Hunt, USA
31490, conf, Petro-Hunt, USA
30715, 2,384, XTO, State 11X-16MB4, one section; t1/16; cum 142K 5/17;
30714, 1,864, XTO, State 11X-16TF4, one section; t2/16; cum 110K 5/17;
30713, 1,823, XTO, State 11X-16MB5, one section, t2/16; cum 110K 5/17;
30685, TATD,  Petro-Hunt, USA 153-95-9C-4-3H,
30569, conf, Petro-Hunt, USA

2014 (the list is complete)

30369, SI/NC -- TATD, Petro-Hunt,
30368, SI/NC -- TATD, Petro-Hunt,
30183, 724, Petro-Hunt, Sherven Trust 153-95-27A-7HS, t10/16; cum 88K 5/17;29978

29978, conf, Petro-Hunt, Van Hise Trust
29091, conf, Petro-Hunt, USA 153-95-23C-14-5H,
29090, conf, Petro-Hunt, USA 153-95-23C-14-6H,
28227, conf, Petro-Hunt, CMNU C-205X,
28155, 1,784, XTO, Gilbertson 34X-26G, t11/14; cum 155K 5/17;
28154, 1,361, XTO, Gilbertson 34X-26BXC,  t11/14; cum 132K 5/17;
28018, 835, Petro-Hunt, USA 153-95-22D-15-4H, t10/16; cum 75K 1/17;
28017, 830, Petro-Hunt, USA 153-95-22D-15-5H, t10/16; cum 75K 1/17;
28016, 912, Petro-Hunt, USA 153-95-22D-15-1HS, 37 stages; 4.7 million lbs, t11/15; cum 366K 5/17; this well is still producing 15,000 bbls/month; not on a pump as of 5/17;
28015, 816, Petro-Hunt, USA 153-95-23C-14-2HS, t10/16; cum 77K 1/17;
27928, 1,543, XTO, Gilbertson 11X-26F, t11/14; cum 96K 12/16;
27927, 1,060, XTO, Gilbertson 11X-26B, t11/14; cum 92K 12/16;
27926, 844, XTO, Gilbertson 11X-26FXG, t11/14; cum 91K 12/16;
27918, 1,167, Petro-Hunt, USA 153-95-4B-9-1HS, t12/14; cum 316K 5/17;
27679, 1,678, XTO, Thompson Federal 41X-17-TF2, t12/14; cum 182K 12/16;
27436, conf, XTO, State 154-94-31C-32-1HS,
27376, 1,578, Petro-Hunt, USA 153-95-27D-6H, t2/15 cum 176K 1/17;
27375, 984, Petro-Hunt, Sherven Trust 153-95-27D-5H, t2/15; cum 118K 1/17;

2013 (list is complete for 2013)
27355, 1,241, XTO, Thompson 41X-17MB3, t12/14; cum 141K 12/16;
27209, DRY, Petro-Hunt, USA 153-95-4B-9-2HR,
27208, 2,262, Petro-Hunt USA 153-95-4B-8-2HS, t12/14; cum 418K 5/17; producing 6,000 bbls/month; not on a pump as of 5/17;
27056, 1,803, Petro-Hunt, Van Hise Trust 153-95-28D-21-2HS, 4 sections, t9/14; cum 191K 10/15;
27055, 1,306, Petro-Hunt, Van Hise Trust 153-95-28D-21-1HS, 3rd of 5 wells drilled on this site; average gases held around 342; high gases just above 3,277 units; 2,560 acres; middle Bakken; t9/14; cum 325K 5/17; on a pump
26701, PNC, Petro-Hunt, Jellesed 153-95-16D-17-5H,
26700, PNC, Petro-Hunt, Jellesed 153-95-16D-17-4H,
26699, PNC, Petro-Hunt, Jellesed 153-95-16D-17-3H,
26446, dry, Petro-Hunt, USA 153-95-4B-9-2H,
26419, 2,904, BR, Archer 14-25TFH, t2/14; cum 277K 10/15;
26374, 992, SEM Energy, Loraine 1X-20H, t2/14; cum 186K 10/15;
26267, 1,672, Petro-Hunt, Van Hise Trust 153-95-28D-21-6H, t9/14; cum 358K 5/17;
26266, 2,476, Petro-Hunt, Van Hise Trust 153-95-28D-21-5H, t9/14; cum 195K 10/15;
26265, 2,168, Petro-Hunt, Van Hise Trust 153-95-28D-21-4H, t9/14; cum 269K 2/17;
26228, 1,097, SM Energy, Wilson Federal 1X-20H, a Three Forks well, formation tops (middle Bakken, 10,319 feet; lower Bakken shale, 10425 feet = 106 feet); (19 days to drill; 26 stages, 3.2 million lbs sand/Onxy over 3 days, t2/14; cum 264K 5/17;
26214, 2,122, Petro-Hunt, USA 153-95-22C-15-3H, t1/14; cum 250K 10/15;
26206, 1,077, Petro-Hunt, Sherven Trust 153-95-27B-2H, t1/14; cum 169K 10/15;
26205, 1,514, Petro-Hunt, Sherven Trust 153-95-27B-3H, t2/14; cum 201K 2/17;
26007, 2,592, BR, Archer 24-25TFH, t2/14; cum 89K 8/14;
26006, 2,928, BR, Archer 24-25MBH, t2/14; cum 95K 8/14;
25962, 2,592, BR, Archer 34-25TFH, t2/14; cum 61K 8/14;
25961, 2,880, BR, Archer 44-25MBH, t2/14; cum 89K 8/14;
25960, 2,312, BR, Archer 44-25TFH, 30 stages, 1.3 million lbs sand/ceramic; formation tops (middle Bakken, 10463 ft; Lower Bakken Shale, 10529 = 66 ft); very low gas units; t1/14; cum 92K 2/17;
25684, 2,966, BR, Sunline 31-1TFH-6SH, 4 sections, t1/14; cum 48K 8/14;
25683, 1,764, BR, Rising Sun 31-1TFH-6NH, 4 sections, t12/13; cum 40K 8/14;
25682, 2,040, BR, Rising Sun 31-1TFH-7NH, 4 sections, t5/14; cum 54K 8/14;
25681, 2,926, BR, Sunline 31-1TFH-7SH, 4 sections, t12/13; cum 185K 2/17;
25680, 2,544, BR, Washburn 42-36TFH, t1/14; cum 121K 8/14;
25679, 2,800, BR, Washburn 41-36MBH, t1/14; cum 121K 8/14;
25678, 2,976, BR,Washburn 41-36TFH, t1/14; cum 128K 8/14;
25665, 2,952, BR, Washburn 44-36TFH, t12/13; cum 99K 8/14;
25656, 1,104, BR, Washburn 43-36MBH, t1/14; cum 118K 8/14;
25655, 2,856, BR, Washburn 43-36TFH, t12/13; cum 325K 5/17;

2012
24050, conf, Petro-Hunt,
24049, conf, Petro-Hunt,
24048, conf, Petro-Hunt,
24047, conf, Petro-Hunt,
24046, 1,661, Petro-Hunt,State 154-94-31C-32-2H, t1/16; cum 164K 2/17;
24045, conf, Petro-Hunt,
23803, 1,301, Petro-Hunt, USA 153-95-1B-7-3H, t11/14; cum 132K 10/15;
23443, PNC, Petro-Hunt,
23442, PNC, Petro-Hunt,
23441, 1,115, XTO, Thompson 21-11SWH, 1 section,  t5/13; cum 55K 8/14;
23440, 2,030, XTO, Thompson 21-11SH, 1 section, t2/13; cum 93K 8/14;
23439, 538, XTO, Thompson 21-11SEH, 1 section, t5/13; cum 50K 8/14;
23080, 1,022, Petro-Hunt, USA 153-95-18B-2H, 1 section, t3/13; cum 85K 8/14;
23079, 817, Petro-Hunt, USA 153-95-18B-1H, 1 section, t3/13; cum 114K 8/14;
22862, 1,532, XTO, Madson 11-33SWH, 1 section, t10/12; cum 138K 8/14;
22861, 1,594, XTO, Madson 11-33SH, 1 section, t9/13; cum 133K 8/14;
22860, 1,471, XTO, Madson 21-33SEH, 1 section, t10/12; cum 138K 8/14;
22701, 1,133, SM Energy, Norby 9X-20HB, t8/12; cum 195K 8/14;
22700, 1,171, SM Energh, Norby 9X-20HA, t8/12; cum 160K 8/14;
22477, 881, XTO, Grimestad 34-33NEH, 1 section, t7/12; cum 94K 8/14;
22476, 1,179, XTO, Grimestad 34-33NWH, 1 section, t7/12; cum 165K 5/17;
22355, PNC, Denbury Onshore, Swenson 36-33SH, Charlson,

2011
21716, 943, Petro-Hunt, Van Hise Trust 153-95-28C-21-2H, t12/12; cum 217K 8/14;
21668, dry/SI/NC, BR, Uberwachen 22-34, a Birdbear well, formation tops (middle Bakken, 10227 feet - lower Bakken shale, 10269 feet = 42 feet; middle Three Forks, 10336 - Three Forks, 10299 = 37 feet); an observation well, no production planned
21512, PNC, Petro-Hunt, USA 153-95-1C-7-3H,
20740, 1,637, XTO, Swenson 41-33SEH, 1 section, t8/11; cum 196K 8/14;
20637, 1.980, BR, Llano 34-34H, 1 section, t6/12; cum 172K 8/14;
20636, 1,363, BR, Brazos 23-34H, 1 section, t6/12; cum 113K 8/14;
20355, 1,127, Petro-Hunt, USA 153-95-1A-7-2H, t2/13; cum 74K 8/14;
20342, 1,430, Petro-Hunt, USA 153-95-4B-9-1H, t11/11; cum 616K 10/15;

2010
19979, 817, Petro-Hunt, USA 153-95-22C-15-1H, t7/11; cum 489K 5/17;
19864, 1,333, Petro-Hunt, Klevmoen Trust 17D-4-3H, 1 section, t7/11; cum 308K 1/17;
19845, 1,084, Petro-Hunt, Van Hise Trsut 153-95-28C-21-1H, F, t8/11; cum 485K 5/17;
19625, PNC, Denbury Onshore, Charlson 24-34H,
19619, PNC, Denbury Onshore, Charlson 24-33H,
19545, PNC, Denbury Onshore, Gilbertson 34-26NWH,
19544, 830, XTO, Gilbertson 34-27NEH, 1 section, t6/11; cum 166K 8/14;
19464, PNC, Denbury Onshore, Swenson 31-33SEH,
18816, 1,415, SM Energy, Norby 16-20H, t10/10; cum 228K 10/15;
18815, 853, SM Energy, Norby 9-20H, t10/10; cum 268K 10/15;
18814, 1,754, SM Energy, Wilson 8-20H, t10/10; cum 231K 10/15;
18703, 888, XTO, Gilbertson 11-26H, 1 section, t6/10; cum 191K 8/14;
18678, 1,174, XTO, Charlson 34X-12B, 1 section, t10/11; cum 128K 8/14;
19991, PNC, Petro-Hunt, USA 18D-4-2H
 

Original Post

Charlson Field

Geologists, operators and drillers talk about targeting a certain formation, such as the Bakken or the Three Forks Sanish. However, when completed, the NDIC reports which pool the wells targeted which is an administrative term, and not a geologic formation term.

The NDIC administratively places all Bakken and all TFS wells in the "Bakken Pool." When the daily activity report states the "Bakken Pool" you cannot know from that which geologic formation was targeted; that information comes from other sources including press releases from the oil company operating the rig.

The "Bakken" formation is divided geologically into three formations, the Upper, the Middle, and the Lower. The Upper Bakken was the target during the 1990's boom; the Middle Bakken is the target now.

The Three Forks Sanish is divided into the Upper and the Lower. I forget, but I believe I first read it from an EOG conference call (it could have been Hess), the drillers in the current boom are targeting the Upper and the Lower Three Forks Sanish.

One can see the cumulative oil and gas production from HORIZONTAL wells by formation at the NDIC site. Click here and use the drop down menu to find the formation you are interested in.

That was all background to explain why I was interested in the Charlson field.

The Charlson field: 

My introduction to the Charlson occurred when I first became interested in Denbury.

The Charlson field is unique among many of the fields I follow because it appears that the formation being targeted in the current boom in the Charlson is almost exclusively the Three Forks Sanish.

The Charlson is a very small field, but historically, very, very active. It is only 48 sections, not even two full townships in size, but yet when you go to the GIS map server, it is so full of old vertical wells, it's hard to see "new" activity.

The Charlson is directly west of the Sanish oil field, on the other side of the river. There are no towns or hamlets in this small field.

Currently  there are 20 producing horizontal wells (and lots of vertical wells, as well as many abandoned wells), 8 wells on the confidential list, and one well being drilled.

But this is an interesting bit of trivia:

The most successful well to date in North Dakota sits in the Charlson: file #16059, the USA 2D-3-1H, a Petro-Hunt, LLC, well that was spudded in October, 2006. To date, it has produced 915,000 barrels of oil. That well targeted the Three Forks Sanish. [At $60/barrel = almost $55 million in about 3 years]. UPDATE: USA 2D-3-1H hit a record this past June, 2010: one million bbls of oil cumulative. See comment at this post. 

16059, 729, Petro-Hunt, USA 2D-3-1H, Charlson, t10/06; cum 1.63 million bbls 5/17;

But the USA 2D-3-1H is not the only highly successful well targeting the Three Forks Sanish. Here are some others targeting the TFS (not all in the Charlson):

16424, 700, USA 11B-2-2H, Petro-Hunt, LLC, cum 597K 5/17; spudded Jul 2007, Charlson field
17113, 3,030, Charlson 14X-35H, XTO/Encore, cum 732K 5/17; spudded Oct 2008, Charlson field
16963, 423, USA 35D-1-1H, Petro-Hunt, LLC, cum 728K 5/17; spudded Sept 2008, Charlson field
17147, 2,101, Boucher 41X-21, XTO Energy, cum 795K 5/17; spudded Mar 2009, Hofflund field
17558, 1,368, McGregor 1-15H, CLR, cum 334K 5/17; spudded Apr 09, Lindahl field;
18159. 754, Rollefstad 1-3H, CLR, cum 503K 5/17; spudded Aug 09, Sanish pool, Antelope field

Additional information added after the above was first posted. This is interesting -- note a couple of the wells targeted the Madison:

854, PA/235, Texaco Exploration, Charlson-Madison North Unit C-109, a Madison well, t6/55; cum 156K 8/77;
17625, 889, Petro-Hunt, McKenzie County 6D-4-4H, 1 sec, t11/09; cum 201K 5/17;
17803, PNC, Petro-Hunt, Charlson Madison North Unit B205 XH
18387, 736, Petro-Hunt, USA 10B-2-4H, t7/10; cum 194K 10/15;
18678, 1,174, XTO/Encore, Charlson Federal 34X-12B, t10/11; cum 147K 10/15;
17859, 827, Petro-Hunt, L. M. Thompson 7D-4-4H, 1 section, t7/11; cum 148K 10/15;
18111, 776, Petro-Hunt, Thompson 8D-4-4H, t5/11; cum 226K 10/15;
17400, IA/546, Petro-Hunt, Sherven Trust 28B-2-4H, 1 section, t3/09; cum 227K 10/15;
17799, 457, BR, Guadalupe 11-23H, 1 section, t3/09; cum 180K 10/15;
17221, 111, XTO/Encore, State 11-16H, one section, t2/09; cum 142K 10/15;
18703, 888, XTO/Encore, Gilbertson 11-26H, one section, t6/10; cum 231K 10/15;
18433, 27 (but sundry form shows 108), XTO/Encore, Swenson 31-33SWH, one section, 12 stages; 1.1 million lbs sand/ceramic; t5/10; cum 315K 5/17;
17356, 356, BR, Archer 14-25H, long lateral; t11/08; cum 385K 5/17;
17309, 260, BR, Washburn 44-36H, long lateral; t7/08; cum 114K 10/15;
18814, 1,754, SM Energy/St Mary, Wilson 8-20H, t10/10; cum 231K 10/15;
18815, 853, SM Energy/St Mary, Norby 9-20H, 80,879; t10/10; cum 268K 10/15;
18816, 1,415, SM Energy/St Mary, Norby 16-20H, t10/10; cum 228K 10/15;
19464, PNC, Denbury/Encore, Swenson 31-33SEH
19544, 830, XTO/Denbury/Encore, Gilbertson 34-26NEH, t6/11; cum 195K 10/15;
19545, PNC, Denbury/Encore, Gilbertson 34-26NWH,
19619, PNC, Denbury/Encore, Charlson 24-33H,
19625, PNC, Encore, Charlson 24-33H,