I no longer follow these wells.
Kaiser-Francis was the operator who got the lion's share of the Fidelity wells:
- 24052, 738, Kraken/Kaiser-Francis/Fidelity, Wayne 3-4-33H, Sanish, 4 sections, 4/13; cum 241K 9/19; small jump in production 8/19;
- 24511, 52, Lime Rock Resources/Fidelity, Irene 12-13H-24, Alger, t4/13; cum 131K 9/19; went off line 5/19; back on line and good production, as of 9/19;
December 5, 2015: was waiting to post fracking data -- posted -- can be moved to "Closed" status
- 25467, 1,821, Whiting, Privratsky 11-27PH, Zenith, Three Forks (Pronghorn), 40 stages, 3.04 million lbs, t3/14; cum 196K 9/19;
- 25468, 1,920, Whiting, Privratsky 21-27PH, Three Forks (Pronghorn), 40 stages, 3 million lbs, t3/14;cum 230K 9/19;
- 25469, 2,272, Whiting, Privratsky 41-27PH, Zenith, Three Forks (Pronghorn), 40 stages; 3 million lbs sand; t3/14; cum 232K 9/19;
November 3, 2015: follow up on this re-frack? #20755. Not a re-frack; simply some work on the pad mostly likely. Nothing to see here. This item closed November 3, 2015. But it's still a good well; cum 376K 9/19;
June 17, 2015: I need to complete the January, 2015, dockets.
September 19, 2015:
- Permitted for re-entry: 16439, 373,
MRO, Hecker 21-5H, Murphy Creek, t9/07; cum 301K 9/19; last on-line
11/14; still off-line as of 6/15; back on ACTIVE status on/about 6/15; tracked here; back on line 4/18 and doing very, very well as of 9/19;
- 19294, PNC, Whiting, BSMU 3605, a Madison well;
- #27441 - EOG RESOURCES, INC., PARSHALL 65-14H, NWNW 14-152N-90W, MOUNTRAIL CO., 446 BOPD, 2354 BWPD - BAKKEN
#27442 - EOG RESOURCES, INC., PARSHALL 66-14H, NWNW 14-152N-90W, MOUNTRAIL CO., 394 BOPD, 2376 BWPD - BAKKEN
- 27441, IA/446, EOG, Parshall 65-14H, Parshall, short lateral, t7/14; from the file report, after reaching TD, gas reached a max of 10,000 units as the well began to flow; 25 stages, 7.6 million lbs; cum 122K 10/18; off line 4/19; remains off line 9/19;
- 27442, 394, EOG, Parshall 66-14H, Parshall, short lateral, t7/14; 19 stages, 5.8million lbs; cum 115K 10/18; went off line 1/19; back on line 9/19;
A comment from a reader, received June 27, 2014:
I'm a non-op partner in 143-97 Leroy Petry Oxy well (#26370). One of my buddies got his first check today and along with it was a letter saying OXY is selling part of its assets to Merit Energy. Thought I would pass along. When I get my paperwork I'll let you know; update July 3, 2015 -- still an OXY USA well; Lime Rock;December 1, 2014, 4:44 p.m. CT: for some inexplicable reason, the number of active rigs in North Dakota jumped from 183 on Black Friday, November 28, 2014, to 189 on Monday, December 1, 2014 during some of the most miserable weather ever in the history of the Bakken boom during the late days of November. If the active rig rate holds or actually increases despite the slump in oil prices, one needs to ask the question, why? This could be an unintended consequence of the slump in oil prices, as operators start to circle the wagons and start to drill the better spots to "stay alive." If the marginal shale plays in the US see a decrease in rig counts, some operators to maintain their production or meet their contracts, may start to move their rigs to the better spots. The Bakken is known for a) consistency; b) reliability; c) adequate takeaway; d) improving infrastructure. So we'll see. I will not put this in a stand-alone post for several reasons. [Update, March 20, 2015 -- my irrational exuberance got ahead of me -- rigs plunged; now stand at 107. Update, June 13, 2015 -- my irrational exuberance got way ahead of me -- active rigs have plunged to lowest post-boom record, at 76]]
April 9, 2015: need to get frack data on these two wells
- 28075, 3,255, MRO, Anthony USA 23-14H, Moccasin Creek, 2.5 section-long horizontal; 100% within the middle Bakken; 93% within MOC geology defined target interval; gas max at 1,300 units; 3,840 acres drilling unit; 23,148 feet TD; 43 stages; 4.5 million lbs; t2/15; cum 477K 9/19;
- 28076, 3,255, MRO, Hale USA 23-14TFH, Moccasin Creek, 2.5 section-long horizontal; Three Forks, 100% within the Three Forks Formation; 69% within the MOC geology defined target interval; gas units very, very low; a 1 - 5' intermittent flare near the end of the lateral; 23,148 feet TD; 43 stages; 4.5 million lbs; t2/15; cum 271K 9/19;
- 29727, 2,319, Whiting, Eide 41-13HU, 4 sections, middle Bakken; 30 stages; 3.4 million lbs; seam 22 feet thick?; max gas at 4,697 units, a consistent 2 - 5 foot flare; t2/15; cum 201K 9/19; jump in production, 7/19;
September 11, 2014: several Oasis wells with very short horizontals; in the process of being completed? I had not seen this before (or don't recall); I was incorrect: these are not very short laterals (see explanation at the link); standard long lateral (about 9,300 feet horizontally)
August 2, 2014: a three-section horizontal lateral
- 25959, 732, CLR, Haffner 1-31H, Noonan, middle Bakken; 1920-acre; 50 stages; 7 million lbs, a true 3-section lateral (full sections 19/30/31 - 162-95); background gases "poor"; t3/14; cum 178K 10/18;
- 27522, 4,207, Whiting, Flatland Federal 11-4TFHU, Twin Valley, spacing: 2560-acre; t10/14; cum 478K 10/18; huge jump, 3/19;
November 29, 2014, a huge well;
- 17314, 431, MRO, Brown 24-9H, Killdeer, a 10 - 30' flare for fifty minutes; this is a bit confusing for me, but I believe this well was spud/completed in 2008, but it was re-fracked in August, 2014, and that's why it shows up in today's report; the re-frack data was not yet scanned in; last full month production was in July, 2014; it will be interesting to see what new production numbers are and what the re-frack data is; t8/08; cum 403K 3/19; update here.
- 16529, 100, CLR, Spry 11-13NH, Cedar Hills, a North Red River B well, t8/07; cum 620K 10/18;
Also, later: #18341.
Was this well that produced 30,000 bbls in the first month really canceled by EOG? This will end up being a non-story. See this post. My hunch is that the "30,000" was an error.
Why did they take this great well off-line in July, 2013? A great well to follow periodically.
- 17310, Rosemary Eckelberg 41-26H, 459, 49,138 bbls in 15 months; t8/08; cum 167K 3/19; went back on line 1/14; significant increase in oil production; no explanation in well file;
- 7571, 482/AB, Hess, Reitsch NCT-2 4, Blue Buttes, a Silurian well, t4/81; cum 1.0062 million bbls 7/17;
- 20879, 2,709, Bruin/HRC, Fort Berthold 147-94-1A-12-2H, McGregory Buttes, t1/14; cum 491K 3/19; off-line as of 9/18; see this note, 10/18;
- 19169, 685, HRC, Carlson 1-11H, Strandahl, northwest of Williston, t2/10; cum 82K 3/19; this was GEOI's first completed Bakken well at a cost of $5.6 million; remains a lousy well (3/19);
- 18362, 641, MRO, Uran 31-2H, Reunion Bay, t6/10; cum 343K 3/19; 15 stages, 2.6 million lbs; no explanation why it was taken off-line for four months in mid/late-2013, and then came back with much better production;
- 10217, 80, Legacy Reserves, Spring Creek Federal 6, Mondak, a Madison well, t10/83; cum 157K 4/14; at $50/bbl, this represents $7.7 million in crude oil; at $5/MCF natural gas, that represents $500,000 in natural gas. It would have cost several million dollars to put in a natural gas pipeline, assuming that regulators would even have allowed a pipeline for one well this remote. Spud in 1983, this well is flaring almost no natural gas but a very, very tiny bit is being flared. I cannot explain why it can go years producing oil but flaring no natural gas, and then back to flaring small amounts. Whatever meager amounts are being produced, none is being sold. [Update: I believe the rules state that the wells have to be producing at least 200 bbls of crude oil to be affected by new flaring rules, or about 6,000 bbls per month. This well is producing only 350 bbls of crude oil per month so it is not affected by new flaring rules.]