I track the Bridger wells here, though that page has not been updated in a long time.
The well:
- 17089, 400, CLR, Bridger 44-14H, Rattlesnake Point, 33-025-00731, a very nice well; t4/08; cum 247K 1/18;
As an aside, when I first started following the Bakken, I was told by a Bakken "expert" at another discussion group, that a North Dakota well could only be on the confidential list once. So much to learn. And I probably only know 1% of all there is to know.
So, what's going on? I don't know.
Let's explore together. As noted, the well has been producing since 2008. The first six months of production data:
BAKKEN | 9-2008 | 23 | 3517 | 3107 | 1041 | 3092 | 3092 | 0 |
BAKKEN | 8-2008 | 31 | 4164 | 4350 | 620 | 3418 | 3418 | 0 |
BAKKEN | 7-2008 | 31 | 5446 | 5346 | 1191 | 4035 | 4035 | 0 |
BAKKEN | 6-2008 | 30 | 4233 | 4102 | 668 | 3098 | 3098 | 0 |
BAKKEN | 5-2008 | 31 | 7422 | 7454 | 1733 | 5364 | 5364 | 0 |
BAKKEN | 4-2008 | 30 | 936 | 798 | 2061 | 0 | 0 | 0 |
Not very exciting, huh?
Now, look at this. Incredible, huh, for a re-entry, a re-fracked well?
17089:
Pool | Date | Days | BBLS Oil | Runs | BBLS Water | MCF Prod | MCF Sold | Vent/Flare |
---|---|---|---|---|---|---|---|---|
BAKKEN | 1-2018 | 23 | 12507 | 12087 | 9752 | 13229 | 12402 | 827 |
BAKKEN | 12-2017 | 17 | 8018 | 8624 | 6968 | 9880 | 9880 | 0 |
BAKKEN | 11-2017 | 30 | 16622 | 16901 | 19907 | 19639 | 19639 | 0 |
BAKKEN | 10-2017 | 31 | 22673 | 21904 | 16941 | 24616 | 22715 | 1901 |
BAKKEN | 9-2017 | 27 | 18302 | 18465 | 15589 | 19122 | 16196 | 2926 |
BAKKEN | 8-2017 | 31 | 27510 | 27488 | 27427 | 28501 | 21738 | 6763 |
BAKKEN | 7-2017 | 5 | 2102 | 2047 | 837 | 1178 | 85 | 1093 |
BAKKEN | 6-2017 | 1 | 519 | 230 | 1306 | 317 | 0 | 317 |
BAKKEN | 5-2017 | 0 | 0 | 0 | 0 | 0 | 0 | 0 |
BAKKEN | 4-2017 | 0 | 0 | 0 | 0 | 0 | 0 | 0 |
BAKKEN | 3-2017 | 0 | 0 | 0 | 0 | 0 | 0 | 0 |
BAKKEN | 2-2017 | 0 | 0 | 0 | 0 | 0 | 0 | 0 |
BAKKEN | 1-2017 | 0 | 0 | 0 | 0 | 0 | 0 | 0 |
BAKKEN | 12-2016 | 0 | 0 | 0 | 0 | 0 | 0 | 0 |
BAKKEN | 11-2016 | 0 | 0 | 0 | 0 | 0 | 0 | 0 |
BAKKEN | 10-2016 | 0 | 0 | 0 | 0 | 0 | 0 | 0 |
BAKKEN | 9-2016 | 0 | 0 | 0 | 0 | 0 | 0 | 0 |
BAKKEN | 8-2016 | 0 | 0 | 0 | 0 | 0 | 0 | 0 |
BAKKEN | 7-2016 | 6 | 335 | 644 | 87 | 433 | 66 | 367 |
From the file report:
The newest data has not yet been scanned in by the NDIC. The cover page says the well is still confidential but I assume we will see the updated file in the next week or so.
The most recent geologist's report was received by the NDIC on October 3, 2016. It was spud September 17, 2016, and drilling ceased on September 19, 2016 or two days of drilling. From the file report:
- the Bridger 44-14H is a horizontal re-entry well targeting the middle Bakken porosity
- the rig started drilling ahead in the re-entry middle Bakken lateral at a MD of 20,845' on September 18th, 2016, at 9:44 p.m. CDT
- gas ranged from 1,400 to 2,100 units
- CLR planned to re-enter and deepen the existing lateral of the Bridger 44-14H; plans to extend the existing lateral by 336 feet to a TVD of 11,090 feet
- that was an open hole frack with slightly more than a million lbs of sand
- 32740, 1,485, CLR, Bridger 10-14H2, Rattlesnake Point, 41 stages; 10.2 million lbs, t9/17; cum 137K 1/18;
- 31847, 1,515, CLR, Bridger 9-14H1, Rattlesnake Point, 40 stages; 15.1 million lbs, t8/17; cum 125K 1/18;
Note the production profile. If one simply looks at the "IP test date" and the current date, one misses much of the story. According to the "IP test date" this well has been producing for eight months. In fact, only five months suggest some level of "unconstrained production":
Monthly Production Data
Pool | Date | Days | BBLS Oil | Runs | BBLS Water | MCF Prod | MCF Sold | Vent/Flare |
---|---|---|---|---|---|---|---|---|
BAKKEN | 1-2018 | 31 | 22479 | 22592 | 29091 | 30923 | 22909 | 8014 |
BAKKEN | 12-2017 | 31 | 25030 | 24856 | 42472 | 26335 | 25701 | 634 |
BAKKEN | 11-2017 | 2 | 1350 | 1435 | 2851 | 1512 | 1444 | 68 |
BAKKEN | 10-2017 | 28 | 18550 | 18609 | 23933 | 21854 | 18996 | 2858 |
BAKKEN | 9-2017 | 30 | 22351 | 22386 | 34827 | 27299 | 20714 | 6585 |
BAKKEN | 8-2017 | 31 | 33264 | 33134 | 51363 | 33145 | 24450 | 8695 |
BAKKEN | 7-2017 | 5 | 1901 | 1846 | 5914 | 271 | 180 | 91 |
BAKKEN | 6-2017 | 2 | 0 | 0 | 3148 | 0 | 0 | 0 |
Aha! It just dawned on me. There's another way to find frack data. Let's see if FracFocus has any new data.
Yup, there it is, fracked 4/28/17 - 5/19/17.
- water : 85% of total proppant by weight
- water: 10,332,000 gallons
- sand: 14.76% by weight
- a gallon of water weighs 8.345404 million pounds
- 10,332 million gallons of water weight 86.224714 million pounds
- 85% of what = 86.224714 million lbs
- 101.4408 million lbs total proppant (sand+water+all that other stuff)
- 14.76% of 101.4408 = 15 million lbs of sand
- my numbers may be off a bit but the neighboring wells were fracked with 10 million lbs and 15 million lbs of sand
- with the exception of sand, there was very little additional cost to re-frack this well; the frack spreads were already in the area
- in the process, CLR essentially got a new well
- CLR did not have to drill a new well: it did not have to build a new pad; it did not have to pay a bonus for a new lease; it did not have to wait for permits; minimal cost in re-evaluating the well; developing design plans, etc
- absolutely (well, almost absolutely) no risk of a dry hole (yes, a few re-entry wells are failures)
- a lot of the extra cost of the sand and re-frack was already "covered" by fracking neighboring wells (I won't go through the details)
- they simply drilled less than two more days, extending the horizontal in the process
- the Bakken 10,000 to 20,000 wells that are candidates for re-works; mini-refracks; re-entry - extension; big re-fracks; etc; and, that's even before we get to tertiary production (EOR)
- and, yes, I'm inappropriately exuberant about the Bakken
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