How's That Renewable Energy Working Out In New England? -- December 26, 2017

A reader alerted me to this. I had seen it earlier but I was not going to post it until I saw this story: the day after Christmas, 75% of US sees freezing temperatures, and it's particularly severe in New England, which naturally led to the next question, "how's that renewable energy working out to keep the heat on?"

Spot prices for electricity surging above $200/MWh. And so it goes. Surrounded by a glut of natural gas and electricity surging above $200/MWh. CAVE dwellers don't want natural gas pipelines.

WTI Hit "$60" Today -- December 26, 2017; Hillary Aghast!

Active rigs:

$59.80	12/26/2017	12/26/2016	12/26/2015	12/26/2014	12/26/2013
Active Rigs	53	41	62	173	186

No new permits.
 
Three permits renewed:

• EOG: three Parshall permits, all in Mountrail County

No permits cancelled.

DUCs reported at completed: none.

Hillary aghast? See this site. In case this link breaks, the issue -- US government looks to subsidize coal industry.

Random Update Of MRO's Kukla Well, #16422 -- December 26, 2017

Updates

March 20, 2018: see long note below. Production has been updated for #16422:

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	1-2018	31	13515	13443	19066	13232	11279	158
BAKKEN	12-2017	31	15498	15756	23576	14411	12418	0
BAKKEN	11-2017	28	17826	17771	30827	13396	7552	3770
BAKKEN	10-2017	26	9433	9390	22877	6674	4064	1461
BAKKEN	9-2017	19	10797	10182	8229	12806	3107	8468
BAKKEN	8-2017	0	0	0	0	0	0	0
BAKKEN	7-2017	0	0	0	0	0	0	0
BAKKEN	6-2017	0	0	0	0	0	0	0

Original Post

 
Disclaimer: in a long note like this there will be typographical and factual errors. It is difficult to separate opinion from facts. I may be seeing things that do not exist, and I certainly see things differently that a lot of analysts. 

Case study: as you go through this case study, think about this. Some folks are suggesting that operators are running out of new drilling locations in the "sweet spots" in the Bakken. I don't buy that. To some extent, "sweet spots" are defined by the price of WTI. Whatever.

The bigger story is continued management of existing wells. Somewhere else one can find the exact number of Bakken wells that have been drilled and are still being "managed." I come up with about 10,500 Bakken wells. The vast majority of those wells have not been re-fracked, either with a mini-re-frack, a modest re-frack, or a full-fledged re-frack.

If one considers an existing Bakken well as a well that could be re-fracked, one could argue it's a "new" drilling location. That may not make sense, but think about it as you go through this case study. This makes unconventional (tight oil) very different from conventional oil.

The well:

• 16422, 293, MRO, Kukla 34-34H, Murphy Creek, F; t12/07; cum 141K 10/17;

Recent production profile:

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	10-2017	26	9433	9390	22877	6674	4064	1461
BAKKEN	9-2017	19	10797	10182	8229	12806	3107	8468
BAKKEN	8-2017	0	0	0	0	0	0	0
BAKKEN	7-2017	0	0	0	0	0	0	0
BAKKEN	6-2017	0	0	0	0	0	0	0
BAKKEN	5-2017	0	0	0	0	0	0	0
BAKKEN	4-2017	0	0	0	0	0	0	0
BAKKEN	3-2017	13	443	747	326	435	0	336
BAKKEN	2-2017	28	1502	1873	462	1461	0	1132
BAKKEN	1-2017	31	2221	2101	705	2098	0	1674
BAKKEN	12-2016	12	478	0	660	240	0	120
BAKKEN	11-2016	0	0	0	0	0	0	0
BAKKEN	10-2016	0	0	0	0	0	0	0

It has been off-line since 1/15:

BAKKEN	12-2014	31	954	926	315	809	360	161
BAKKEN	11-2014	30	976	939	361	759	360	115
BAKKEN	10-2014	31	1001	1140	343	670	283	94
BAKKEN	9-2014	30	994	906	347	630	244	100
BAKKEN	8-2014	31	1073	1129	372	884	432	151
BAKKEN	7-2014	31	1139	1118	422	742	348	86
BAKKEN	6-2014	30	1162	1122	443	685	233	148
BAKKEN	5-2014	31	1338	1611	570	747	232	186

Initial production after original frac:

BAKKEN	9-2008	30	2450	2433	707	1546	1546	0
BAKKEN	8-2008	31	2918	3008	838	1958	1958	0
BAKKEN	7-2008	31	3184	3124	1043	2004	2004	0
BAKKEN	6-2008	30	4113	4279	1197	2749	2749	0
BAKKEN	5-2008	31	4627	4371	1523	2543	2543	0
BAKKEN	4-2008	18	1774	1821	862	931	931	0
BAKKEN	3-2008	31	3197	3218	808	1590	1590	0
BAKKEN	2-2008	29	3755	3766	914	1770	1770	0
BAKKEN	1-2008	29	5030	5176	1307	2309	2309	0
BAKKEN	12-2007	31	5800	5219	2915	2280	2280	0

FracFocus:

• Re-fracked 7/24/2017 - 8/10/2017; 6,706,365 gallons of water; water, 91% by mass; 
• a gallon of water weighs: 8.345404 pounds
• 6,706,365 gallons x 8.345404 pounds = 56 million pounds
• 91% of what = 56 pounds
• 61.5 million pounds - 56 million pounds = 5.5 million pounds proppant max
• let's see if there's sundry form over at NDIC
• wow, there is
• the new IP: 1,742 (crude oil)
• 45 stages
• and, the amount of proppant? 5.3 million lbs (whoo-hoo, the math above was right on target)

The other two wells in the drilling unit unremarkable at this point: #25761 and #25760, although the latter was off-line 10/17; it's not a great well, and wonders if this one might be a candidate for a re-frack?

The graphic:

Comments:

• this well was, in the big scheme of things, a pretty lousy well from the beginning; the IP and total production the first couple of years was not all that great
• it was shut in for almost two  years
• it was then re-fracked, and by "modern" standards, it was re-fracked with a small amount of proppant, 5.3 million pounds
• the modest re-frack resulted in an IP and a first two-month production well above what the well produced when it was first drilled/fracked back in 2007
• the operator had almost no risk re-fracking this well
• the well was already drilled; no new infrastructure costs were incurred; no new lease money; no new nothing as far as costs, except the costs associated with a modest re-frack
• my hunch is that the geologist/company could almost "guess" what new production would be based on their knowledge of the Bakken
• finally, note that this well is almost ten years old, and is still flowing, without a pump, at least according to the scout ticket; sometimes the scout tickets are wrong
• could one consider this a "new" drilling location? Just saying
• one more thing: note that is an MRO well; it's my feeling that MRO is taking the lead on re-fracks

October, 2017, US Crude Oil Production Data To Be Released Later This Week -- Richard Zeits -- December 26, 2017

EIA to report US crude oil production for October, 2017, at the end of the week. Richard Zeits forecast and my comments:

• 9.45 million bopd; above the 9.28million bbls/day implied by the EIA's weekly estimates
• Zeits reminds us that October, 2017, production was strongly impacted by Hurricane Nate
• Zeits again wades into the controversy regarding EIA forecasts
• oil peak folks think the EIA is overly bullish
• Zeits thinks EIA may be under-estimating the oil industry
• the best "news": unless I missed it, Zeits did not mention rig count; CNBC was still emphasizing rig count as the best way to measure/forecast US crude oil productivity

How Bad Was The Saudi Trillion-Dollar Mistake? -- December 26, 2017

It will take them more than a decade to balance their budget. 

From Bloomberg:

• Saudi assumes: oil revenue will surge by 80% by 2023 -- that's five years from now; and almost ten years from when Saudi first announced plans to flood the world with oil, to crush US shale (their trillion-dollar mistake)
• six-year program to balance the budget
• their plant assumes rising oil prices and increasing output: will push oil sales to 801.4 billion riyals ($214 billion) from 440 billion riyals this year
• assumes the price of oil will reach $75 (when that happens is not provided)
• one expert says these assumptions look very "challenging"
• "the strong oil revenue growth in 2017 will be difficult to repeat"
• forecast: oil production to 11.03 million bopd vs an average 10 million bopd
• for 2020: 10.45 million bopd

From another story earlier this month, this is how the Saudi's plan to execute their budget:

Random Note Regarding A Dry Well In Newporte Oil Field -- December 26, 2017

This well was reported as dry today:

• 33289, dry, Armstrong, Hanson 33-43, Newporte, Cambro/Ordovician, no production data, 

This is from the summary at the file report:

This well was drilled on the outer rim on the west side of a seismically-defined meteor impact crater. Production has been established in two wells; one on the eastern side of the crater, and on the southwestern side of the crater. Both of these wells are completed in the Deadwood Sand.

This well, unfortunately, found no Winnipeg Sand. Just below the Winnipeg Shale is a tight sand identified as Deadwood Sand. There was no show in this sand. The Winnipeg Sand is quite pyritic; it usually appears as medium grained sand with pyrite filling the interstices. [The geologist] referred to the Winnipeg Sand as chrome plated -- that is what it looks like: clear quartz grains protruding through the silvery pyrite. Therefore I believe that the Winnipeg Sand is absent her, and the sand present is Deadwood Sand. 

And then this:

The depths reported by the driller and the logger differ by 56 feet. This could be due to mis-counting drillpipe (2 joints). [The geologist] believes a more likely explanation lies in the abandonment of magnetically marked cables on the wireline truck. This results in depths measured by the logger being less than that reported by the driller. There was fill in the hole; during the latter part of the hole [the geologist] observed black shale cleats up to 1" by 1 1/2'  x 1/2'. The up-hole shales were sloughing in irregular timed pulses. The logger (wisely) did not spud the tool on bottom. [The operator} was in and out of the hole several times whilst waiting for a logging truck to get to location, and [the geologist] cannot image the rig crews mis-counted the drillpipe the same way every time. [The geologist] thinks the presence of ill, and the known error in depth measurements by logging companies since abandonment of marked cables can account for the discrepany in the depths reported by the driller and the logger.

The Market And Energy Page, T+339 -- December 26, 2017 -- TSLA And The "Death Cross"

Wells coming off confidential list today: have been updated.

WTI: from a post early this morning --

Before the open, WTI was $58.44. Early after the opening, WTI jumped to $59.41, said to be due to a pipeline blast in Libya and  the loss of Forties oil right now.  My thoughts: the jump in price had little to do with the Forties pipeline or the Libyan story. The Forties pipeline story is not new; the pipeline has been repaired; and, already the pipeline is being tested for re-start in early January, just as the company said would happen. Libya? When do we not hear of a problem in Libya. Some might argue that WTI is headed toward $60 on a "no-news" story.  [Later: on CNBC we now learn that the pipeline blast in Libya has resulted in 90,000 bopd -- that is so inconsequential as to be laughable as a cause for the jump in the price of oil.]

API drawdown data: normally, the API reports API US crude oil inventories late in the afternoon on Tuesdays; normally I find those reports linked at this site; so far it's not on today's calendar, suggesting the report will be released tomorrow; it's my gut feeling that some folks know that data point before it's officially released and could affect the price of WTI; WTI was up significantly despite no "real" news -- a Libyan pipeline explosion removing 90,000 bopd isn't a big enough story to move the price of oil;

TSLA: earlier today, a reader sent me this link, suggesting that it will be years (decades?) before Tesla can possibly have a positive cash flow. Now this, the "death cross":

Market: whatever the reason for the jump in WTI (and Brent), the bigger story is the jump in share prices across the board in the oil sector. Whoo-hoo.

Disclaimer: this is not an investment site. Do not make any investment, financial, job, travel, or relationship decisions based on what you read here or what you think you may have read here.

NYSE, new highs and lows.

• new highs, 168: Arch Coal (!!); CA; CAT; CVX; DE; EOG; Marathon Petroleum; OXY; Phillips 66; Shell; Statoil; UNP; 
• new lows, 19
• if you want to see another reason why Arch Coal might be doing better, see this post.

Wage disparity:

• gender
• CEO/employees
• federal / non-federal worker

CLR Shows "Major" Improvement In Oil Production -- Filloon -- December 26, 2017

Over at SeekingAlpha:

• CLR continues to better stimulation and increase sand and fluids usage
• well design has increased production per foot significantly and this should continue into 2018
• CLR is well positioned as higher oil prices and lower Bakken differential improve economics
• Banks field has the best oil curve. It is followed by Camp, Camel Butte, and Elm Tree. Elm Tree and Sanish field account for 35 completions.

Continental Resources, Inc. has had a number of very good results in the Bakken since the beginning of 2016.

Better stimulation techniques coupled with increased volumes of sand and fluids continue to improve completions.

We pulled the production data of 88 CLR Bakken locations turned to sales after January 1 of 2016. The results were quite good. A number of locations topped 200 KBO, and one did this in seven months. Two horizontals produced over 350 KBO in 14 months. 74 of the 88 completions had laterals of at least 9,000 feet.

Global Warming Update For The Bakken -- December 26, 2017

Updates

December 26, 2017: It isn't just the Bakken enjoying global warming. Some other headlines today --

• Erie, PA, get record snowfall during Christmas blizzard; 34 inches; another 19 inches fell before dawn Tuesday, bringing two-day total to 53 inches; greatest two-day total in PA history; previous record was 44 in Morgantown, in March 1958; the previous record was 20' set in 1956; the greatest seven-day snowfall is 40" in over 2001-2002 holidays; bitter col enveloped much of the midwest
• cold envelopes much of central, eastern US; NYC to face biting winds for New Year's Eve celebration
• near record cold forecast for New Year's Eve in NYC

Original Post 

Most interesting: the "cold" months in western North Dakota are generally later January, and early- to mid- February. 

Today's temperatures, screenshots taken at 7:13 - 7:21 a.m., December 26, 2017, for North Pole (the Arctic); Watford City, ND (the Bakken); and the South Pole (the Antarctic):


Williston, ND:

Watford City:

North Pole:

South Pole:

Random Update Of Three Whiting/KOG Mandaree Wells -- December 26, 2017

NB: note the names of the two earlier wells; and the name of the re-fracked well.

The wells:

• 18517, 1,595, Whiting, Two Shields Butte 2-24-12-2H, Mandaree, t9/11; cum 494K 10/17;
• 19826, 2,945, Whiting, Two Shields Butte 2-24-12-1H3, Mandaree, Three Forks; 9/11; cum 454K 10/17; 10562; well name change from 2-24-12-1H to 2-24-12-1H3;
• 30929, 1,989, Whiting, Two Shields Butte 1-24-12-1H, Mandaree, 44 stages, 14.6 million lbs, t1/17; cum 210K 10/17; 10476; 

18517, 2-24-12-2H:

BAKKEN	10-2017	31	4975	4937	3036	1677	1060	400
BAKKEN	9-2017	19	3094	3125	1845	843	252	447
BAKKEN	8-2017	29	5242	5301	3191	1849	1331	295
BAKKEN	7-2017	31	6419	6503	4630	3180	2629	331
BAKKEN	6-2017	30	5917	5852	4360	3927	2351	1355
BAKKEN	5-2017	31	6141	6102	4898	5270	2508	2454
BAKKEN	4-2017	30	5573	5620	4750	6083	2806	3001
BAKKEN	3-2017	31	6131	6028	7961	4515	4014	263
BAKKEN	2-2017	21	2451	2390	3767	2064	1853	92
BAKKEN	1-2017	0	0	263	0	0	0	0
BAKKEN	12-2016	0	0	0	0	0	0	0
BAKKEN	11-2016	30	2656	2561	1141	2801	2173	43
BAKKEN	10-2016	31	3353	3454	1749	4318	3178	394
BAKKEN	9-2016	29	3920	3832	1697	2884	638	165

19826: 2-24-12-1H3:

BAKKEN	8-2017	31	3510	3575	7918	1025	705	156
BAKKEN	7-2017	31	5460	5578	9414	3354	2777	350
BAKKEN	6-2017	30	6310	6229	7903	5873	3539	2039
BAKKEN	5-2017	31	6060	6036	7924	7601	3637	3559
BAKKEN	4-2017	30	6179	6227	8171	7082	3274	3501
BAKKEN	3-2017	31	6675	6640	9213	5037	4487	294
BAKKEN	2-2017	28	5726	5595	7374	6092	5564	275
BAKKEN	1-2017	5	301	419	219	144	128	0
BAKKEN	12-2016	0	0	0	0	0	0	0
BAKKEN	11-2016	15	1308	1350	769	500	365	7

30929, 1-24-12-1H:

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	10-2017	31	20057	20038	9505	18790	12489	4717
BAKKEN	9-2017	30	21416	21451	10048	16377	5204	9228
BAKKEN	8-2017	31	24001	24083	11513	24035	18063	4000
BAKKEN	7-2017	31	20601	20521	8789	18889	16006	2017
BAKKEN	6-2017	17	9649	9720	3482	8536	5191	2991
BAKKEN	5-2017	31	16965	16928	8226	19877	9584	9377
BAKKEN	4-2017	30	18717	18956	8904	21838	10181	10888
BAKKEN	3-2017	31	23713	23856	10933	18502	16707	1094
BAKKEN	2-2017	28	31180	31383	27852	22159	20445	1011
BAKKEN	1-2017	25	24057	23078	24633	15942	15770	0

Random Production Update For An Armstrong Lodgepole Well In Southwest North Dakota -- December 26, 2017

I track this well at this post. This page will not be updated. Random update of production data for this well:

• 18496, 474, Armstrong Operating, Gruman 18-3, Patterson Lake, t3/10; cum 740K 10/17;

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
LODGEPOLE	10-2017	31	10652	10612	0	4474	4331	0
LODGEPOLE	9-2017	30	8761	8638	0	3679	3541	0
LODGEPOLE	8-2017	24	6088	6268	0	2576	2466	0
LODGEPOLE	7-2017	31	7899	7716	2	3336	3193	0
LODGEPOLE	6-2017	30	7485	7671	7	3098	2960	0
LODGEPOLE	5-2017	31	7644	7458	7	3050	2907	0
LODGEPOLE	4-2017	30	7392	7468	6	2916	2778	0
LODGEPOLE	3-2017	31	7652	7879	10	2890	2747	0
LODGEPOLE	2-2017	28	6980	6873	11	2674	2545	0
LODGEPOLE	1-2017	31	7864	7851	11	3037	2894	0
LODGEPOLE	12-2016	30	7954	7871	8	3136	2998	0

Random Update Of Re-Fracked QEP Wells -- December 26, 2017

Back on October 28, 2017, there was a post discussing recent comments by QEP on re-fracking. In that post:

Likely candidates, all in Heart Butte (there may be other candidates) :

• 20964, 1,035, QEP, MHA 1-32-33H-148-92, Heart Butte, t1/12; cum 265K 9/18;
• 20965, 810, QEP, MHA 3-32-33H-148-92, Heart Butte, t1/12; cum 168K 9/18;
• 23093, 2,052, QEP, MHA 3-06-31H-150-92, Heart Butte, t9/13; cum 449K 9/18;
• 23097, 2,512, QEP, MHA 2-06-31H-150-92, Heart Butte, t9/13; cum 486K 9/18; (see production profile below); according to FracFocus (API 33-025-01754), fracked in 2013; and re-fracked 6/18/17 - 6/29/2017;
• 24209, 2,854, QEP, MHA 5-04-33H-150-92, Heart Butte, t5/13; cum 334K 9/18;

At the time, the data for several of the wells above was not provided, but it has now been updated.

I have long forgotten how those five candidates were chosen as candidates for re-fracking. I assume it came from going through the production profiles of producing wells in Heart Butte.

So, let's look at the last 10 months (or so) of production from each of those wells:

20964, API: 33-025001394:

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	10-2017	31	4532	4433	6151	2367	652	61
BAKKEN	9-2017	30	4293	4256	6055	2739	799	546
BAKKEN	8-2017	29	4051	4494	5609	1759	696	194
BAKKEN	7-2017	30	3676	3570	6564	2288	86	0
BAKKEN	6-2017	30	5248	5156	8538	2935	776	0
BAKKEN	5-2017	27	5384	5595	7252	3256	1090	0
BAKKEN	4-2017	30	5792	5467	8298	4898	3170	0
BAKKEN	3-2017	31	6845	6879	10363	5637	3699	0
BAKKEN	2-2017	28	7218	7267	13092	5995	3697	0
BAKKEN	1-2017	22	7814	7925	12121	4556	2854	0
BAKKEN	12-2016	27	9374	9062	16655	6102	4110	20
BAKKEN	11-2016	30	10284	10361	20908	6570	4573	0
BAKKEN	10-2016	31	12254	12564	32490	7235	5090	288
BAKKEN	9-2016	29	8839	8900	29626	4880	3327	0
BAKKEN	8-2016	27	5260	5311	30430	2529	1152	0
BAKKEN	7-2016	3	156	0	16476	890	33	446
BAKKEN	6-2016	9	340	223	570	773	2	43
BAKKEN	5-2016	29	1129	1121	1323	1528	0	0

20965, API: 33-025-01395:

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	10-2017	25	1518	1554	2809	1415	333	31
BAKKEN	9-2017	30	2848	2831	5423	1549	446	304
BAKKEN	8-2017	31	2860	2742	6932	1606	636	177
BAKKEN	7-2017	1	32	255	97	415	1	0
BAKKEN	6-2017	20	2343	2406	5415	1467	378	0
BAKKEN	5-2017	27	3735	4095	8707	1493	434	0
BAKKEN	4-2017	30	5978	5633	14205	5000	3245	0
BAKKEN	3-2017	31	6853	6796	16577	5101	3325	0
BAKKEN	2-2017	28	5298	5220	13896	2487	1390	0
BAKKEN	1-2017	17	3442	3271	11827	2389	1446	0

23093, API: 33-025-01750:

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	10-2017	31	17354	17395	16274	20966	5685	14880
BAKKEN	9-2017	30	22176	22122	27112	26150	924	25185
BAKKEN	8-2017	31	21753	21706	46545	24159	9210	14867
BAKKEN	7-2017	10	4762	4658	18822	4021	2139	1800
BAKKEN	6-2017	0	0	42	0	0	0	0
BAKKEN	5-2017	22	1818	1717	665	1378	0	1069
BAKKEN	4-2017	16	1659	1984	437	1971	1121	526
BAKKEN	3-2017	31	3876	3785	803	4564	4037	97
BAKKEN	2-2017	28	3362	3318	828	3732	3300	52
BAKKEN	1-2017	31	4254	4249	726	4744	3888	435

23097, API: 33-025-01754:

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	10-2017	31	14243	14242	9461	14859	3994	10457
BAKKEN	9-2017	30	16472	16515	8660	19032	673	18318
BAKKEN	8-2017	31	20709	20755	9192	19800	7558	12201
BAKKEN	7-2017	13	5761	5648	9788	5077	2683	2258
BAKKEN	6-2017	0	0	53	0	0	0	0
BAKKEN	5-2017	18	2298	2371	522	2663	0	2405
BAKKEN	4-2017	30	3864	3948	879	4331	2670	1253
BAKKEN	3-2017	31	3943	3810	793	3993	3463	83
BAKKEN	2-2017	26	3101	3031	900	3098	2709	43
BAKKEN	1-2017	26	3562	3645	874	3674	2989	334

24209, API: 33-025-01949:

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	10-2017	18	9800	9761	3824	8915	0	7094
BAKKEN	9-2017	23	12173	12202	9062	11330	0	9681
BAKKEN	8-2017	29	16147	16128	23609	13822	371	11383
BAKKEN	7-2017	4	2173	1859	4036	1505	0	1215
BAKKEN	6-2017	2	47	181	48	113	47	3
BAKKEN	5-2017	27	1262	1344	783	1717	590	239
BAKKEN	4-2017	30	2167	2101	866	2040	733	269
BAKKEN	3-2017	31	2363	2447	933	2155	989	72
BAKKEN	2-2017	28	2164	2133	897	1971	862	90
BAKKEN	1-2017	31	2335	2394	1062	2130	565	398

Frack data (from FracFocus):

• 20964, API: 33-025001394: re-frack, 7/14-27/2016;a sundry form at NDIC, re-frack 7/28/16; 30 stages; 8.3 million lbs;
• 20965, API: 33-025-01395: re-frack, 7/14-22/2016;
• 23093, API: 33-025-01750: frack 9/5-22/2013; re-frack 6/18-30/2017;
• 23097, API: 33-025-01754: frack 8/30-31/2013; re-frack 6/18-29/2017;
• 24209, API: 33-025-01949: frack 5/11/2013; re-frack 7/1-9/2017;