Weekly EIA Petroleum Report -- September 14, 2022

Breaking

Natural Gas: from a reader: 

Natural gas at $9.09 right now. 

US natural gas futures jumped more than 6% toward $8.8/MMBtu, the highest in almost 2 weeks and slowly approaching 14-year highs of $10 reached in August, boosted by higher demand forecast and more coal-to-gas switching in case of a rail strike. 

 

The potential railroad strike, which could come as early as Friday, could force generators to burn more gas to produce electricity as about two-thirds of the nation's coal-fired power plants receive their coal by rail.

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Near-Term Risks

Link here.

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Weekly EIA Petroleum Report
US Crude Oil Inventory

Link here.

• US crude oil inventories increased by 2.4 million bbls. 

That is all. 

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Gasoline Demand

Link here.

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The Book Page

I'm pretty happy with the reading program I had this past summer. 

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Back to the Bakken

Active rigs: 45.

WTI: $88.83. Creeping up.

Natural gas: $9.062. Trending toward 10-year high. Could benefit from a railroad strike.

No new permits:

One well permitted for recompletion:

• 8324, White Rock, Barkland 1-18-2A, wildct; Bonnie View.

Shifting The Focus To Optimized Production -- November 17, 2019

Beginning with the abstract sent to me by a reader I did a google search for relevant articles hoping to learn a bit more about drilling locations and completion strategies in the Bakken.

Springer, September 23, 2019: growth drivers of Bakken oil well productivity. The full article currently available. One may want to archive it before it disappears. Wow, wow, wow -- a light bulb goes off -- it comes down to technology and geology. The former is dynamic, the latter is static. Let's look at geology. In all the articles I have read, this seems to be the progression:

• the oldest articles compared basins around the world -- akin to macroeconomics in the business world
• with the shale revolution, articles began to compare various basins in the US: the Haynesville, the Marcellus, the Permian, the Eagle Ford, the Bakken, etc. -- again, macroeconomics
• most recently, analysts are comparing "areas" within a basin, such as areas owned by certain operators, or in the case of the North Dakota Bakken, the four or five major counties
• I don't follow the other plays closely enough to say, but in the North Dakota Bakken, for whatever reason the state regulators decided to define fields, it has worked out incredibly well;
• it seems like a no-brainer but studies are still faulted for comparing McKenzie County with Williams County, for example. Each of those counties is relatively huge; and different fields within each county vary significantly in quality.  

The second light bulb that goes on: in this paper, wells from 2010 through 2017 were analyzed. I'm sure the researchers factored all that in but I think including wells drilled in 2010 with wells drilled in 2017 is like comparing apples to oranges. Too much to think about. Time to move on. [Later: see first comment.]

Denver Well Logging Society, Spring, 2019, workshop.

Hart Energy, one year ago, September 4, 2018: shifting the focus to optimized production. Operators see opportunities for production gains in legacy wells, refracturing, and data analytics.

• caption at the linked article: Equinor will deploy artificial-intelligence powered artificial lift technology on its rod pump wells in North Dakota
• there is evidence that operators might be pumping as much proppant into the well as they can can and that laterals have extended so long that it might not be economic to drill out much farther
• the phrase "reached a point of maximum return" is tarting to show up more often
• so, if operators have reached "maximum return" with regard to sand, where do they go next?
• Equinor -- machine learning/artificial intelligence

in late July (2018) Equinor announced it will deploy a rod lift technology developed by Ambyint—a company that specializes in artificial lift and production optimization equipment— on its wells in the Bakken Shale, where Equinor will expand the system to full-field development.During pilot testing, Equinor was able to automate rod pump well optimization through the use of Ambyint’s autonomous set point management functionality, according to a press release. By identifying wells that were overpumping or underpumping, controller set points were adjusted “with minimal human interference,” the release stated.

• legacy well optimization:
• pumping improvements (see article)
• workovers
• managing chokes
• it's not the highest EUR, but the highest IRR
• well refracturing
• Oasis experience in the Bakken (see article)
• artificial life trends (see article)
• analytics (see article) -- may be the biggest payoff
• well bashing -- relationship between "parent" and "child" (see article)
• again, Oasis in the Bakken

Oasis’ Reid said that in North Dakota the company is applying full-field development strategies, so Oasis does not have much activity cycling in the same area, which helps allay the effects of well bashing.

“We generally have one parent well in each of our DSUs, and when we come in for development drilling we are drilling out the full DSU at all depths in the Bakken and Three Forks to minimize future interference effects,” he said. “In addition, we are often refracking the parent well to improve its performance and to minimize the disruption to the new wells from a depleted parent well.”

Re-Entry Of An Old Duperow - Stonewall Well -- September 12, 2018

September 12, 2018, daily activity report -- recompleted well:

• 14876, White Rock Oil & Gas, Federal 16-28; 

Sundry form:

• stimulated formation: Stonewall, 3/4/17
• recompleted and commingled production from the Mondak-Stonewall pool and Mondak-Duperow pool; allocation will be based on fingerprint analysis; currently, allocation suggests 47% Duperow, 53% Duperow; rod lift with "19 oil, 15 gas, and 48 water."

Screenshot of scout ticket:

NDIC File No: 14876     API No: 33-053-02527-00-00     CTB No: 114876 Well Type: OG     Well Status: A     Status Date: 6/22/2018     Wellbore type: Vertical Location: SESE 28-148-104     Footages: 1240 FSL 1060 FEL     Latitude: 47.607951     Longitude: -103.929577 Current Operator: WHITE ROCK OIL & GAS, LLC Current Well Name: FEDERAL 16-28 Elevation(s): 2451 KB   2430 GR     Total Depth: 13130     Field: MONDAK Spud Date(s):  10/14/1999 Casing String(s):  9.625" 2067'   5.5" 13110'   Completion Data    Pool: DUPEROW     Perfs: 11248-11254     Comp: 6/22/2018     Status: AL     Date: 7/3/2018     Spacing: E2    Pool: RED RIVER     Perfs: 12906-12931G     Comp: 2/24/2000     Status: PNA     Date: 2/27/2017     Spacing: E2    Pool: STONEWALL     Perfs: 12564-12574     Comp: 3/13/2017     Status: PNA     Date: 3/13/2017     Spacing: E2 Cumulative Production Data    Pool: RED RIVER     Cum Oil: 604982     Cum MCF Gas: 981163     Cum Water: 304550    Pool: STONEWALL     Cum Oil: 3730     Cum MCF Gas: 2652     Cum Water: 2106    Pool: DUPEROW     Cum Oil: 292     Cum MCF Gas: 144     Cum Water: 717 Production Test Data    IP Test Date: 2/24/2000     Pool: RED RIVER     IP Oil: 655     IP MCF: 590     IP Water: 5    IP Test Date: 3/15/2017     Pool: STONEWALL     IP Oil: 34     IP MCF: 31     IP Water: 5    IP Test Date: 7/3/2018     Pool: DUPEROW     IP Oil: 132     IP MCF: 8     IP Water: 2

Monthly Production Data Pool Date Days BBLS Oil Runs BBLS Water MCF Prod MCF Sold Vent/Flare DUPEROW 7-2018 31 292 72 717 144 144 0 RED RIVER 7-2018 0 0 0 0 0 0 0 STONEWALL 7-2018 31 330 149 1433 165 165 0 RED RIVER 6-2018 0 0 0 0 0 0 0 STONEWALL 6-2018 30 536 536 167 0 0 0

Marathon Oil CEO To Be Keynote Speaker At Annual Williston Basin Petroleum Conference

The Bismarck Tribune is reporting:

Lee Tillman, chief executive officer of Marathon Oil Corp., will give the keynote address at the 22nd Annual Williston Basin Petroleum Conference.

Also speaking:

• Harold Hamm of Continental Resources
• Tommy Nusz of Oasis Petroleum
• Jim Volker of Whiting Petroleum

The conference and expo will be held in Bismarck May 20-22. Registration opens at 9 a.m. Wednesday.

According to The Tribune: Exhibit space for the conference sold out in 17 minutes when Bismarck hosted the conference in 2012. More than 4,000 people registered, making it the largest event to be held in Bismarck-Mandan.

Prior to the conference, readers may want to review MRO's most recent presentation:

• 370,000 net acres
• 1,300 net wells inventory, up from 450 in 2011
• cost target, $7 - $7.8 million
• testing 320-acre spacing (4MB, 4TF1/1280)
• 6 TF2 wells in forward planning
• added a second frack spread
• will increase rig count by 20% each in Bakken and Eagle Ford
• Bakken: low-risk play

This may be the most interesting news (posted earlier). MRO has moved from open hole completions to 20 stages to 30 stages now. They will go back to all open hole completions and complete them to current best completion design; recompletions based on lessons learned from 9 recompletions accomplished in 2011. The recompletion results in an additional 280,000 bbls/wells; effectively "re-sets" the decline curve, not a trivial issue in the Bakken.

Perhaps other operators are recompleting their early wells, but MRO is the only operator I see talking so much about it.

Disclaimer: there might be errors in the data points from the presentation; I go through these quickly; I do not have narrative that accompanies the slides. 

To have the MRO CEO the keynote speaker is a big, big deal. Of all the operators in the Bakken, there are very few international operators; MRO is one of the few. Opportunity for CEO to compare the Bakken with rest of world.  

Two Interesting KOG Re-Entry Wells

Updates

May 25, 2014: the "rest of the story" for the Two Shields Butte #18987 has now been told. Any updates will be tracked at that link. 

Later, 3:59 pm: The original post was "not ready for prime time." But I will leave it there. I'm not in the mood to re-do it. But I have pulled up the well files. Here some notes from the well files:

18987, 223, KOG, Two Shields Butte 14-21-16-2HS, t4/11; cum 119K 4/13;

• Spacing is now listed as ICO. 
• Fracked 2/21-27/13; 27 stages; 4 million lbs; all ceramics; middle Bakken, a horizontal re-entry..
• ISP following that (first and only) frack: 2,061
• Sundry, dated December 18, 2012: KOG notes plans to sidetrack and redrill this well.
• First pump: 9/30/11.
• Reached TD 10/16/10; not fracked; but producing; IP of 223; 
• Spacing unit: E2 sections 21 and 16; 640 acres;
• Production history for this well:

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	4-2013	30	29922	29870	11756	19524	6877	12557
BAKKEN	3-2013	30	39986	39636	33530	22340	0	22251
BAKKEN	2-2013	0	0	0	0	0	0	0
BAKKEN	1-2013	0	0	0	0	0	0	0
BAKKEN	12-2012	1	1	75	0	0	0	0
BAKKEN	11-2012	20	1478	1731	30	1118	0	1058
BAKKEN	10-2012	31	2354	2081	20	1760	0	1668
BAKKEN	9-2012	30	2050	2359	28	1596	0	1507
BAKKEN	8-2012	23	2184	1953	27	1482	0	1415
BAKKEN	7-2012	25	2176	2134	19	1601	0	1536
BAKKEN	6-2012	30	2516	2576	44	1939	0	1852
BAKKEN	5-2012	31	3038	2978	59	2257	0	2166
BAKKEN	4-2012	17	2043	2017	28	1333	0	1282
BAKKEN	3-2012	2	546	561	528	263	0	257
BAKKEN	2-2012	29	2765	2778	1606	1903	0	1819
BAKKEN	1-2012	31	3042	3021	1913	2106	0	2016
BAKKEN	12-2011	31	3222	3232	2933	2259	0	2166
BAKKEN	11-2011	29	3328	3594	774	2885	0	2160
BAKKEN	10-2011	18	1809	1824	1974	1087	0	637
BAKKEN	9-2011	21	1751	1766	181	889	0	364
BAKKEN	8-2011	31	2774	2902	741	1609	0	834
BAKKEN	7-2011	29	2552	2836	12	1581	0	856
BAKKEN	6-2011	30	3650	3285	410	2219	0	1469
BAKKEN	5-2011	26	4007	4006	114	2470	108	1712
BAKKEN	4-2011	10	1713	1535	153	863	0	613
BAKKEN	3-2011	1	0	0	48	0	0	0
BAKKEN	2-2011	1	323	0	0	0	0	0
BAKKEN	1-2011	0	0	0	0	0	0	0
BAKKEN	12-2010	0	0	0	0	8903	0	8453

21513, 23, KOG, Smokey 3-6-7-14HS, Bully, t2/12; cum 24K 4/13;

• Date of first production after sidetrack: 3/9/12.
• Sundry, dated December 18, 2012: KOG notes plans to sidetrack and redrill this well
• Reached TD 11/24/11; fracked with 2 stages; 1.7 million lbs, all ceramics; IP of 23; 
• Spacing: two sections, 1280-acres
• Production history for this well:

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	4-2013	30	11413	11443	15372	20171	19911	170
BAKKEN	3-2013	20	11362	10894	20838	7640	0	7581
BAKKEN	2-2013	0	0	0	0	0	0	0
BAKKEN	1-2013	0	0	0	0	0	0	0
BAKKEN	12-2012	0	0	0	0	0	0	0
BAKKEN	11-2012	1	14	158	30	0	0	0
BAKKEN	10-2012	0	0	0	0	0	0	0
BAKKEN	9-2012	1	35	0	3	0	0	0
BAKKEN	8-2012	20	265	440	234	137	0	77
BAKKEN	7-2012	2	38	0	87	0	0	0
BAKKEN	6-2012	1	144	0	40	2	0	0
BAKKEN	5-2012	7	157	263	304	25	0	4
BAKKEN	4-2012	22	254	280	533	175	0	110
BAKKEN	3-2012	0	0	0	0	0	0	0
BAKKEN	2-2012	12	327	0	569	170	0	134

Original Post 

This post is not ready for prime time.

It may be deleted later when I find an obvious error or mistake. But for now:

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By the way, there is something going on with the KOG wells. I haven't pulled down the file reports but look at this.

• 18987, 223, KOG, Two Shields Butte 14-21-16-2HS, Heart Butte, t4/11; cum 119K 4/13;
• 21513, 23, KOG, Smokey 3-6-7-14HS, Bully, t2/13; cum 24K 4/13

Those are the WORSE IPs KOG has ever posted, and these are in the best spots in the Bakken.

But KOG is producing:

18987, see above, KOG, Two Shields Butte 14-21-16-2HS:

Date	Oil Runs	MCF Sold
4-2013	29870	6877
3-2013	39636	0
12-2012	75	0

 21513, see above, KOG, Smokey 3-6-7-14HS, Bully:

Date	Oil Runs	MCF Sold
4-2013	11443	19911
3-2013	10894	0

In other words, these are HUGE wells for KOG, and yet their IPs were the worse possible.

It turns out these wells were drilled some time ago, and had lousy IPs. They were taken off-line for two to three months -- no one has said why -- what they were doing during these two months. Prior to taking them off line, they were producing 300 bbls/month.

After coming back on line, they were gushers, to 40,000 bbls/month in one case; and 11,000 bbls/month in the other case.

My hunch is that KOG drilled these wells a long time ago, but never fracked them (for all kinds of reasons) but they reported an IP before the wells were fracked. After fracking, the huge production.

The problem with that theory is that I have never seen an operator report an IP before the Bakken well was fracked. They simply carried it on the books as on DRL status.

I'm hoping the well files show something; if not, I will need Zeits or Filloon or a corporate presentation to explain what is going on.

But from 300 bbls/month to 40,000 bbls/month is absolutely incomprehensible.

Wells Approved for Re-Entry, Re-Fracking; "Delayed" Initial Fracking -- December 19, 2012

Locator: 10001RE-ENTRY.

See also: this thread over at the discussion group. 

Disclaimer: I do not understand permitting process for re-entry, re-frack, delayed fracks, etc. I am using using page to start to sort this stuff out.

If I remember, I will add "re-complete" wells at this post. Wells that are re-fracked will be followed elsewhere; see tag at bottom of blog.

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First Fracked Horizontal Well In The Bakken

• 8201, 87, CRL, Robert Heuer 1-17R, a re-entry in a Madison -- DRY -- hole; Sadler field, 319,444 lbs of 20/40 sand; short lateral; t3/04; cum 123K 7/16; cum 145K 3/23; source:
  
  
  
  http://www.willistonnd.com/usrimages/hammmonument.pdf

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New Permits for Re-Entry

May 24, 2023:

• 4079, 136, Scout Energy Management, Medora Heath-Madison Unit 19, Madison formation, Medora, t6/16; cum 561K 3/23;

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Reported. Not Listed Earlier

March 28, 2014, reported: 

• 11485, PA, XTO, Wegley 20-1, originally a Red River well completed in 1986; cum 173K bbls through June, 2013; recompleted March, 2013, into the Madison, with an IP of 13; 
  

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Two interesting KOG re-entry wells:

• See below: 18987, 223, WPX/Whiting/KOG, Two Shields Butte 14-21-16-2HS, t4/11; cum 541K 7/16; cum 758K 3/23;
  
• See below: 21513, 23, Whiting/KOG, Smokey 3-6-7-14HS, Bully, t2/12; cum 141K 7/16; cum 251K 3/23;
  

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16686, 379, MRO, Shobe 24-20H, Reunion Bay, t2/08; cum 302K 7/16; permitted for re-entry; production jump, 12/18; cum 566K 3/23;

28071, 1,628, Petro-Hunt, Sorenson 152-96-24C-13-2HR, Union Center, t10/14; cum 238K 7/16; cum 388K 3/23;

21947, 161, Thunderbird Resources LP/GMX Resources, Fairfield State 21-16-1H, St Demetrius, originally completed with 37 stages; 1.2 million lbs; Three Forks;; first IP, 9/12 = 161; second IP, 1/14 = 576; cum 63K 7/16; cum 109K 3/23;

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	3-2014	15	2880	2009	10210	2302	2125	177
BAKKEN	2-2014	12	2460	2661	8745	2256	2153	103
BAKKEN	1-2014	24	6904	6557	32509	5361	2355	3006
BAKKEN	12-2013	0	0	0	0	0	0	0
BAKKEN	11-2013	0	0	0	0	0	0	0
BAKKEN	10-2013	0	0	0	0	0	0	0
BAKKEN	9-2013	0	0	0	0	0	0	0
BAKKEN	8-2013	0	0	132	0	0	0	0
BAKKEN	7-2013	0	0	0	0	0	0	0
BAKKEN	6-2013	0	0	0	0	0	0	0
BAKKEN	5-2013	0	0	0	0	0	0	0
BAKKEN	4-2013	0	0	0	0	0	0	0
BAKKEN	3-2013	0	0	0	0	0	0	0
BAKKEN	2-2013	0	0	0	0	0	0	0
BAKKEN	1-2013	0	0	0	0	0	0	0
BAKKEN	12-2012	10	88	228	294	2	0	2
BAKKEN	11-2012	29	780	910	4397	883	633	250
BAKKEN	10-2012	27	833	680	5516	612	580	32
BAKKEN	9-2012	21	1111	897	7650	474	284	190
BAKKEN	8-2012	19	92	0	1115	46	0	46

17602, 215, CLR, Charlie Bob Creek 1-25H/Charlie Bob Creek 1-25RH, Ranch Coulee, t12/08; a re-entry well; cum 96K 7/16; production jumps 10-fold; link; cum 136K 3/23;

BAKKEN	3-2013	31	4451	4493	2775	4537	4537	0
BAKKEN	2-2013	28	5377	5440	3185	4792	4792	0
BAKKEN	1-2013	11	3469	3118	2521	2779	2779	0
BAKKEN	12-2012	0	0	0	0	0	0	0
BAKKEN	11-2012	6	45	367	92	29	29	0
BAKKEN	10-2012	31	310	225	437	122	122	0
BAKKEN	9-2012	21	250	225	337	111	111	0

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26927, 1,323, BR, Crater Lake 11-14MBH-R, Hawkeye, t12/14; cum 105K 7/16; cum 223K 12/22; off line/IA;
26928, 1,363, BR, Craterlands 11-14TFH-R, producing, t3/14; cum 143K 7/16; cum 244K 3/23;

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Interesting Case Studies

• 21513, 23, Whiting/KOG, Smokey 3-6-7-14HS, Bully, t2/12; cum 141K 7/16; cum 251K 3/23. This well was originally spud in late 2011 and completed/tested in February, 2012. For whatever reason (bad frack?) it never produced much oil -- almost dry. Then in early 2013, KOG requested permission to drill a sidetrack which they did. I assume they cemented off the old lateral well bore (but don't know for sure). The new sidetrack was fracked and is a nice well. Interestingly, the "new" IP is not provided. The well's original name was "Smokey 3-6-7-14H." The name of the new well (same permit/file number) is "Smokey 3-6-7-14HS." The "S" probably identifies the horizontal as a sidetrack, or that the horizontal runs south. This is a graphic of the well:
  
  
  
  
  18987, 223, Whiting/KOG, Two Shields Butte 14-21-16-2HS, t4/11; cum 541K 7/16; cum 758K 3/23;. This seems to be very similar to KOG's #21513 above. This well was originally spud in late 2010 and tested in early 2011 (April, 2011). It also didn't produce much, for whatever reason (appears not to have been fracked). KOG even put a pump on this well in September, 2011. A little over a year later, in December, 2012, KOG requested to re-enter this well and drill a sidetrack. It appears they drilled the sidetrack in February, 2013, and reported 30 days of production as of March, 2013: 39,986 bbls over 30 days (obviously a successful re-entry). In this particular case, the IP for the sidetrack was provided: 2,061. Like the well above, this well's name was changed from Two Shields Butte 14-21-16-2H to Two Shields Butte 14-21-162HS to signify that the horizontal is a sidetrack.
  
  
  

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25215, PA/33, Armstrong Operating, Scherr 1-18; Duperow 6/13; Deadwood 4/13; Dawson Bay 3/13; Madison, AR, 1/14; Duperow with minimal amount of oil; now drilling the Madison; Madison didn't amount to anything (last produced 3/14).

25731, 2,291, Whiting, Edie 41-13HR, Timber Creek, t10/13; cum 163K 7/16; cum 245K 3/23;

A Statoil re-entry well? Based on its name, this appears to be a re-entry well:

• 26971, 1,016 (reported June 5, 2014), Grayson Mill / Statoil, Ross-Alger 6-7 7TFH-R, Alger, Lot 4 31-156-92 Footages: 351 FSL 655 FWL; t5/14; cum -- No, it is not a re-entry well; in this case, the "R" stands for "revised." The original permit information was revised; t5/14; cum 76K 7/16; cum 174K 3/23;
  

A similarly named well:

• 26656, dry, Statoil, Ross-Alger 6-7 7TFH, Alger, Lot 4 31-156-92 Footages: 351 FSL 625 FWL

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1361, PA/177, Hess, Hawkeye-Madison Unit G-613 HR, Hawkeye oil field; t7/59; cum 617K 7/16; in 1956 this was drilled as a vertical well (the uppermost porosity of the South Hastings member of the Mississippian Mission Canyon formation). A lateral leg was drilled in December, 1999, in a southeast direction, same formation. A second lateral leg was drilled in 2000 in a northwest direction. The original vertical well produced 426,704 bbls through May, 1999. The well last produced any oil in January, 2013, and is shown as inactive. Cumulative oil as of 9/13 was 608,266 bbls. It is shown as a Madison well. No evidence of fracking, which of course makes sense; was IA; when I checked 5/14; it was A again.

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
MADISON	3-2014	31	442	371	13777	401	78	323
MADISON	2-2014	25	378	235	7721	597	0	597
MADISON	1-2014	0	0	0	0	0	0	0
MADISON	12-2013	0	0	0	0	0	0	0
MADISON	11-2013	0	0	7	0	0	0	0
MADISON	10-2013	6	31	26	1338	63	63	0
MADISON	9-2013	0	0	0	0	0	0	0
MADISON	8-2013	0	0	16	0	0	0	0
MADISON	7-2013	0	0	45	0	0	0	0
MADISON	6-2013	0	0	0	0	0	0	0

1295, PA/288, Hess, short lateral, Hawkeye-Madison Unit E-613HR, s12/56; t1/57; cum 240,003 3/14; this was a vertical that was re-entered and was a very short lateral; was A; when I checked 5/14, it was IA; last produced 6/12; 

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26297, 2,272, Whiting, Schilke 14-33RH, Pleasant Hill, t11/13; cum 121K 7/16; cum 187K 3/23;
26296, 1,415, Whiting, Schilke 14-33-2RH, Pleasant Hill, t11/13; cum 85K 7/16; cum 141K 3/23;
21483, 2,503, Whiting, Marsh 21-16TFH-R, Dutch Henry Butte,  t11/11; cum 218K 7/16; cum 279K 3/23;

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25338, PA/AR, Whiting, Jandt 14-1-2, Delhi oil field, a Red River well; spacing: W2; no production data, re-entered Interlake, AR, 10/13; no production data from that well;

11913 - stand-alone post

25753, 1,093, Grayson Mill / Statoil, Margaret 5-8 3TFH-R, Spring Creek, t6/14; cum 93K 7/16; cum 212k 3/23;

16071, PA/IA, Armstrong Operating, Hanisch 26-1, Moraine, this was a Duperow well producing since 3/06; recompleted as a Winnipegosis, 11/13; the Winnipegosis was dry (4/06); the Interlake was dry (4/06); the Duperow is PNA (10/13); cum 93K 3/14; (Duperow); last produced 8/15;

25994, 1,016, Ovintiv/Newfield, Barracuda 150-100-11-2-3HR, Sandrocks, t10/13; cum 123K 7/16; cum 212K 3/23;

27522, 4,207, Whiting, Flatland Federal 11-4TFHU, Twin Valley, t10/14; cum 369K 7/16; cum 644K 3/23;

27521, 5,002, Whiting, Flatland Federal 11-4HR, Twin Valley, t10/14; cum 388K 7/16; cum 519K 3/23;

27631, 90, Denbury Onshore, CHSU 41-35SHR 15, Cedar Hills, a Red River B well, t6/14; cum 4/15; no production since 4/15;

26850, 1.861, Oasis / QEP, Otis 4-28-33BHR (was Otis 29-32-28-33LL), Grail, t7/14; cum 316K  7/16; cum 505K 3/23;

22223, AR-->AB, Williston Exploration/CHK, Hutzenbiler 9-137-99 A 1H, wildcat, re-entering to test the Tyler, after CHK PNC's the Three Forks horizontal well; Tyler, AR, 2/14; was this well renamed, Loourdes 16-15 1TH; now operated by Medora Minerals, LLC?

27209, dry, Petro-Hunt, USA 153-95-4B-9-2HR, -- I think this "R" stands for a "revised" permit -- not a re-entry well.

Recompletion Wells -- Inaugural Post -- Denbury Enters the Tyler

Updates

May 24, 2014:

• 14713: producing again from the Madison, about 400 bbls/month; nothing from the Tyler it appears, now PNA (Tyler)
• 13453: still producing only from the Madision, about 1,300 bbls/month; Tyler, PNA

May 4, 2013: 

• 14713: no production from either formation in past 8 months
• 13453: producing only from the Madison, 1,300 bbls/month; Madison, t4/07; cum 128K 3/13; 

December 19, 2012:

• 14713: In October, no production from either formation. Cum 79K 10/12 from the Madison. 0 from the Tyler.
• 13453: In October, no production from the Tyler. Cum 521K 4/07, from the Tyler; cum 122K 10/12 from the Madison; the Madison is producing at 1,300 bbls/month.

Original Post

This is the inaugural entry for "recompletion wells" which are occasionally on daily activity reports.


April 19, 2012

• 14713, 30 (Madison), Denbury Onshore, South Fryburg 40-26, Fryburg Field, Billings County; s11/97; cum 78K 2/12 Madison Pool ; re-complete 4/12, Tyler Pool;

Spud date: 11/2/1997; Madison Pool; cum 78K 2/12
Re-complete date: 4/19/2012; Tyler Pool;
So this well was originally drilled back in 1997; has produced 78,000 bbls to date; a vertical well with one section spacing; now they are going back in to target the Tyler. This well is about 9 miles southwest of Belfield, in the southwest part of the state where the Tyler is being targeted.

A random example of another Madison / Heath well in this immediate area:

• 13453, 93 (Madison); 203 (Heath); Hess, Fryburg Heath-Madison Unit J-806HR, Fryburg field; t1993 (Heath); t2007 (Madison); cum 521K 2/12 (Heath); cum 110K (Madison) 2/12; the Heath last produced in 2007; the Madison is producing about 1,800 bbls/month.