Almost 500K Bbls Crude Oil In Slightly More Than One Year Of Production -- February 6, 2020

Re-posting.

I posted this earlier, when it came off the confidential list, but it was part of a longer post. I want to post this as a stand-alone post so it can be highlighted at the sidebar at the right. We didn't have the frack data at the original post. Here's the pertinent frack data: 56 stages; 11.4 million lbs; Three Forks, first bench;

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The MRO Well

The previous monthly record?

• 32975, 9,166, MRO, Jerome USA 12-23TFH, Reunion Bay, t9/18; cum 474K 3/21; TD: 23,722 feet; permit: Three Forks B2; stimulation: Three Forks B1; 56 stages; 11.4 million pounds proppant; sundry form dated September 4, 2017, name change and target changed from second bench to first bench;
  

Monthly Production Data:

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	4-2019	30	34767	34915	32321	76106	25649	47196
BAKKEN	3-2019	31	52081	52872	46748	85724	16771	62683
BAKKEN	2-2019	22	38759	37401	35904	56589	21944	31313
BAKKEN	1-2019	1	28	959	11	36	1	32
BAKKEN	12-2018	29	37430	37048	40410	59261	15451	39814
BAKKEN	11-2018	28	56299	56577	55748	99904	32294	63510
BAKKEN	10-2018	31	133711	133069	124441	201573	35899	156881
BAKKEN	9-2018	5	19416	19229	17619	20980	0	19699

Note: looking at the NDIC map, a Slawson well, under the lake, looks like the horizontal was a full three-section lateral, or a "3-mile well." The MRO wells looks like the horizontal, also under the lake, was 2.5 sections or a "2.5-mile well."

In the same area:

• 32973, 9,061, MRO, Joshua USA 13-23TFH-2B, Three Forks B2, 56 stages; 11.4 million lbs, Reunion Bay, t9/18; cum 393 12/19; 11.6 million gallons of water; 89% by weight; see this post with production profile;

Graphics:

Re-Posting: This MRO Well Extrapolates To 107K Bbls Crude Oil Over 30 Days -- October 17, 2018

Updates

March 9, 2019: I could have picked any well in this group to highlight. They are incredible. Production data for #34484, Yellowface:

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	1-2019	0	0	0	0	0	0	0
BAKKEN	12-2018	0	0	373	0	0	0	0
BAKKEN	11-2018	26	38121	38149	36122	55231	22311	30136
BAKKEN	10-2018	22	64629	64806	97592	100750	25283	71165
BAKKEN	9-2018	22	59992	59414	56538	63182	0	59228

 

Original Post

I am completely blown away by this well.  I am re-posting the original note with minor edits and updates.

In addition to everything else, note that it is a Three Forks upper bench well. Years ago, Lynn Helms famously said that the Three Forks was likely to be better than the middle Bakken on a well-to-well comparison. For newbies: that would be comparing a TF with a MB drilled from the same pad, using optimized completion strategies on both.

Also, note: the drilling unit has eleven horizontal wells; room for many more.

For newbies: when the boom began, folks were drilling wells anticipating an EUR of 375,000 bbls.

The geologist's report and the fracking data is yet to be scanned in at the NDIC site.

The spacing unit: 1600 acres according to the permit. S23 &24T151 R94 - W/2 19T151 R93;

Note the IP: 8,887. Record IPs, FAQ 9 at this post.

Staggering:

• crude oil: extrapolates to 107K over 30 days
• natural gas: extrapolates to  17K boe over 30 days
• total boe extrapolates to 124K over 30 days

NDIC File No: 32972     API No: 33-053-07751-00-00     CTB No: 219446 Well Type: OG     Well Status: A     Status Date: 8/29/2018     Wellbore type: Horizontal Location: NESE 22-151-94     Footages: 1676 FSL 749 FEL     Latitude: 47.881082     Longitude: -102.688255 Current Operator: MARATHON OIL COMPANY Current Well Name: LAMARR USA 13-23TFH Elevation(s): 2193 KB   2166 GR   2179 GL     Total Depth: 23740     Field: REUNION BAY Spud Date(s):  11/16/2017 Casing String(s):  9.625" 2042'   7" 11164'   Completion Data    Pool: BAKKEN     Perfs: 11266-23603     Comp: 8/29/2018     Status: F     Date: 8/31/2018     Spacing: ICO Cumulative Production Data    Pool: BAKKEN     Cum Oil: 17765     Cum MCF Gas: 16877     Cum Water: 10005 Production Test Data    IP Test Date: 8/31/2018     Pool: BAKKEN     IP Oil: 8887     IP MCF: 10628     IP Water: 5541

Monthly Production Data Pool Date Days BBLS Oil Runs BBLS Water MCF Prod MCF Sold Vent/Flare BAKKEN 8-2018 5 17765 17352 10005 16877 0 15720

Well file:

• geologic report: not yet scanned in
• fracking report: not yet scanned in

FracFocus: 33-053-07751

• fracked 6/25/2018 - 7/9/2018
• 10.8 million gallons of water (typical amount seen in Bakken 2.5); 
• water: 88.6% by mass
• sand: 11% by mass

Other posts:

• December 22, 2017
• September 12, 2018: 
• September 12, 2018: #19446; it is close to this one -- look at that huge IP -- 32971, 8,702, MRO,Whitebody USA 14-23H, Reunion Bay

Wells in graphics below:

• 33980, 6,113, MRO, Michelle USA 14-14TFH, t10/18; cum 144K 1/19;
• 33981, 5,386, MRO, Phyllis USA 11-23H, t11/18; cum 128K 1/19;
• 33982, 6,325, MRO, Clara USA 11-23TFH-2B, t10/18; cum 184K 1/19;
• 21172, 5,067, MRO, TAT USA 12-23H, t11/18; cum 142K 1/19;

• 32975, 9,166, MRO, Jerome USA 12-23TFH, t9/18; cum 265K 1/19; only 1 day in 1/19;
• 32974, dry, MRO, Jorgenson USA 12-23H,
• 32973, 9,061, MRO, Joshua USA 13-23TFH-2B, t9/18; cum 223K 1/19;

• 19446, 24 (no typo), MRO, TAT USA 13-23H, Reunion Bay, 22 stages; 3.2 million lbs;, t2/11; cum 91K 8/18; was off line for the past year (about 11 months); was on line for 12 days in 8/18; it took 105 hours to drill the vertical (in 2018, they can drill these verticals in 55 hours); the lateral was drilled in 186 hours (in 2018, they can drill these laterals in 55 hours); the report did not say how long it took to build the curve (assume about 5 days); gas shows reached 3,000 units in some areas, but generally weak throughout most of the lateral; the lateral was 95% within the zone and 100% within the middle Bakken. Sporadic activity; after months of no production, 6 bbls on one day in 1/19;

• 34484, IA/6,504, MRO, Yellowface USA 13-23H, t9/18; cum 163K 1/19; off line as of 12/18:
• 32972, see above;
• 32971, see this post;
• 32970, 4,313, MRO, Loren USA 13-23TFH, Antelope, t8/18; cum 205K 1/19; geologist's report and frack data not yet posted over at NDIC; 1600-acre drilling unit;

The graphics:

WPX Reunion Bay Wells -- Random Note -- January 28, 2018

WPX in Fort Berthold Indian Reservation has quite an interesting history.

WPX is now reporting some incredible wells.

From my "FAQ" page with regard to record IPs:

• 33398, 3,291, WPX, Hidatsa North 14-23HX, Reunion Bay, huge well; if this is not a typo, could be a new record: 85,032 bbls in the first full month, Three Forks, 51 stages; 8.6 million lbs; t9/17; cum 167K 11/17;
  

Now, this WPX well to be reported later this week:

This will be a fun well to watch this week, posted January 28, 2018:

• 33381, conf, WPX, Mandan North 13-24HW, Reunion Bay, API 33-061-04011, a huge well; 75K in first full month; 65K in second full month; FracFocus shows this well was fracked 9/15 - 22/2018; 8.7 million gallons of water; proppant, 9.95%
• 8.7 million gallons = 72 860 973.755 lbs
• 89.6% of what = 72 860 973.755 lbs; 81,318,051 lbs
• 9.95% x 81,318,051 lbs = 8,091,146 lbs
• so, we'll see when the NDIC data is reported whether proppant was about 8 million lbs

Production data:

Date	Oil Runs	MCF Sold
11-2017	65327	37613
10-2017	75779	17539
9-2017	101

A Graphic Of The Area Where CLR Wants To Drill 25 Wells On An Existing 2560-Acre Spacing Unit In The Elm Tree-Bakken Oil Field -- April 11, 2016

Updates

June 8, 2018: this 2560-acre drilling unit is being updated. 

October 29, 2016: a new screenshot of this area has been placed at this post.

Original Post 

In the April hearing dockets, case #25003 (note: this is a case number, not a permit number):

• 25003, CLR, Elm Tree-Bakken, 25 wells on an existing 2560-acre unit, sections 14/23/26/35-153-94, McKenzie:

This is the screenshot of the area of the 4-section (2560-acre unit) stand-up drilling unit (depicted in part by the thick purple north/south arrow) -- shown are parts of section 23 and 26. Section 14 is to the far north, and section 35 is to the south.  If the wells shown are all spaced for 1280-acres, then the 25 wells "on the existing 2560-acre unit" would be in addition to the wells already sited here.