Reason #5 Why I Love To Blog -- The Amber Renee; Permitted For Re-Entry -- December 3, 2014

 Locator: 100100AMBER.

 

Updates

September 28, 2023: these great wells are coming off line. See this note.

March 16, 2022: hallelujah! Murex finally reporting the Amber Renee as a completed DUC. More to follow.

• 36887, 448, Murex, Amber Renee 25-36H-R, Sanish, first production, 8/21; t--; cum 71K 1/22. Total depth, 20,272 feet. Frack: 47 stages; 10.25 million lbs proppants.
• spud date: October 1, 2019
• cease drilling: October 30, 2019
• curve completed overnight in about twelve hours
• lateral drilling began in the afternoon on October 26, 2019; TD in the afternoon on October 30, 2019 (four days); completed in two runs. The second run from 18,312' to 20,272'.
  

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	1-2022	31	10147	10147	689	20219	19816	0
BAKKEN	12-2021	31	10887	11087	870	21382	19875	1104
BAKKEN	11-2021	30	11255	11255	1064	19430	17960	1080
BAKKEN	10-2021	31	13372	13472	1378	21344	19666	1275
BAKKEN	9-2021	29	13075	13136	2282	17713	10699	6624
BAKKEN	8-2021	30	12650	12289	3328	15589	14631	568

March 16, 2022: So, what about the Sophia Drake?

• 36888, 458, Murex, Sophia Drake 25-36H-4, Sanish, first production, 10/20; t--; cum 281K 1/22; more to follow. Frack: 48 stages; 10.05 million lbs proppant.
  
• spud date: September 28, 2019
• cease drilling: October 22, 2019
• the curve took almost 24 hours to complete
• lateral began at around noon, October 18, 2019; TD reached about dinner time on October 22, 2019; only 4.5 days; completed in one run. 
  
• initial production:
  

BAKKEN	4-2021	30	19657	19384	811	22839	22449	0
BAKKEN	3-2021	31	20687	21642	21250	21194	21194	0
BAKKEN	2-2021	28	19229	19204	1114	19558	19558	0
BAKKEN	1-2021	31	22568	22162	1570	21984	21984	0
BAKKEN	12-2020	31	21890	22135	2810	20156	20156	0
BAKKEN	11-2020	30	21568	21153	3861	13823	13823	0
BAKKEN	10-2020	10	5559	4447	2952	2054	1924	0

March 16, 2022: other wells of interest near Sophia Drake and Amber Renee:

• 16839, total depth, 13,719 feet; cum 557K 1/22;  nice jump in production; see full production profile here;
  
• 17263, total depth, 19, 230 feet; cum 1.209 million bbls; 1/22; perhaps a small halo effect; see full production profile here.
  

August 24, 2019: I've seen the "R" in permits mean different things to different folks, to include, "revised" and "re-enter." In this case the Sophia Drake was never spud, and the Amber Renee was a great well until it was taken off line. Now, the Sophia Drake (with a slightly new name, and a new permit) will be drilled; and, a "different" / "new" Amber Renee will be drilled, see graphic:

July 2, 2016: update. Why the Amber Renee is on TA status. 
 

Original Post

 

With a long post like this, there may be factual and typographical errors. If this information is important to you, go to the source.

I don't own any minerals in the Bakken. One well means nothing more to me than any other well except for the specifics about the well. But I do have to say that there are a few wells in the Bakken, that for whatever reason, "stick out" for me. The "Amber Renee" well is one such well.

First, I like the name. Amber Renee. A perfect name for a young woman and/or a Bakken well. On the other hand, not a good name for a Kentucky Derby thoroughbred. For the latter, a better name, Runstowin.

Second, the Amber Renee got my attention when after producing about 800,000 bbls of oil, the operator shut it down. That gets my attention.

But now this. In the December 3, 2014, daily activity report, Murex has indicated that it wants to re-enter the well:

PERMITTED FOR RE-ENTRY:
#18408 - MUREX PETROLEUM CORPORATION, AMBER RENEE 25-36H, NWNW 25-154N-91W, MOUNTRAIL CO., 250' FNL and 510' FWL, DEVELOPMENT, SANISH, API #33-061-01156

When you look at the scout ticket below, note:

• IP
• total production to date
• "F" -- no indication this well has been put on a pump (but sometimes there are reporting errors)
• how very, very little water has been produced; great expense for wells with lots of water to be disposed
• the monthly production of this well when it was taken off-line

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As noted above, I've enjoyed following this well. Here are the previous posts regarding this well:

From June 19, 2014:

Back on line:

• 18408, 1,945,  Amber Renee 25-36H, Sanish; one mile to the west of the Chandler James; t2/10; F; 821K 12/13 -- 661K in first two years; no pump; still 9K/month 1/13; IA 1/14; now back on line apparently (shown as "A" but still no new production except a bit of natural gas sold in 4/14); on January 27, 2016, I noted this well was now "AB" -- abandoned;

From March 30, 2014:

In the Sanish, Murex has taken the Amber Renee off-line (as of January, 2014). It is now listed as "inactive." Could it be related to activity planned for the Jacob Daniel well south of the Amber Renee? Right now I don't see any other activity on the GIS map server.

[For some background to Murex, a reader noted that the company was featured in a Forum article some years ago. I remember that article and have it linked elsewhere on the blog. Here is the original story.]

The Amber Renee is a huge well. It was spud December 21, 2009, and drilling stopped on January 12, 2010. A frac tree was installed in May, 2010. It looks like it was fracked with 14 perforations and with slightly less than 900,000 lbs of sand. It was tested February 27, 2010, with an IP of 1,945. With a TD of 16,000 feet it extended slightly longer than a short lateral (but was planned as a long lateral based on a 1280-acre drilling unit) in the Sanish. A marked increase in gas (10,000+ units) was noted in the lateral. Interpretation of other data suggested a natural fracture. At 16,050 feet there were indications that there might be communication with a neighboring well (Jacob Daniel 25-36H, now Jacob Daniel 25-36H-RE (#16839), a short lateral) and the drilling was stopped.

• 18408, 1,945, Murex, Amber Renee 25-36H, t2/10; cum 821K 8/14;

From April 15, 2013: 

The Amber Renee well was completed/tested almost exactly three years ago. It has produced about 750,000 bbls in those three years. It is still producing about 10,000 bbls/month, and is not on a pump (based on the scout ticket)

• 18408, 1,945,  Murex, Amber Renee 25-36H, Sanish, one mile to the west of the Chandler James; s12/09; t2/10; F ; "long" lateral; cum 750K 2/13; 

This well is considered a "long lateral" but, in fact, is quite short, barely extending in to the second section;  the Chandler James is in the same section, running parallel to Amber Renee, but is a "full" long lateral.

From August 1, 2011:

18408, 1,945, Amber Renee 25-36H, was spudded December 21, 2009. It still is producing 30- to 35,000 bbls/months. As of June 30, 2011, Amber Renee had produced 476K bbls of oil (at $50/bbl = $24 million). I believe the Amber Renee was a 14-stage frac.

From February 21, 2011:

18408, 1,945, Amber Renee 25-36H, was spudded December 21, 2009. It still is producing 30- to 35,000 bbls/months. As of 5/13, Amber Renee had produced 777K bbls of oil (at $50/bbl = $24 million).

From "Things To Follow Up On":

18408: flowing, no pump; ever fracked? In same section as 17263. As of October 25, 2014, no frack data in file; sundry form scanned in but no frack data.  Also, 17500: no frack data and no explanation why well taken off-line recently. Sister well #18912 was taken off line in 2014 at same time #17500 taken off-line.

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In one of the entries above, it was noted that the Amber Renee might have been interfering with the Jacob Daniel. From the GIS map server, note the Amber Renee (#18404) to the northwest; Chandler James to the northeast; and, Jacob Daniel to the south:

************************************************

The scout ticket with the production profile only since March, 2013:

NDIC File No: 18408    
Well Type: OG     Well Status: IA     Status Date: 2/25/2010     Wellbore type: Horizontal
Location: NWNW 25-154-91      Latitude: 48.138199     Longitude: -102.329314
Current Operator: MUREX PETROLEUM CORPORATION
Current Well Name: AMBER RENEE 25-36H
Total Depth: 16050     Field: SANISH
Spud Date(s):  12/21/2009
Completion Data
   Pool: BAKKEN     Comp: 2/25/2010     Status: F     Date: 2/27/2010     Spacing: 2SEC
   Pool: BAKKEN     Status: LOC     Date: 12/3/2014
Cumulative Production Data
   Pool: BAKKEN     Cum Oil: 821537     Cum MCF Gas: 573256     Cum Water: 6856
Production Test Data
   IP Test Date: 2/27/2010     Pool: BAKKEN     IP Oil: 1945     IP MCF: 230     IP Water: 0

Monthly Production Data

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	10-2014	0	0	0	0	0	0	0
BAKKEN	9-2014	0	0	0	0	0	0	0
BAKKEN	8-2014	2	51	133	0	61	0	53
BAKKEN	7-2014	0	0	0	0	0	0	0
BAKKEN	6-2014	0	0	0	0	0	0	0
BAKKEN	5-2014	0	0	0	0	0	0	0
BAKKEN	4-2014	0	0	0	0	1	1	0
BAKKEN	3-2014	0	0	0	167	0	0	0
BAKKEN	2-2014	0	0	0	0	0	0	0
BAKKEN	1-2014	0	0	0	0	0	0	0
BAKKEN	12-2013	30	307	272	5	449	403	0
BAKKEN	11-2013	30	6697	6702	57	9874	9874	0
BAKKEN	10-2013	31	6994	6999	52	14292	14292	0
BAKKEN	9-2013	30	6799	6809	52	10402	10402	0
BAKKEN	8-2013	31	7512	7555	55	11286	10919	367
BAKKEN	7-2013	31	7971	8001	67	11733	11733	0
BAKKEN	6-2013	30	8148	8333	62	11581	11581	0
BAKKEN	5-2013	31	8299	8196	68	12270	12270	0
BAKKEN	4-2013	30	9058	9173	105	12578	12578	0

But there is more to the story. Below is the production profile of the Jacob Daniel well in late, 2009, through late, 2010 (see if you spot the obvious).

The Jacob Daniel (during the period the Amber Renee was fracked):

BAKKEN	9-2010	30	8635	8713	126	4391	4391	0
BAKKEN	8-2010	31	9049	9220	441	3744	3744	0
BAKKEN	7-2010	15	3102	2382	1473	1692	1692	0
BAKKEN	6-2010	8	60	0	0	1	1	0
BAKKEN	5-2010	0	0	0	0	0	0	0
BAKKEN	4-2010	0	0	0	0	0	0	0
BAKKEN	3-2010	31	0	0	0	0	0	0
BAKKEN	2-2010	1	7	225	0	1	1	0
BAKKEN	1-2010	14	844	913	0	370	370	0
BAKKEN	12-2009	31	5129	5715	0	2889	2889	0
BAKKEN	11-2009	30	5297	5338	0	3072	3072	0

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But there is even more to the story. There is a third well in that section, the Chandler James. This is the production profile of the Chandler James around this same period of time:

BAKKEN	5-2010	31	12199	11575	74	6068	6068	0
BAKKEN	4-2010	30	18751	18925	67	9592	9592	0
BAKKEN	3-2010	31	21395	22002	67	9335	9335	0
BAKKEN	2-2010	28	20769	20563	50	10242	10242	0
BAKKEN	1-2010	31	18396	18575	23	9085	9085	0
BAKKEN	12-2009	23	20106	19617	57	10859	10859	0
BAKKEN	11-2009	29	22025	22961	66	12131	12131	0
BAKKEN	10-2009	31	37584	37274	138	21062	21062	0
BAKKEN	9-2009	30	38330	38627	293	22059	22059	0

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For the rest of the discussion, I am going to assume that:

• the Amber Renee was completed/fracked/tested in late February, 2010
• the two other wells in this section (Jacob Daniel and Chandler James) were NOT re-fracked or re-worked during this same period of time
• that there would be little reason for the operator to manipulate production during this period of time

With those assumptions, there are two observations resulting in two conclusions (one "firm" and one "maybe, but it's a stretch."

The first observation and first conclusion: Note that the Amber Renee was fracked in February. The horizontal to the south (Jacob Daniel), coming close to the Amber Renee, was taken off-line during that time period. When it came back on line, its production jumped significantly, from 5,000 bbls/month to 9,000 bbls/month. If the assumptions are correct, it's hard not to conclude that fracking the Amber Renee did not affect the Jacob Daniel, at least for a short period of time (double negatives, but I think you understand what I'm trying to say).

The second observation: the third well in that section, the phenomenal Chandler James, parallels the Amber Renee but is much farther way than the Jacob Daniel. The Chandler James was not taken off-line during the time period when the Amber Renee was fracked. Look closely at the production profile of the Chandler James prior to February, 2010, before the Amber Renee was fracked -- almost a typical "Bakken" decline, starting September, 2009, at 38.3K; then to 37.6K the following month; then 22.0K; then 20.1K, and finally 18.4K in January.

Interestingly enough, there was a jump in the following month, the month that the Amber Renee was fracked. The Chandler James went from 18.4K in January, 2010, to 20.8K in February, and and an even bigger increase the following month to 21.4K before starting to taper.

If the assumptions are correct, it's hard to argue that fracking the Amber Renee had not effect on the Chandler James.

The second conclusion: "maybe, but I think it's a stretch." The two parallel horizontals are so far away it's hard to believe fracking the one had an effect on the other. So, I won't argue with folks who suggest that my assumptions are wrong, or that it's simply an anomaly, a not unusual variation in monthly production in the oil patch. But it is interesting.

By the way, this whole discussion has huge implications if the slump in the price of oil persists for two years.