One other point even if the oil play from 8,400 to 8,430 is of choice; deepest oil play of feasibility would be the first started. So the oil play at 8,650 if feasible would be drained first and the upper play later in time.
Sentiment: Strong Buy
Known 30 feet of play at 8,400 to 8,430 with 5% contained oil would be choice.
Known play at 8,090 may not be economic.
Sentiment: Strong Buy
Earlier this year SSN logged results to the pre-cambium basement.
Oily mud was observed at 8,090 feet and 8,430 feet and the mud analysis recorded up to 5% of contained oil at 8,650 feet. Recording at 8,400 feet, the well kicked and was shut in at the surface utilizing the blowout preventer. 1,620 psi was recorded on the annulus at this point, increasing to 2,080 psi with a 9.3 lbs per gallon mud weight recorded.
SSN will now determine the feasibility of each play.
Sentiment: Strong Buy
The Bluff 1-11 well was perforated within the 9,500 sand over the interval 7,738 to 7,754 feet, and
the well unloaded the completion brine almost immediately and flowed non inflammable gas at a
rate of 8 MMcfpd. The rate was relatively constant during the 41 hour flow period. The well flowed
on a 20 or 21/64ths inch choke at a tubing pressure of between 2,500 and 2,600 psig that
increased during the flow period. No formation water was evident. Gas samples were taken and
are in the process of being analyzed. The well is currently shut in for approximately 10 days whilst
the pressure response is measured.
The gas flow was not able to be ignited, and based on our previous samples was most likely
largely nitrogen as determined from the analysis of the wire line logs.
The test was designed to achieve several objectives all of which have been achieved or are
expected to be achieved:
1) To prove that a trap at the Bluff prospect exists, this has been demonstrated with a flow
rate that was sustained during a lengthy flow period. This enables the possibility of an oil
leg being present down dip of the nitrogen intersected in this well bore
2) To prove that the 9,500 sand was a viable reservoir, such that if an oil leg was present it
could be produced.
3) To enable clinical samples to be taken particularly for the presence of helium which is often
associated with nitrogen in natural gas reservoirs. These samples will also determine
whether the nitrogen has an organic source or not.
4) To determine through transient pressure analysis the presence of any fluid or reservoir
5) To determine reservoir characteristics such as reservoir pressure and permeability.
Sentiment: Strong Buy
Oil reserves in sedimentary rocks are the source of hydrocarbons and the byproduct of this Nitrogen trap is evidence that Oil is nearby.
The organics remaining are Hydrocarbons (alkanes)
methane, CH4 - one carbon and four hydrogenethane,
C2H6 - two carbon and six hydrogenpropane,
C3H8 - three carbon and 8 hydrogenbutane,
C4H10 - four carbon and 10 hydrogenpentane,
C5H12 - five carbon and 12 hydrogenhexane,
C6H14 - six carbon and 14 hydrogen
liquids (e.g. hexane, benzene, Xylene, and Toluene)
waxes (e.g.paraffin wax and naphthalene)
Nice DD Joe - Happy thanksgiving to Y'ALL.
Sentiment: Strong Buy
There is a 13K BOE/D difference between # 11 and 10 so let's hold onto the 11th spot as it would take two more rigs and 1 1/2 years to catch number 10. Tucker didn't do the math either but he's right here (and loud) so # 11 to 10 is a big jump.
Floyd will contract a 4th rig in North Dakota for Williams county for part of next year as needs to "Hold by Production" on some more leases. Currently all 3 rigs in North Dakota are working "pads". Numbers will look stronger as the NDIC mandated a flaring percentage in October so Floyd had to complete infrastructure. Four Bears, McGregory Buttes, and Antelope fields are hooked up so the Oil to Gas percentage will be a little lower as the capture MCF gas now.
From — Ashley Lindly petroleumnewsbakken
1 Continental Resources 102,115
2 Hess Corp. 90,435*
3 Whiting Oil and Gas Corp. 78,245
4 Burlington Resources Oil and Gas LP (ConocoPhillips) 72,021*
5 XTO Energy, Inc. (ExxonMobil) 64,471
6 EOG Resources, Inc. 63,405
7 Marathon Oil Co. 59,304
8 Statoil Oil and Gas LP 57,969
9 Oasis Petroleum North America 51,857
10 Kodiak Oil and Gas (USA) Inc. 51,286
11 Halcon Resources 38,423
12 QEP Energy Co. 38,185
13 WPX Energy Williston 32,040
14 Slawson Exploration Co., Inc. 27,485
15 Petro-Hunt 22,977
16 SM Energy Co. 20,533
17 Newfield Production Co. 19,103
18 Oxy USA Inc. (Occidental Petroleum) 17,688
19 Enerplus Resources USA Corp. 13,804
20 Triangle USA Petroleum Corp. 11,580
21 Fidelity Exploration and Production Co. (MDU) 11,202
22 Hunt Oil Co. 9,664
23 Zavanna LLC 8,218
24 Murex Petroleum Corp. 7,179
25 Abraxas Petroleum 5,939
26 Samson Resources Co. (KKR and Co.) 5,817
27 Baytex Energy USA 4,214
28 Emerald Oil, Inc. 4,196
29 American Eagle Energy Corp. 3,647
30 Sinclair Oil and Gas Co. 2,166
31 Liberty Resources Management Co. 1,838
32 Crescent Point Energy U.S. Corp. 1,644
33 Arsenal Energy USA Inc. 1,306
34 Petrogulf Corp. 1,028
35 Denbury Onshore, LLC 972
36 Cornerstone Natural Resources 884
37 North Plains Energy 747
38 True Oil LLC 730
39 Mountain Divide (Mountainview Energy) 632
40 SHD Oil and Gas 614
41 Thunderbird Resources LP 575
42 Armstrong Operating 494
43 Bakken Hunter, LLC 342
44 Rim Operating, Inc. 119
45 Windsor Energy Group 119
46 Resource Drilling 107
47 Legacy Reserves Operating LP 88
48 Texakota 40
49 Tracker Resource Development III 35
50 Condor Petroleum 33
Information derived from the preliminary September 2014 Oil and Gas Production Report published by the
North Dakota Industrial Commission, Department of Minerals’ Oil and Gas Division. This is oil produced by
wells operated by these companies; it does not identify the percentage of oil from the Bakken petroleum system, including Bakken, Three Forks.
DD on Continental and Halcon lower bench wells Three Forks benches 2and 3 were separated by 880 feet at depth and alternated.
The companies also had an either or situation regarding Three Forks in that they chose a bench 1, 2, or 3 but not drilling each under one another. If bench 3 was chosen they did that first and let that settle for 3 ½ to 4 months. Continental had 11 Rollefstad wells and they were about 90% of a Bakken and are over 100K BOE in 5 months (after the settle period).
SSN Bootleg 8 messed up the other wells above and they had to be cleaned out. TB skidded over Ironbank 8 well.
Now that was the bad news.
Ironbank 6 and 7 should be complete and that along with the 35 stage Bakken Billabong as in process or being FRAC’D.
Wait I ran out of fingers and toes to count these wells; might need my slide rule.
Billabong , Sail & Anchor, Blackdog , Tooheys , Coopers , Lil Creature , Harstad 1-15H, LEONARD 1-23H,, GENE 1-22H RODNEY 1-14H, GARY 1-24H, EARL 1-13H, EVERETT 1-15H , Matilda Bay 1, Matilda Bay 2, Bootleg 4, Bootleg 5, Ironbank 4, Ironbank 5, Bootleg 6, Bootleg 7,Ironbank 6, Ironbank 7, Bootleg 8, Gladys
All on line numbers coming out on next Operational update.
On hold Ironbank 8, 9, 10, 11, 12, 13, 14 Bootleg 9, 10, 11, 12, 13, 14
Ladies and gentlemen it is time, Strong Buy.
HAVE A HAPPY THANKSGIVING!
Sentiment: Strong Buy
Section 35 of township 148 and range 94 reports 3 wells with gas infrastructure hooked up.
Only 89, 94, and 99 days of production reporting and each over 100K BOE sold.
File # 25598 has 1,066 BO Jul, 33,046 BO Aug, 30,225 BO Sep and 30,323 BO Oct for 94,660 BO with 63,922 MCF for 105,325 BOE
File # 25597 has 823 BO Jul, 40,474 BO Aug, 28,297 BO Sep and 28,212 BO Oct for 97,806 BO with
73,522 MCF for 110,060 BOE
File # 25596 has 1,286 BO Jul, 36,481 BO Aug, 29,234 BO Sep, and 30,067 BO Oct for 97,068 BO with 71,627 MCF for 109,006 BOE
Halcon sustaining in North Dakota but October was shy of September as Patterson 268 rig was working in proximity of 4 Eagle Nest wells file #’s 20172, 20918, 20919, and 20173 so they are shy.
Good news is that September 2014 was Halcon’s best month in September 2014
You are right! Frontier Rig 24 skidded right by Ironbank 8. Finished lateral on Ironbank 7. The only reason would be that determination of the FRAC of Bootleg 8 which was also a Three Forks bench 2, caused FRAC sand to develop in the upper wells. The rig is done as it's all work over from here including Billabong. Off to Rainbow (Bootleg 8 on hold) it looks to be a farm-in for Rainbow now.
IRONBANK 8? About a 1/2 dozen places you would have to interpret and combine data.
First step is the SF IPAA presentation from the home site samsonoilandgas
Slide 19 & 20 depict Ironbank 8.
First you can see Bootleg 8 and Ironbank 8 are Three forks bench 2 with Bootleg wells ar Westerly and Ironbank Easterly. The three forks formations are below the Bakken and you would have to measure depths across the laterals and compare from the well files to determine the depth differences.
You need the ND state case files and Plat plan to view the layout but David Ninke from Samson oil provides and depicts information in the TB slides.
Here is all you see in ND state
NDIC File No: 29076 API No: 33-105-03659-00-00
Well Type: ON CONFIDENTIAL STATUS
Location: NESW 14-154-99 Footages: 1340 FSL 2200 FWL Latitude: 48.158180 Longitude: -103.379178
Current Operator: SLAWSON EXPLORATION COMPANY, INC.
Current Well Name: IRONBANK 8-14-13TF2H
The rest you need to build from the permit and case file and time the rig movement. it's actually quite easy once you get the hang of it. Check the San Fran IPAA presentation and see if you can relate to the different oil plays and layers.
How many oil companies that you own have been to bench 2 of Three Forks?
Rather new oil play and the Bootleg wells weave under 3 Bakken plus half of Rodney well.
This company has done well utilizing premier operators (Slawson and Continental) so my advice to come back into SSN is do tour TB complaining as this stock board has folks who enjoy you opinion (zoom included).
After the FRAC of Bootleg wells 4, 5, 6,7, & 8 which were Three Fork Benches 1 & 2. Some of the existing wells in the Bakken (87 feet above) had to be reworked on the Tofte 2 Pad to clean out sand of the Coopers, Tooheys well bore from the FRAC sand. Little Creature is scheduled to be cleaned out be next. A separate work over rig is being utilized to perform this task. The new Bootleg 4, 5 ,6 ,7 , and 8 have been cleared and are flowing. The work horse "Big Rig" Frontier Rig 24 continues on the Easterly Ironbank wells and Ironbank 6 & 7 vertical portion and casing set, now on Ironbank 8 vertical to the Three Forks second bench. The lateral portion of these three wells are scheduled to commence in 8 days as the Frontier 24 skids over on the pad.
Ironbank 4 & 5 wells were previously drilled, FRAC and well completed with 5 days flow-back. Flow will continue and IP's reported after Ironbank 8 through the Three Forks bench 2 IP. The "Big Rig" will work the three remaining Ironbank wells 6,7, and 8 laterals (about 8 days on bench 1 and 9 on bench 2). FRAC of the 3 remaining wells scheduled after lateral completion. The Billabong 35 stage Bakken also will be fit in at this time.
With the completion of the lower benches of Bootleg (West); all the Bootleg and upper wells are operational and producing. Ironbank are East 4 & 5 have FRAC and flow, 6,7, and 8 completing. These are in play... say good night shorts.
ND File # __ Well name
24794 __ Billabong
24795 __ Sail & Anc
24796 __ Blackdog
26020 __ Tooheys
26019 __ Coopers
26698 __ Lil Creature
16481 __ Harstad 1-15H __
17446 __ LEONARD 1-23H
18009 __ GENE 1-22H
18054 __ RODNEY 1-14H
18824 __ GARY 1-24H
19328 __ EARL 1-13H
20510 __ EVERETT 1-15H
27635 __ Matilda Bay 1
27636 __ Matilda Bay 2
27912 __ Bootleg 4
27911 __ Bootleg 5
28054 __ Ironbank 4
28053 __ Ironbank 5
27914 Bootleg 6
27915 Bootleg 7
28979 Ironbank 6
28980 Ironbank 7
29076 Ironbank 8
29022 Bootleg 8
28457 __ Gladys 1-20
Ironbank 4 & 5 have also flowed 4-6 days with 6,7 and 8 early December.
Billabong by mid December and Matilda Bay 1 rework in December.
December surge is over 5X current rate. Half the wells contributing now, TB numbers (for once) are low and have been realized.