US Will Help Brazil Develop Their Oil Assets For Future US Imports

See link.

Now, with a seven-year offshore drilling ban in effect off of both coasts, on Alaska's continental shelf and in much of the Gulf of Mexico — and a de facto moratorium covering the rest — Obama tells the Brazilians:

"We want to help you with the technology and support to develop these oil reserves safely. And when you're ready to start selling, we want to be one of your best customers."

Obama wants to develop Brazilian offshore oil to help the Brazilian economy create jobs for Brazilian workers while Americans are left unemployed in the face of skyrocketing energy prices by an administration that despises fossil fuels as a threat to the environment and wants to increase our dependency on foreign oil.

I cannot make this stuff up. 

EOG Featured on CNBC's "Mad Money" With Jim Cramer -- March 21, 2011

This is at least the fourth segment on the Bakken that Jim Cramer has featured on his show in the last 30 days.

It is almost as if he has just discovered the Bakken.

For Investors Only: NOG -- Questions Regarding Valuation -- Bakken, North Dakota, USA

Updates

May 13, 2011: On wives, friends, and beauticians.

March 29, 2011: NOG bounces back. 

March 28, 2011: NOG provides operational update. Responds to recent "bear raid."

March 28, 2011: SeekingAlpha.com replies. All smoke, no gun.

March 24, 2011: NOG has leveled off; now going back up.

March 24, 2011: Bakken Shale Discussion Group weighs in. 

March 24, 2011: My hunch -- a lot of folks are waiting for NOG to level off and then they will buy back in. Traders only make money with volatility. This will be very interesting to follow.

March 24, 2011: The Wall Street Journal weighs in.  Be sure to read the comments.

March 23, 2011: Motley Fool says "no" to NOG.

March 23, 2011: It appears the article has its intended effects. It will be interesting to see how this all plays out. I would think that if the stock is oversold, the company would go back in and aggressively buy back stock, or there would be increased insider buying. If not, one has to wonder how relevant the research is. Regardless, it was good to see this happen: it keeps folks like me who are inappropriately exuberant about the Bakken grounded, cautious, and diversified. The next three quarters will be the most important quarters in NOG's relatively young history as a billion-dollar market cap company. My enthusiasm for NOG's unique business model has not waned one iota. 

March 22, 2011, 2200 hrs: here's another blog that has piggy-backed unto the original Street Sweeper blog questioning the valuation of NOG, and shorting the stock. The blog appears to be coming out of Australia, and it sounds like in addition to questioning NOG, he questions the entire Bakken. Again, I am glad the article on NOG came out: it keeps me grounded, cautious, and diversified. Also, if NOG pulls back significantly, it provides another opportunity to accumulate more shares.

ORIGINAL POST

Someone alerted me to this 2-part story regarding the valuation of NOG:

http://thestreetsweeper.org/undersurveillance.html?i=1665
http://thestreetsweeper.org/undersurveillance.html?i=1671

The story was picked up by a contributor to SeekingAlpha.com and can be found here:

http://seekingalpha.com/article/259340-will-growth-spurt-last-for-northern-oil-and-gas?source=yahoo

I have always been a fan of NOG's business model. It will be interesting to see how this plays out.

The contention is that NOG is not accounting for the huge decline rates in Bakken wells. The articles do not discuss the effect $100 oil has on the company, or the valuation. I would suspect many of these companies are being valuated on $60 or $75 oil at a time when more and more pundits see $100 oil for the foreseeable future.

Update: for traders, this may be an opportunity to sell and buy back in when NOG settles at its new "floor."

For long term investors, this could be typical volatility that will work itself out over time.

Update on the Scanlan 3-5H, #18770, Truax Field

Someone asked about the "Scanlan 3-5H."

Assuming we are talking about:

• 18770, 819, North Plains Energy, LLC, Scanlan 3-5H, Truax field, Middle Bakken; 21 stages; 2.1 million lbs

Here is the most recent NDIC data:

• This well was spudded on 6/4/10.
• The IP was tested on 9/8/10.  (Again, three months from spud date suggests a short, but not excessively long delay in fracking,)
• The IP was 819.

Production data:

• In September, 2010, for 23 days it produced 19,039 bbls;  published "runs": 18,400 and no natural gas produced or sold or flared
• In October, 2010, 27 days, it produced 11,789 bbls; published "runs" of 11,770 bbls; 102,000 cubic feet of natural gas produced; 77,000 cf flared; none sold
• In November, 2010: 18 days; 6,319 bbls produced; published "runs" of 6,252 bbls; 2 million cubic feet of natural gas produced; most of it flared
• In December, 2010: 31 days; 10,860 bbls produced; published "runs" of 10,483 bbls; 17 million cubic feet of natural gas, and all of it flared, not of it sold
• In January, 2011: 31 days; 9,474 bbls produced; published "runs" of 9,493 bbls; 21 million cubic feet of natural gas produced and all of it flared.

The well has produced a cumulative of 57,481 barrels (if I did not make any typos, adding up monthly production should total cumulative production), in less than five full months. Someone elsewhere has said he/she uses 100,000 barrels as the breakpoint for paying for the well (at the wellhead). For me, this would be a very, very good well. Maybe not great compared to some in the Bakken, but if this wells pays for itself in 18 months, and then runs for 25 - 30 years, that's not bad.

It is my understanding that "runs" is the amount of oil "run" into the pipeline to be sold.

As a rule of thumb, one can divide cubic feet of natural gas by 6,000 to get rough estimate of "oil equivalent."  Thus, 21 million cubic feet of natural gas equates to 3,500 barrels of oil equivalent.  I could be wrong on this last point and if I am wrong, I am sure that someone will write in to tell me I'm wrong. This sounds like a lot of boe but Lynn Helms says natural gas is not economical for North Dakota Bakken wells.

I also could have made typographical errors on this but I will correct them if I find them or someone points them out to me.

This well is still flowing on its own; no pump (or assisted lift) yet, although that will eventually happen (based on experience in the Bakken). Its total depth was 18,955 feet which means it was a long lateral, and its spacing is two sections (1280 acres).

Price of Oil Increased Today -- What's Driving the Price?

Commentary only; not about the Bakken.

What's driving the price of oil? This is a multiple choice question; there are no wrong answers. 

• Libya: 500,000 bbls/day lost to the European market (the actual number has fluctuated from 400K to 1.5 million based on agenda of the journalist reporting)
• Bahrain: unrest spreading and closing in on Saudi Arabia
• Japan: acknowledging that it needs to increase refining capacity
• China: suspending plans for 28 nuclear reactors (40 percent of the world's nuclear capacity); China had planned on building 110 reactors

One can make an argument for any one of the four, along with the US gradually ending its own domestic drilling program:

• Offshore Alaska -- decreasing production and new fields out of the question
• Onshore federal lands: bureaucratic delays in issuing permits
• Onshore non-federal lands: lawsuits to prevent development
• Gulf of Mexico: permitorium continues
• Converting 40% of corn (food) to ethanol

My hunch: unrest in the Mideast spooked the market but once that settled down, the fact that Japan is now acknowledging that it will need to increase the use of oil, natural gas, or coal; and China will need to do the same if they don't bring their nuclear reactors on line have both replaced the Mideast issue. (I am in the minority on this; pundits say it is the "western bombing on Libya." Remember, the max amount of oil taken off the market due to this is 1.5 million barrels/daily and that all went to Europe; and some feel it is closer to less than a million barrels/day.  North Dakota, alone, is producing 350,000 bbls per day.)

But short term, the story that the Japanese government is asking its refiners to increase production speaks volumes:

Japan’s government is pursuing a number of emergency measures to deal with fuel shortages that include shipping 38,000 kl (about 10,000 gallons) of oil products by sea from refineries in Hokkaido and western Japan to the Tohoku region, hard-hit by the recent earthquake and tsunami.

Minister of Economy, Trade, and Industry Banri Kaieda called on the Petroleum Association of Japan (PAJ) to implement the emergency steps after earlier urging oil distributors to release 1.26 million kl for supply to the market.

Kaieda also called for the operating rates of refineries in western Japan, which stand at around 80%, to be raised to at least 95%. 

Increasing refinery operating rates from 80 percent to full capacity is remarkable. 

Nordic American Tanker sent a letter to its shareholders with the following paragraph (this link is dynamic and may break):

(On Japan) As far as the impact on our industry goes, it is too early to tell, but if nuclear power becomes less attractive, then it is reasonable to assume that the demand for other energy sources such as oil will increase..."

Meanwhile, from Washington, I get a sense of "business as usual":

• A trip to Brazil (I still don't know why) [Update: here's the reason]
• Weekend radio addresses on education reform
• Supreme Court agrees that list of banks receiving bailout dollars must be released

It's very possible it is "business as usual," and maybe by the end of the month, things will be back to normal. But as I list the issues above (at the top of the page), one certainly gets a feeling of things running faster than normal (I didn't even mention the undeclared war on Libya -- 124 Tomahawks and counting; $100 million in missiles alone, so far).

I hope the price of oil doesn't get to $110. It will be blamed on speculators.

CLR Moves Headquarters to Oklahoma City, Oklahoma -- Quite An Incredible Story -- North Dakota, USA

Continental Resources announced today the company is moving corporate headquarters to Oklahoma City, Oklahoma, part of their strategic plan to triple the size of the company in five years.

This is an incredible story. I don't know what CLR's market cap was in 2007 but today it's about $11 billion. The Bakken made this company what it is and it was the foresight of its CEO and his willingness to stake his company on a new formation and new technology that made is so successful.

The Bakken has been a great run for many folks and for North Dakota, the story is only about four years old. For Montana, Elm Coulee, the story is about eleven years old, and now companies are going back in and refracking/reworking the original wells in Elm Coulee/Bakken.

And it's numbers like this (posted earlier today) that make the Bakken very, very interesting (this is a Whiting well, not a CLR well, but the point is still the same):

The Niemitalo 31-15XH (#19502) runs parallel to the Kinnoin 11-14H (#17081) which had an IP of 3,311, and has produced 534,267 bbls of oil as of 6/12. It was spudded 8/08.  (At $50/bbl, 400K bbls = $20 million.) 400,000 bbls in less than three years and it continues to produce at 10,000 bbls/month (at $75/bbl, 3/4 of a million dollars every month); t2/11; cum 426K 7/17; cum 517K 11/23;

Monthly production:

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	7-2017	31	2510	2449	339	2705	2643	0
BAKKEN	6-2017	30	2403	2452	428	2464	2404	0
BAKKEN	5-2017	31	2703	2670	368	2756	2694	0
BAKKEN	4-2017	30	2860	3043	369	2794	2734	0
BAKKEN	3-2017	31	3011	2873	439	2804	2721	21
BAKKEN	2-2017	28	2749	2692	333	2419	2332	31
BAKKEN	1-2017	31	2996	3201	307	2400	2187	151
BAKKEN	12-2016	31	3206	3084	382	2369	2128	180
BAKKEN	11-2016	29	2933	2908	408	2267	2209	0
BAKKEN	10-2016	31	3205	3166	404	2368	1609	697
BAKKEN	9-2016	30	3047	3041	397	2160	2100	0
BAKKEN	8-2016	31	3206	3258	487	2228	2157	9
BAKKEN	7-2016	31	3519	3453	460	2478	2416	0
BAKKEN	6-2016	30	3391	3494	465	2239	2179	0
BAKKEN	5-2016	31	3815	3893	540	2534	2472	0
BAKKEN	4-2016	30	3951	3805	482	2527	2467	0
BAKKEN	3-2016	31	3851	3833	606	2257	2108	87
BAKKEN	2-2016	28	3204	3236	1223	1255	1129	70
BAKKEN	1-2016	29	3577	3556	1337	1530	1388	86
BAKKEN	12-2015	31	3944	4470	1430	1769	1629	78
BAKKEN	11-2015	30	3269	2825	1467	1655	1522	73
BAKKEN	10-2015	23	1975	1934	1026	989	944	0
BAKKEN	9-2015	21	1908	1876	403	1880	1796	43
BAKKEN	8-2015	31	3045	3047	641	3230	3168	0
BAKKEN	7-2015	31	3131	3136	729	3294	3226	6
BAKKEN	6-2015	30	2978	2984	619	3124	2860	204
BAKKEN	5-2015	31	3214	3225	634	3053	2961	30
BAKKEN	4-2015	30	3257	3218	644	2916	2803	53
BAKKEN	3-2015	31	3341	3437	700	3274	3212	0
BAKKEN	2-2015	28	3238	3166	636	3129	3073	0
BAKKEN	1-2015	31	3570	3534	700	3174	3096	16
BAKKEN	12-2014	31	3696	3793	517	3039	2896	81
BAKKEN	11-2014	30	3693	3799	597	3132	3034	38
BAKKEN	10-2014	31	3906	3726	460	3099	3037	0
BAKKEN	9-2014	30	4175	4286	430	3038	2960	18
BAKKEN	8-2014	31	4437	4634	454	3108	3046	0
BAKKEN	7-2014	31	4580	4278	496	2958	2809	87
BAKKEN	6-2014	25	3431	3530	593	2556	2511	0
BAKKEN	5-2014	31	4425	4433	600	3397	3335	0
BAKKEN	4-2014	30	4715	4623	544	3452	2695	697
BAKKEN	3-2014	31	5212	5634	761	3678	2573	1043
BAKKEN	2-2014	27	4775	4850	878	2793	2732	10
BAKKEN	1-2014	28	5109	4855	1010	2576	2521	0
BAKKEN	12-2013	31	5821	6413	1454	3413	3233	118
BAKKEN	11-2013	30	6057	5636	1537	3434	3374	0
BAKKEN	10-2013	31	5851	5804	1541	3099	3023	15
BAKKEN	9-2013	28	5216	5359	1316	2796	2740	0
BAKKEN	8-2013	30	5879	5668	1405	2957	2816	81
BAKKEN	7-2013	31	4563	4429	1031	2482	2420	0
BAKKEN	6-2013	13	1301	1296	360	976	952	0
BAKKEN	5-2013	30	3832	4031	583	3269	3210	0
BAKKEN	4-2013	30	4491	4355	825	3456	3396	0
BAKKEN	3-2013	31	5846	5909	1004	4084	4022	0
BAKKEN	2-2013	28	5392	5356	905	3413	3352	5
BAKKEN	1-2013	31	6129	6163	1022	3961	3899	0
BAKKEN	12-2012	31	5710	6096	1046	4559	4497	0
BAKKEN	11-2012	30	7050	6711	1438	4371	4311	0
BAKKEN	10-2012	31	7658	7633	1106	4552	4234	256
BAKKEN	9-2012	28	7306	7175	992	3951	3872	24
BAKKEN	8-2012	31	6934	7391	813	3451	3383	8
BAKKEN	7-2012	31	7062	6972	832	3425	3355	8
BAKKEN	6-2012	30	7418	7554	855	3703	3643	0
BAKKEN	5-2012	31	8986	8768	1019	4908	4846	0
BAKKEN	4-2012	28	8306	8330	1029	5213	5150	8
BAKKEN	3-2012	31	9998	10143	1378	6548	6486	0
BAKKEN	2-2012	29	9073	9823	935	5425	5150	217
BAKKEN	1-2012	31	9740	8381	2615	5449	5281	106
BAKKEN	12-2011	7	590	963	1048	854	102	742
BAKKEN	11-2011	17	5367	5833	130	1740	0	1710
BAKKEN	10-2011	28	10596	10801	352	3448	1	3394
BAKKEN	9-2011	22	12156	11383	324	3872	0	3835
BAKKEN	8-2011	25	13014	13705	452	4670	0	4625
BAKKEN	7-2011	27	16017	15626	629	5468	1123	4295
BAKKEN	6-2011	30	14320	14920	819	7600	7542	0
BAKKEN	5-2011	26	7501	7529	589	3801	2823	935
BAKKEN	4-2011	30	10515	10392	802	5620	5420	140
BAKKEN	3-2011	31	18830	18563	1369	10495	9263	1170
BAKKEN	2-2011	13	11869	10936	4491	6088	3356	2707

Lodgepole -- Oil for America -- The Jury Is Still Out -- North Dakota, USA

Finally, after coming off the confidential list a month ago, Oil for America is reporting production for:

• 19258, 75, Oil for America, Zastoupil 22-1, Wildcat, Lodgepole

The "75 barrels" is the production for one (1) day in January. My enthusiasm for this well (and the others of this group) has waned, but I am still waiting for another couple months of production to see what "they" have. But the Lodgepole is supposed to be a reservoir (a pool of oil) that is sequestered and if hit will produce flowing oil without fracturing. But 75 barrels on one day is not encouraging.

But I am waiting for a) a few more months of production; and/or b) a press release from the company explaining their results and future plans.

Wow, Wow, Wow -- Great Wells On Today's Daily Activity Report -- Bakken, North Dakota, USA

These were some of the wells that were reported on today's daily activity report:

• 19512, 1,959, WLL, Oja 14-27XH, Sanish, Bakken, spudded 10/10; tested 2/11
• 19502, 2,720, WLL, Niemitalo 31-15XH, Sanish, Bakken, spudded 10/10; tested 2/11
• 19222, 1,100, WLL, Bartleson 21-3H, Sanish, Bakken, spudded 10/10; tested 2/11
• 19005, 1,289, WLL, Satterthwaite 43-1H, Sanish, Bakken, spudded 10/10; tested 2/11
• 18889, 1,512, Murex, Kevin Wayne 10-3H, West Bank, Bakken, spudded 9/10; tested 3/11

It goes without saying that these are incredible wells.

The Niemitalo 31-15XH (#19502) runs parallel to the Kinnoin 11-14H which had an IP of 3,311, and has produced 402,351 bbls of oil as of 1/11. It was spudded 8/08.  (At $50/bbl, 400K bbls = $20 million.)

And 500 feet east of that well, and running parallel is Kinnoin 21-14H, which had an IP of 2,404.  It has produced 244,073 bbls as of 1/11. It was spudded 1/10 (about a year ago). It is still producing 13,000 bbls/month. (At $50/bbl, 250K bbls = $12.5 million [and that's about one year]). 

And I remain inappropriately exuberant about the Bakken. Remember, these Bakken wells are expected to produce for 25 - 30 years.

Four (4) New Permits -- North Dakota, USA

Producers: CLR (2), BEXP (2)

Fields: Camp, Banks, and a wildcat.

The CLR wildcat is in Williams County.

The two BEXP wells will be on the same pad. This may be one of the multi-well pads for BEXP (I can't remember, but it's certainly one of their first, if not their first).

In addition, the daily activity report reported several great wells, which will be reported elsewhere.

Sand Creek Oil Field: North Plains Energy, LLC, Reports A Nice Well in Sand Creek -- Bakken, North Dakota, USA

Updates

March 12, 2020: update; two rigs drilling Sand Creek wells; three rigs actually in the Sand Creek oil field, but one rig drilling wells that will go south into Banks oil field.

October 24, 2014: permits, production data update; 7 rigs in this field today;

November 20, 2011: reminder -- KOG bought North Plains Energy assets, to close January, 2012.

September 24, 2011 -- permits since 19096 --

• 21529, 2,015, Newfield, Pittsburgh Federal 153-96-3-2H, t11/13; cum 77K 8/14;
• 21530, 2,058, Newfield, Pittsburgh Federal 153-96-3-3H, t11/3; cum 49K 8/14;
• 19708, conf, KOG/North Plains, Federal 4-7H
• 19889, 1,678, XTO/Denbury Onshore, Sand Creek 21-10SH; t5/11; cum 243K 8/1;4
• 20522, conf, Newfield/North Plains, Sand Creek Federal 153-96-30-1H,
• 20523, conf, Newfield/North Plains, Sand Creek Federal 153-96-30-10H,
• 20084, 1,742, Newfield, Garvey Federal 153-96-29-2H, t3/12; cum 117K 8/14;
• 20336, 1,162, BR, Sun Notch 43-23H, t9/11; cum 30K 8/14; (see below)
• 20777, 2,405, BR, Renegade 34-10TFH, t9/12; cum 26K 8/14; (for updates, see below)
• 19814, PNC, XTO, Flatland 24X-11,
• 20832, 1,200, BR, Outlaw Gap 34-23TFH, t1/12; cum 165K 8/14; (for updates, see below)
• 20812, 1,884, BR, Hammerhead 31-26MBH, t4/12; cum 292K 8/14; (for updates, see below)
  

May 26, 2011: A nice Newfield well in Sand Creek:

• 19096, 2,862, Newfield, Helsingborg 1-22H, Sand Creek, Bakken; t2/11; cum 99K 4/12; 

Permits

2020  (through March 11, 2020)
37440, conf, Oasis, Wold ... 2B, Sand Creek,
37439, conf, Oasis, Wold ... 6B, Sand Creek, ,
37416, conf, Oasis, Wold ... 5B, Sand Creek,
37381, conf, Oasis, Wold ... 4B, Sand Creek,
37352, loc, Oasis, Wold ... 12TX, Sand Creek,

2019 (the list is complete)
37167, loc, Newfield, Pittsburg ... 5H, Sand Creek,
37166, loc, Newfield, Pittsburg ... 4H, Sand Creek,
37165, loc, Newfield, Pittsburg ... 1H, Sand Creek,
36363, PNC, Slawson, Gunslinger .. 1TFH, Sand Creek,
36362, conf, Slawson, Gunslinger .. 1H, Sand Creek,
36361,
36360,
36359,
36358,
36357,
36356,
36355,
36354,
36301, conf, BR, Renegade 34-15TFH-R, Sand Creek,
36112, conf, BR, Outlaw 34-23MBH, Sand Creek,
36111,
36110,
36109,

2018
35773, drl, Whiting, Tarpon Federal 44-19-2TFHU, Sand Creek,
35772, loc, Whiting, Tarpon Federal 44-19-3H, Sand Creek,
35571,

35570,

35769,
35768,
35193, SI/NC, Whiting, Tarpon Federal 34-30-3H, Sand Creek,
34916, SI/NC, Whiting, Wold Federal 44-1-4H, Sand Creek,
34915,

34914,

34663, SI/NC, Whiting, Wold Federal 44-1-2TFH, Sand Creek,
34662,

34661,

34660,
34659,

34631, SI/NC, Whiting, Tarpon Federal 34-20-1H, Sand Creek,
34630,
34629,
34628,
34627,

2017 (list is complete)
34341, conf, Newfield, Sorenson Federal 153-96-4-9-12H, Sand Creek,
34333, conf, Newfield, Sorenson Federal 153-96-4-9-3H, Sand Creek,
34332,
34331,
34330,
34329,

33890, 233, BR, Chuckwagon 41-15TFH, Sand Creek, t1/19; cum 118K 1/20;
33626, conf, Slawson, Gunslinger Federal 15-1-12TF2H, Sand Creek,
33625, IA/1,433, Slawson, Gunslinger Federal 4-1-12H, Sand Creek, t2/18; cum 351K 9/19; remains off line 1/20;
33624,
33623,
33622,
33621,

33555,
33554,
33553, 480, BR, Gladstone 3-1-25MBH A, Sand Creek, t2/18; cum 403K 1/20;

33544, 285, BR, Outlaw Gap 24-23MBH-A, Sand Creek, t4/18; cum 221K 1/20;
33543,
33542,
33541,
33540,
33485,
33484,
33483,
33482,
33481,
33472,
33471,
33470,
33469, 1,757, Whiting, Wold Federal 42-1-1TFH, t10/18; cum 32K 12/18;

2016 (list is complete)
33024, conf, BR, Renegade 24-10 TFH,
33023, conf, BR, Renegade 24-10 MBH,
33022, conf, BR, Chuckwagon 21-15TFH,
32991, PNC, BR,Outlaw Gap 24-23MBH33,
32990, PNC, BR, Outlaw Gap 24-23TFH,
32989, PNC, BR, Outlaw Gap 14-23MBH,
32988, PNC, BR, Outlaw Gap 14-23TFH,
32987, PNC, BR, Outlaw Wagon 14-23MBH-ULW,
32934, conf, BR, Renegade 44-10MBH, Sand Creek, producing,
32933, conf, BR, Chuckwagon 41-15MBH, Sand Creek, producing,
32926, 560, BR, Chuckwagon 31-15TFH, Sand Creek, t12/18; cum 7K after 8 days;
32925, l3 (no typo), BR, Renegade  34-10MBH, Sand Creek, t12/18; cum 6K after 10 days;
32924, dry, BR, Renegade 34-15TFH, Sand Creek, from a COP note: the well was drilled to depth, but problems developed after casing was set and cemented; when the string was pulled, it was noted that the running tool / wiper dart was not observed. It was assumed to be somewhere in the top of the liner. The liner was full of cement, with a calculated 17 bbls of cement outside the casing shoe. The decision was made to plug and abandon the well, and re-drill it from a future pad in the area;
32923, 181, BR, Chuckwagon 31-15MBH, Sand Creek, t12/18; cum 7K after 5 days;
32877, 1,487, Newfield, Helsingborg Federal 153-96-27-22-11H, Sand Creek, t12/16; cum 238K 12/18;
32876, 901, Newfield, Helsingborg Federal 153-96-27-22-4H, Sand Creek, t10/13; cum 167K 12/18;
32875, 1,328, Newfield, Helsingborg Federal 153-96-27-22-12H, Sand Creek, t12/16; cum 237K 12/18;
32874, 1,511, Newfield, Helsingborg Federal 153-96-27-22-13H, Sand Creek, t12/16; cum 284K 12/18;
32859, PNC, BR, Gladstone 1-1-25 MBH,
32858, PNC, BR, Gladstone 2-1-25 TFH,
32857, PNC, BR, Gladstone 3-1-25 MBH,

2015 (list is complete)
32041, 1,229, Newfield, Skaar Federal 153-96-30-5HLW, t2/16; cum 133K 1/20;
32040, 2,347, Newfield, Skaar Federal 153-96-30-1H, t2/16; cum 64K 5/16;
32039, 2,308, Newfield, Skaar Federal 153-96-30-2H, t2/16; cum 78K 5/16;
32038, 2,202, Newfield, Skaar Federal 153-96-30-3H, t2/16; cum 87K 5/16;
32037, 2,981, Newfield, Skaar Federal 153-96-30-4H, t2/16; cum 89K 5/16;
31639, 2,640, BR, Old Hickory 43-32 MBH-R, Sand Creek, t2/17; cum 317K 1/20;
31258, conf, BR, Gladstone 7-1-13TFH,
31226, 1,509, XTO, Harley Federal 24X-15A, Sand Creek t1/17; cum 214K 12/18;
31225, 444, XTO, Harley Federal 24X-15E, Sand Creek, t12/16; cum 153K 12/18;
31224, 1,242, XTO, Harley Federal 24X-15B, Sand Creek, t11/16; cum 162K 12/18;
31223, 1,474, XTO, Harley Federal 24X-15F, Sand Creek, t10/16; cum 152K 12/18;
31214, conf, BR, Gladstone 4-1-13TFH,
31213, conf, BR, Gladstone 4-1-13MBH,
31212, conf, BR, Gladstone 5-1-13TFH,
31211, conf, BR, Gladstone 6-1-13MBH,
31210, conf, BR, Gladstone 8-1-13MBH,
30743, conf, Newfield, Skaar Federal 153-96-28-13HLW,
30742, 1,736, Newfield, Skaar Federal 153-96-28-21-5H; t10/15; cum 117K 5/16; 
30741, 1,085, Newfield, Skaar Federal 153-96-28-21-12H; t10/15; cum 88K 5/16;
30740, 1,019, Newfield, Skaar Federal 153-96-28-21-4H; t10/15; cum 121K 5/16;
30739, 1,243, Newfield, Skaar Federal 153-96-28-21-11H; t10/15; cum 116K 5/16;
30632, PNC, Newfield, Prairie Moon Federal
30630, PNC, Newfield, Prairie Moon Federal
30629, PNC, Newfield, Prairie Moon Federal
30628, PNC, Newfield, Prairie Moon Federal
30627, PNC, Newfield, Prairie Moon Federal
30626, PNC, Newfield, Prairie Moon Federal
 
2014
30326, 2,652, BR, Old Hickory 41-32TFH, t2/17; cum 347K 12/18;
30325, AB/1,683, BR, Sun Notch 41-32TFH, Sand Creek, t12/16; off line 91/7; cum 103K 12/18;
30234, 1,844, BR, Sun Notch 43-32TFH, t11/15; cum 99K 5/16; only 20 days past two months;
30233, A/IA/1,363, BR, Old Hickory 43-32TFH, t11/15; cum 135K 11/19; last production 2/16; back on line 9/17; off line 11/19; remains off line 1/20;

30232, 2.405, BR, Sun Notch 43-32MBH, t11/15; cum 133K 5/16;on 32 days last two months;
30231, dry, BR, Old Hickory 43-32MBH 
30227, 792, BR, Sun Notch 42-34TFH, Sand Creek, t10/16; cum 346K 12/18;
30226, 1,560, BR, Old Hickory 42-32TFH, Sand Creek, t1/17; cum 277K 12/18;
30225, 2,640, BR, Sun Notch 42-32MBH, Sand Creek, t10/16; cu 234K 12/18;
30224, 2,544, BR, Old Hickory 42-32MBH, Sand Creek, t1/17; cum 332K 1/120;
29850, 1,249, Newfield, Rolla Federal 153-96-29-13H, t5/15; cum 77K 5/16;

29268, 1,407, Newfield, Rolla Federal 153-96-21-28-13HLW, t512/14; cum 224K 1/20;

29258, 693, Newfield, Rolla Federal 153-96-29-12H, t5/15; cum 43K 5/16;

29257, 1,418, Newfield, Rolla Federal 153-96-29-4H, t5/15; cum 64K 5/16;

29200, 2,468, Whiting, Tarpon Federal 44-19-3RTF, Three Forks B1, 1280-acre, t2/15; cum 101K 5/16;

29199, 3,238, Whiting, Tarpon Federal 44-19-1RH, t2/15; cum 137K 5/16;

29115, 1,513, Newfield, Helsingborg Federal 153-96-22-27-3H, t12/14; cum 133K 5/16;

29114, 1,889, Newfield, Helsingborg Federal 153-96-22-27-10H, t12/14; cum 124K 5/16;

29113, 1,284, Newfield, Helsingborg Federal 153-96-22-27-2H, t12/14; cum 123K 5/16;

28961, 807, Newfield, Skaar Federal 153-96-29-10H, t5/15; cum 46K 5/16;

28960, 1,289, Newfield, Skaar Federal 153-96-29-3H, t5/15; cum 61K 5/16;

28959, 1.090, Newfield, Skaar Federal 153-96-29-11H, t5/15; cum 58K 8/15;

28797, PNC, Newfield, Helsingborg

28796, PNC, Newfield, Helsingborg

28795, PNC, Newfield, Helsingborg

28784, 1,200, BR, 

28783, 1,512, BR, 

28782, 1,488, BR, 

28781, 1,080, BR, 

28780, 1,603, BR, 

28779, 1,443, BR, 

28778, 1,483, BR, 

28767, 970, Newfield, 

28765, 2,190, Newfield, 

28496, 2,959, Whiting, Tarpon Federal 24-20-3RTF, t1/15; cum 73K 8/15;

28495, 3,606, Whiting, Tarpon Federal 24-20-2RH, t1/15; cum 96K 8/15;

28493, 3,444, Whiting, Tarpon Federal 24-20-1RTF, t12/14; cum 109K 8/15;

28492, 4,371, Whiting, Tarpon Federal 24-20-1H, t12/14; cum 152K 8/15;

27528, 766, Newfield,

27527, 1,243, Newfield,

27526, 1,004, Newfield, Sand Creek State 153-96-16-12H, t1/15; cum 51K 8/15;

27413, 3,131, Whiting, Tarpon Federal 44-19TFHU, t2/15; cum 81K 8/15;

2013

25809, conf, XTO, Twin State Federal 34X-36G,

25808, conf, XTO, Twin State Federal 34X-36C,

25807, conf, XTO, Twin State Federal 34X-36H,

25806, conf, XTO, Twin State Federal 34X-36D,

25417, 3,001, XTO, Rolfsrud State 14X-36F, t3/14; cum 210K 8/15;

25416, 1,564, XTO, Rolfsrud State 14X-36E, t2/14; cum 105K 8/15;

25415, 1,509, XTO, Rolfsrud State 14X-36A, t3/14; cum 128K 8/15;

25074, 1,515, Newfield, Sand Creek State 153-96-16-3H, t1/5; cum 82K 8/15;

25073, 1,034, Newfield, Sand Creek State 153-96-16-10H, t1/15; cum 68K 8/15;

25072, 1,449, Newfield, Sand Creek State 153-96-16-2H, t1/15; cum 83K 8/15;

2012

24221, 1,629, Newfield, Pittsburg Federal 153-96-3-11H, t11/13; cum 93K 1/20;

23431, 1,464, XTO, Flatland 11X-2E, t11/12; cum 132K 1/20;

22914, 2,954, BR, Sun Notch 44-32TFH, t5/13; cum 360K 1/20;

22912, 2,972, BR, Old Hickory 14-33TFH, t5/13; cum303K 1/20;

22870, 1,894, XTO, Flatland 11X-2B, t12/12; cum 243K 1/20;

22869, 971, XTO, Flatland 11X-2A, t11/12; cum 180K 1/20;

22556, 2,967, Whiting, Tarpon Federal 44-19-2RH, R=revised, t2/15; cum 89K 8/15;

22555, IA/3,259, Whiting, Tarpon Federal 44-19-2RTF, R=revised, t2/15; cum 167K 10/19; remains off line 10/19;

22554, IA/2,272, Whiting, Tarpon Federal 44-19-1RTF, R=revised, gas max at 3,500 units; sixth and final of six wells drilled on the pad, the upper Bakken was 20 feet thick; the middle Bakken was 42 feet thick; the lower Bakken was 18 feet thick, t2/15; cum 218K 10/19; remains off line 1/20;

2011

21698, PA/181, XTO, Flatland 11X-2F, 1 stage, 600,000 lbs, t10/12; cum 0;

21529, 2,015, Newfield, Pittsburg Federal 153-96-3-2H, t11/13; cum 182K 1/20;

20832, 1,200, BR, Outlaw Gap 34-23TFH, t1/12; cum 305K 1/20;

20812, 1,884, BR, Hammerhead 31-26MBH, t4/12; cum 421K 1/20;

20777, IA/2,405, BR, Renegade 34-10TFH. "middle Three Forks", 5 stages, 500,000 lbs, t9/12; cum 73K 1/19;

20528, IA/2,892, BR, Chuckwagon 21-15MBH, 20 stages; 2.2 million lbs sand/ceramic, t12/11; cum 171K 10/19; remains off line 1/20;

20523, PNC, Newfield,

20522, PNC, Newfield,

20336, 1,162, BR, Sun Notch 43-32H-R, 20 stages; 2.1 million lbs sand/ceramic, very erratic production, company watching well for problems? t9/11; cum 358K 1/20; noticeable jump in production 4/19;

Original Blog

The North Plains well:

• 18787, AB/801, Whiting/KOG/North Plains Energy, LLC, Sorenson Federal 15-5H, Sand Creek, Bakken; t1/11; cum 144K 12/17;

What is interesting is that this well appears to be in a very nice oil field that has been "under the radar." The field is now mostly spaced for 1280-acre units, but the early wells were short laterals, and placed on 640-acre spacing.

No, this new North Plains Energy well is not a thousand-barrel IP, but for a small company in an obscure field, this is pretty good.

The Sand Creek oil field is in a fairly non-descript area of the Basin. It is located a bit farther east of the Stockyard Creek oil field and is on the south side of the river (the Stockyard Creek is on the north side). It is immediately west of the very nice Charlson field. 

It is a small field, only about one township in size: half of two townships -- T153N-R96W and T153N-R97W.

As an example of how good this field might be:

• 18282, 1,947, Equinor/BEXP, Strand 16-9 1-H, Squires, extended short lateral, spudded10/09; tested 11/09; cum 227K 1/20;

Denbury is currently drilling a well that is sited only 422 feet to the east of the BEXP well. I assume it will be a horizontal running in the opposite direction (running south).

• 19889, 1,678, XTO/Denbury, Sand Creek 21-10SH, t5/11; cum 596K 1/20;

BR is currently drilling another well in the field:

• 20336, 1,162, BR, Sun Notch 43-32H; t9/11; cum 358K 1/20; problems (see above)?

There are some very nice wells in this field, in addition to the BEXP well noted above (the early ones are short laterals; I assume most of the new ones will be long laterals (remember, once they reach 100,000 bbls, it is likely that the wells will pay for themselves at some point):

• 18662, 2,145, BR, Old Hickory 43-34H, long lateral running east to west; spudded 2/10; tested 5/10; cum 438K 1/20. In 8/10 it was still producing 13K per month. This is one of the better BR wells that I have seen in the Bakken
• 18414, 2,861, Newfield, Sand Creek Federal 1-27HA, short lateral; s9/10; t11/10; cum 308K 1/20; one doesn't see many short laterals any more and this was just drilled
• 17758, 617, Newfield, Alice Federal 1-28H, short lateral, s7/09; t8/09; cum 164K 1/19; remains off line 1/20; still considered A. Look how soon after spudding, fracking completed and tested; seems to have leveled off at about 1,200 bbls per month
• 18323, 2,654, Newfield, Sand Creek Federal 1-21H, short lateral, spudded 12/09; tested 3/10; cum 260K 1/20; off-line much of 1/11 (due to weather?);
• 17811, 2,825, Newfield, Garvey Federal 1-29H, short lateral, spudded 12/09; tested 5/10; cum 268K 1/20; (not taken off line during 1/11 -- so maybe something other than weather for the others)

New Director's Cut -- March 16, 2011 -- North Dakota, USA

Link here.

Production down in January, 2011, due to severe winter weather.

• December, 2010, oil: 344,064 bopd
• January, 2011, oil: 342,088 bopd
• Record oil production remains at 356,505 bopd
• December producing wells: 5,331
• January producing wells: 5,314 (all time high, 5,331 Dec 2010)

Permitting

• December, 2010: 143
• January, 2011: 142

Pricing

• December, 2010: sweet crude, $81
• January, 2011: sweet crude, $80

Director's comments:

The idle well count jumped to 760 in January 2011, [due to severe winter weather] the highest number since April 2002. We continue to have surplus crude take away capacity with pipeline, rail, and truck transportation all included. Shipment by rail is increasing and crude trucked to Canada is steady.

Rigs

• 20,000-foot capable rigs: over 90% utilization rates
• 7,000 or less-capable rigs: less than 50% utilization rates