Sunday, November 11, 2018

Off The Net For Tonight -- See You Tomorrow -- Good Luck To All -- November 11, 2018

The production numbers coming out of the Bakken are simply staggering. They are using a lot of proppant but not that much more.

See these two posts; the production numbers are staggering.
Bruin? See "Bakken operators" and scroll down at the link. Where did Bruin come from? Halcon. Wow.

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So how do you improve upon toilet paper besides labeling it with "Hello, Kitty"?

3-ply, of course. And I am not kidding. See if you can find 3-ply in your local grocery store.

Bruin Will Report A Staggering Antelope Well This Next Week -- November 11, 2018

Updates

January 5, 2019
  • 30541, 4,871, Bruin, Fort Berthold 151-94-26A-35-4H, 33-053-06668, FracFocus: 12 million gallons of water, 87% water, Antelope-Sanish, an incredible well; staggering, t6/18; cum 350K 11/18; hit the first 350K in less than seven months:
PoolDateDaysBBLS OilRunsBBLS WaterMCF ProdMCF SoldVent/Flare
SANISH11-20182214137142131292422550967610733
SANISH10-201831436914382230933650252755932588
SANISH9-20183052975530445615060629460675677
SANISH8-201831725167240863718906714548039524
SANISH7-201831638006364674543906084289342889
SANISH6-201830953159595967134672113723225562
SANISH5-20181577996657261691392175723178
SANISH4-20180000000


Original Post

This is simply staggering. It all starts with #30541 which will be coming off the confidential list this next week. I can't wait to see the completion strategy.

As you go through this post, comments and observations:
  • once they come off the confidential list we will see how many are middle Bakken and how many are Three Forks; if these are all middle Bakken, Katie, bar the door;
  • a lot of pundits suggest operators are running out of drilling locations in the Bakken; not for awhile;
  • "peak oil" folks and "conventional oil" experts and others are telling us that new wells are damaging existing producing wells; well, not so far;
  • just a few thoughts; I'm sure you have many, many more; and,
  • these are simply staggering. 
So, let's start. This well will be coming off the confidential list this next week:
  • 30541, conf, Bruin, Fort Berthold 151-94-26A-35-4H, 33-053-06668, FracFocus: 12 million gallons of water, 87% water, Antelope, an incredible well; staggering:
DateOil RunsMCF Sold
9-20185304446067
8-20187240845480
7-20186364642893
6-20189595937232
5-201866577572

For the archives:
  • 37,232,000 / 6001 = 6,954 boe
  • 95,959 + 6,954 = 103K boe in one month
The graphic:


Producing wells in this section:
  • 22707, 1,959, Bruin, Fort Berthold 151-94-26B-35-3H, Antelope, t4/14; 513K 11/18;
  • 22708, 1,776, Bruin, Fort Berthold 151-94-26B-35-2H, Antelope, t4/14; 308K 11/18;
  • 20328, 1,647, Bruin, Fort Berthold 151-94-26B-35-1H, Antelope, t3/12; 546K 11/18;
Other wells in this section:
  • 31774, 5,508, Bruin, Fort Berthold 151-94-26B-35-10H, Antelope, t7/18; cum 294K 11/18;
DateOil RunsMCF Sold
9-20185088153380
8-20189618372538
7-20186033816676

  • 31775, 2,402, Bruin, Fort Berthold 151-94-26B-35-15H, Antelope, t8/18; cum 156K 11/18;
DateOil RunsMCF Sold
9-201822401603
8-20186337039587
7-20185205609
  • 32431, 4,215, Bruin, Fort Berthold 151-94-26B-35-13H, Antelope, t7/18; cum 175K 11/18;
DateOil RunsMCF Sold
9-20182164525775
8-20187681777901
7-2018228464417
  • 31776, 1,992, Bruin, Fort Berthold 151-94-26B-35-12H, Antelope, t8/18; 85K 11/18;
  • 31777, 3,376, Bruin, Fort Berthold 151-94-26B-35-11H, Antelope, t7/18; cum 160K 11/18;
DateOil RunsMCF Sold
9-20181170612122
8-20186198843584
7-2018224912576
  • 31778, 1,549, Bruin, Fort Berthold 151-94-26B-35-10H, Antelope, t8/18; cum 60K 11/18;
DateOil RunsMCF Sold
9-201881955241
8-20182119823870
7-2018383246

  • 30546, 661, Bruin, Fort Berthold 151-94-26A-35-9H, Antelope, t7/18; cum 45K 11/18;
  • 30545, 2,070, Bruin, Fort Berthold 151-94-26A-35-8H, Antelope, t6/18; cum 184K 11/18;
DateOil RunsMCF Sold
9-20181214911037
8-20184718531244
7-20183071920591
6-20183285531464
5-201829421267
  • 30544, 1,129, Bruin, Fort Berthold 151-94-26A-35-7H, Antelope, t6/18; cum 54K 11/18;
  • 30543, 2,837, Bruin, Fort Berthold 151-94-26A-35-6H, Antelope, t6/18; cum 195K 11/18;
    DateOil RunsMCF Sold
    9-20181484111025
    8-20183282922985
    7-20185308234423
    6-20184440339049
  • 30542, 2,010, Bruin, Fort Berthold 151-94-26A-35-5H, Antelope, t6/18; cum 89K 11/18;
  • 22706, PNC, Bruin, Fort Berthold 151-94-26A-35-5H, Antelope -- I have not seen this before; two wells the identical legal name, but different permit numbers;
  • 30541, 4,871,  Bruin, Fort Berthold 151-94-26A-35-4H, Antelope; see this post; t6/18; cum 350K 11/18;
    PoolDateDaysBBLS OilRunsBBLS WaterMCF ProdMCF SoldVent/Flare
    SANISH9-20183052975530445615060629460675677
    SANISH8-201831725167240863718906714548039524
    SANISH7-201831638006364674543906084289342889
    SANISH6-201830953159595967134672113723225562
    SANISH5-20181577996657261691392175723178
    SANISH4-20180000000

Record IP? See FAQ #9 at this site. There you will find -- well, lookeee here -- it's already been posted! Whoo-hoo! Finally, coming off the confidential list:
August 1, 2018: still on confidential, but for first full month of production, 95,959 bbls of oil; #30541, Bruin, Fort Berthold 151-94-26A-35-4H, Antelope; see this post;
While pondering those production numbers, something nice:

Waterloo Sunset, The Kinks

Wells Coming Off The Confidential List This Next Week -- November 11, 2018

Monday, November 19, 2018:
34048, conf, MRO, State Kelling 14-36TFH, Bailey, no production data,
33329, conf, XTO, Dakota Federal 42X-36D, Bear Den, no production data, 
33225, conf, CLR, Kennedy 7-31H, Dimmick Lake, a huge well:
DateOil RunsMCF Sold
9-20182620149279
8-20184505478131
7-20181465526328
5-20187870

32960, conf, Oasis, Ceynar 5298 44-32 13B, Banks, a huge well;
DateOil RunsMCF Sold
9-20183319150620
8-20183714547881
7-20183275272070
6-20182518648293
5-20181084524899

Sunday, November 18, 2018:
32945, conf, Oasis, Ceynar 5298 42-32 10B, Banks, a very nice well;

Saturday, November 17, 2018:
33872, conf, MRO, Lawrence 34-35H, Bailey, no production data, 
33330, conf, XTO, Dakota Federa 42X-36HXE, Bear Den, no production data, 

Friday, November 16, 2018:
34171, conf, Windridge, Kestrel State 36-25 1H, Short Creek, producing, albeit not much;
33871, conf, MRO, Rummel 24-35TFH, Bailey, no production data, 
33224, conf, CLR, Kennedy 8-31H1, Dimmick Lake, a mediocre well, it appears;
33223, conf, CLR, Miles 5-6H, Dimmick Lake, a nice well;
30541, conf, Bruin, Fort Berthold 151-94-26A-35-4H, Antelope, an incredible well; staggering:

DateOil RunsMCF Sold
9-20185304446067
8-20187240845480
7-20186364642893
6-20189595937232
5-201866577572

Thursday, November 15, 2018:
33870, conf, MRO, Arthur 24-35H, Bailey, no production data, 
32801, conf, Oasis, Ceynar 5298 42-32 11T, Banks, a nice well; 

Wednesday, , November 14, 2018:
34453, conf, XTO, Cherry Creek State 14X-36EXH-S, Pembroke, no production data, 

Tuesday, November 13, 2018:
34844, conf, BR, Rink 8-1-5 MBH-R, Pershing, some early production;
34366, conf, XTO, Cherry Creek State 14X-36AXD, Siverston, no production data, 
34028, conf, NP Resources, Trotter State 145-102-23-14-2H, Cinnamon Creek, a nice well; about 11K per month for three consecutive months; 
33869, conf, MRO, Wickett 24-35TFH, Bailey, no production data, 
32943, conf, Oasis, Ceynar 5298 42-32 8B, Banks, huge well:
DateOil RunsMCF Sold
9-20182037131586
8-20182992646235
7-20182606950344
6-20182304436243
5-20181300321514

Monday, November 12, 2018:
34368, conf, XTO, Cherry Creek State 14X-36EXF, Siverston, no production data, 
32944, conf, Oasis, Ceynar 5298 42-32 9T, Banks, producing nicely;

Sunday, November 11, 2018:
34370, conf, XTO, Cherry Creek State 14X-36B, Siverston, no production data,
33222, conf, CLR, Miles 6-6H2, Dimmick Lake, producing nicely,

Saturday, November 10, 2018:
34495, conf, WPX, Howling Wolf 28-3HY, Wolf Bay, no production data, 
33315, conf, Oasis, Muri 5198 11-4 3B, Banks, huge well:

Friday, November 9, 2018:
  • 34269, SI/NC, Oasis, Muri 5198 11-4 14T, Banks, a DUC but producing nicely:
PoolDateDaysBBLS OilRunsBBLS WaterMCF ProdMCF SoldVent/Flare
BAKKEN9-20182010059996320071225791076711692
BAKKEN8-201831151581515831510330031977313044
BAKKEN7-20183118045180453803841660378113663
BAKKEN6-20183021253212533692741992418120
BAKKEN5-2018211411414364400428

Update: Speaking of Romsaas And Finsaas, An Update Of The Hellandsaas Well -- November 11, 2018

This page will not be updated. 

The section: 153-97-8, Banks Oil Field, Whiting, Hellandsaas And Frick -- tracked here.
  • 32995, 2,341, Whiting, Hellandsaas 44-8-1H, Banks, 30 stages; 6.2 million lbs, medium/small; a very, very nice well; 80K+ in first four full months; (#19533 with nice jump in production); t10/17; cum 140K 9/18;
*********************************** 
Swimming Lessons


Is CLR Getting Ready To Frack The Rolf Wells -- November 11, 2018

The CLR Rolf wells are tracked here.

This well has just been taken off -line:
  • 20183, 282, CLR, Rolf 1-20H, t6/11; cum 249K 9/18;
There are nine Rolf wells on SI/NC status.

Section 10-152-91: Tollefson, Sorenson, Murray, Hauge, Pennington -- November 11, 2018

A reader suggested I take a look at these wells in this drilling unit: these are huge wells and "no" water that needs to be transported away.

The wells:
  • 25176, 327, Whiting, Murray 13-3H, Sanish, t8/13; cum 222K 9/18; very short lateral, TD = 16,515 feet; got off to relatively slow start then typical Bakken production profile but is holding at a very, very respectable 3,000 bbls oil/month
  • 17912, 2,581, Whiting, Sorenson 11-3H, Sanish, t2/10; cum 854K 9/18; granddaddy of them all in this drilling unit; see notes for #25164 below; huge initial production, including almost 50K first full month; flowing, not on a pump;
  • 25331, 566, Whiting, Penning 11-3H, Sanish, t9/14; cum 277K 9/18; similar to #25164, just not quite as good; TD - 20,170 feet;
  • 25164, 768, Whiting, Hauge 41-3H, Sanish, t5/13; cum 359K 9/18; a typical Bakken well; high initial production; steep decline; then plateaued; no significant "halo" effect over the years; short lateral, TD = 17,905 feet;
The above four wells run north to south; this well runs south to north:
  • 18109, 2,409, Whiting, Tollefson 44-10H, Sanish, t9/09; cum 659K 9/19; did have a jump in production in 8/13, corresponding to frack of #25164; like #17912 above, flowing, not on a pump; a long lateral, TD = 20,170 feet; holding at 2,000 bbls of crude oil / month
The reader suggested comparing the Field Trust wells in section 7-154-101 -- which are producing a lot of water -- unfortunately. Maybe later.

Well, This Is Weird -- New England Is Now Burning Oil To Generate Electricity --

Link here.

I'm sure this is nothing new. If I have seen this before, I have forgotten.

Right now, electricity rates are dirt-cheap in New England, in fact, going "negative" earlier this morning -- meaning more electricity if being produced than is needed -- and yet, the region is now burning oil? No coal this morning, but rather, we now see oil.


Meanwhile, from Boston Globe's "Talking Points PM":

Natural gas pipeline expansion in New England:
Giving up on Access North -- the project to expand a major natural gas pipeline: When fires and explosions rocked Lawrence-area homes and businesses in September, the Columbia Gas incident was bound to hurt the already-tenuous political stature of the natural gas industry around here. [Lawrence, MA]

Now, Eversource Energy is paying a price for the damage to the industry's reputation: $32.9 million. That’s the pretax value of Eversource’s 40-percent stake in the proposed Access Northeast pipeline expansion project. Eversource just wrote off the full amount.

The company hasn’t officially given up on Access Northeast. But the utility’s accountants have decided, at least for now, that its share in the project is worthless. The reason? Eversource blamed the Merrimack Valley gas disaster, in a document filed Tuesday with the Securities and Exchange Commission, even though the incident didn’t take place in Eversource’s service territory.

Eversource and its partners in Access Northeast, National Grid and Enbridge, say the need to expand the Algonquin pipeline system's capacity in New England remains pressing. The $3 billion-plus project would provide gas for the region’s power plants on the coldest days of the year, when most of that fuel is used to heat homes and businesses, not to generate electricity.

However, the Massachusetts Supreme Judicial Court ruled in 2016 that electric ratepayers couldn’t be forced to pay for gas pipelines. That was a major setback for Access Northeast at the time, one that could yet prove to be a fatal blow.
In 2017, Algonquin owner Enbridge notified the Federal Energy Regulatory Commission that it was withdrawing its project application, essentially putting Access Northeast on the back burner.

Cheap Oil? Really, Really Cheap Oil And Canada Has It -- November 11, 2018

What does it mean for Canada with the demise of the Keystone XL (again)? Well, for one thing, it means really, really cheap oil: Western Canadian Select -- now known as Western Canadian Landlocked -- is trading for less than $16/bbl.

From Investor Village:
Canada, the world's fourth-largest producer of crude oil, missed out on a recent global recovery in energy prices, and is now taking it on the chin as prices fall.

Crude prices in Canada briefly dropped below $16 a barrel on Friday, after a U.S. federal judge blocked construction of a key pipeline needed to transport oil from Alberta to Nebraska.

That means Canadian crude is going for a fraction of supplies elsewhere, even as U.S. prices have tumbled 21% from last month's highs to about $60 a barrel . In October, Canadian crude traded at its largest-ever discount to U.S. oil of more than $51.

Because of the steep discount, Canadian producers are leaving 40 million Canadian dollars, or $30.65 million, a day on the table. Energy accounts for nearly 11% of the country's nominal GDP, according to government figures.

The Canadian market was dealt a fresh blow Thursday, when a federal judge ruled that TransCanada Corp. couldn't advance its Keystone XL pipeline without a supplemental environmental review. Completed, the pipeline would carry up to 830,000 barrels a day to Nebraska, where it could then be carried to the Gulf Coast.

Week 45: November 4, 2018 -- November 10, 2018

International:
National:
Geoff Simon's top North Dakota energy stories:
Top Bakken story of the week
Operations
Pipelines
Bakken 2.5
Bakken economy
Miscellaneous

MDU Announces Two New Natural Gas Pipelines In The Bakken -- November 11, 2018

MDU is expanding its Bakken transportation network with two new projects -- link here.
After a fifth consecutive quarter of record natural gas transportation volumes, MDU Resources Group Inc. is moving forward with two new pipeline projects in Montana and North Dakota as record production in the Bakken Shale continues to drive demand for additional transportation capacity.
MDU is finalizing construction plans for Demicks Lake, a 14-mile, 20-inch diameter pipeline in McKenzie County, ND, and a Line Section 22 expansion near Billings, MT.
Construction on both projects, which are supported by long-term customer agreements, is expected to begin in early 2019 with expected in-service by end of year.