Monday, December 17, 2018

NDSU To Play E. Washington For The FSC Championship, January 5, 2019

For those who may have missed it, NDSU will be playing Eastern Washington for the 2019 FCS Championship.

#1 NDSU defeated #5 SDSU, 44-21, in the semi-finals.

#3 E. Washington defeated #7 Maine in the other semi-final bracket.

NDSU will be playing E. Washington on January 5, 2019, for the championship. The game will be played in Toyota Stadium, Frisco, TX, just down the road from where we live. But, no, we won't be going.

The Bison aim for their seventh FSC championship in eight years. Link here
NDSU cruised to a perfect season by racking up 584 points, or 41.7 per game, compared to their opponents' 165 points. The run-heavy Bison averaged 285.9 yards per game and 184.6 more through the air.
The Bison will look for a seventh title in eight years, having won in 2011, 2012, 2013, 2014, 2015 and 2017. Eastern Washington. 12-2, won it's only title game appearance in 2010.


Despite Plummeting Oil Prices, The Number Of Active Rigs Continues To Increase In North Dakota -- December 17, 2018

Coolest video of the day, winter, 1936 (Don sent me the link):

My dad often talked about the winter of 1936 or thereabouts. Set all kinds of records. He was living in Newell, South Dakota, at the time. He was fourteen years old and he talks about riding with his dad on a four-hour drawn wagon to deliver milk to the dairy.
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Back to Shale

US shale: hold on to your hats. US shale production will rise to 8.2 million b/d in January -- EIA.
January's expected growth is one of the more robust monthly increases of late.
In November, EIA predicted December's oil output would be 7.944 million b/d, an increase of 113,000 b/d month on month.
EIA also forecast monthly increases of 98,000 b/d for November and 79,000 b/d for October.
******************************
The Daily Activity Report

Active rigs:

$49.8812/17/201812/17/201712/17/201612/17/201512/17/2014
Active Rigs68534064182

Six new permits:
  • Operators: Hess (5); Petro-Hunt
  • Fields: Antelope (McKenzie); Little Knife (Dunn)
  • Comments: Hess has permits for a 5-well AN-Lone Tree / AN-Double Bar V pad in section 11-152-95; Petro-Pad has a permit for a well in section 32-145-97;
Five permits renewed:
  • Slawson (3): two Atlantic Federal permits and one Bazooka Federal permit in Mountrail County
  • MRO: a Whitney USA permit and an Alvina USA permit, both in Dunn County
Three producing wells (DUCs) reported as completed:
  • 30063, 200, Equinor, Enderud 9-4 5H, Banks, t10/18; cum --
  • 30064, 481, Equinor, Enderud 9-4 8TFH, Banks, t10/18; cum --
  • 32301, 1,085, Whiting, Pronghorn Federal 41-14PHU, Park, t10/18; cum --

Williams Gets Final FERC Approval For Gateway Project -- Zacks -- December 17, 2018

Over at Zacks via Yahoo!
Bringing in pleasant news for the company, the Federal Energy Regulatory Commission (FERC) recently approved Williams Companies Inc.’s WMB Gateway project, which is an expansion of the firm’s Transco pipeline. Notably, the Transco pipeline delivers almost half of the natural gas consumed in New York and New Jersey.
With the existing Transco pipeline capacity being fully utilized, the expansion will allow additional gas volumes to be delivered to the northeastern markets.

Notably, the company had applied for the Gateway expansion project’s FERC permit in late 2017. Upon the receipt of the required regulatory approvals, the company is scheduled to commence the construction of the project in spring 2019.
The Gateway expansion project is expected to come online by November 2020.

With the Gateway expansion project, Williams will be able to fulfill its commitment to supply an incremental 65,000 dekatherms per day of firm transportation capacity and the mounting natural gas needs of customers in the Northeast during the winters of 2020 to 2021. The project will help provide additional natural gas service to UGI Corporation’s UGI affiliate UGI Energy Services LLC and utility firm Public Service Enterprise Group Inc.’s PEG unit, PSEG Power, LLC. 
Much more at the link.

A quick search of the blog for an RBN Energy blog on the Gateway project was not productive. It's surprising that of all that RBN Energy has written about, I can't find a blog on this project.

WTI Drops Below $50 -- December 17, 2018 -- North Dakota Sweet Trading At $25/Bbl -- Source

Down 2.6%; down about $1.33; trading at $49.87.

See comments.

North Dakota sweet oil is down to $25/bbl or thereabouts according to some sources. That was also noted in the most recent Director's Cut.


"Poll" or "survey" at the sidebar at the right was posted the day the Director's Cut came out, asking what readers thought was the "most important" data point.

Qatar -- Monday, December 17, 2018

Qatar certainly has been in the news lately. Previous posts:
Today, Qatar is again in the news, from Rigzone:
Qatar Petroleum (QP) and Eni S.p.A. signed a deal Sunday that will enable QP to acquire a stake in three Eni-operated oil fields in Area 1 in Mexico’s Bay of Campeche.
“We are pleased to sign this agreement, with our valued partner, Eni, to participate in the development and production of oil fields in Mexico,” QP President and CEO Saad Sherida Al-Kaabi, said in his company’s announcement. “This agreement marks another milestone for Qatar Petroleum as it strengthens its international footprint and expands its presence in Mexico.”

CAPEX Falling Short? -- Wood Mackenzie -- December 17, 2018; US Oil Production To Jump From Less Than 11 Million B/D To Over 12 Million B/D -- EIA

Don sent me the link. Thank you. I would have missed this story. I find the data points in this article absolutely fascinating.
The number of new oil and gas projects will rise five-fold next year from a 2015 trough but overall spending is still unlikely to be enough to meet future demand, consultancy Wood Mackenzie said.
Shaken by a sharp drop in oil prices in recent months, boards are generally expected to stick to spending discipline imposed following the 2014 price crash.
Global investment in oil and gas production, known as upstream, is expected to reach around $425 billion next year.
That compares with a total spending of $770 billion in 2014, which dropped to $400 billion in 2016 and 2017.
Although spending levels have slightly recovered since then, next year's capital expenditure will still fall short of the $600 billion required to meet demand growth and to offset the natural decline of output from field.
I think folks have been saying this for the past ten years -- that CAPEX would not meet future demands. I'm curious how far out Wood Mackenzie is looking. Certainly, there is no suggestion that supply won't meet demand for the next ten years?

Disclaimer: I am inappropriately exuberant about the US shale revolution.

From the EIA today, via twitter: In December, EIA forecasted that US crude oil production will average 10.9 million barrels per day (b/d) in 2018 and 12.1 million b/d in 2019.


Meanwhile, December, 2018, Rystad update. This is a hard graph to see, but remove the brown (natural gas) and it certainly appears crude oil discoveries are doing relatively fine, although that's i the eye of the beholder, and I won't argue with anyone who disagrees with me. As noted, I am inappropriately exuberant about short-cycle projects, as Chevron calls them.


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Pretty Funny -- Ya Gotta Love It -- Canada Keeping America Great

Faux environmentalists in Quebec love their SUVs. In the period from 1990 and to 2017 sales of SUVs, trucks and pick-ups had soared by 246 percent, and sales of gasoline had risen by a third over the period.

The report can be found here. Highlights of the report:
  • Quebec’s per capita energy consumption remains high, at 193 gigajoules. This is less than the United States or the rest of Canada, but much more than Germany or Norway.
  • Energy consumption in the industrial sector has declined, but the intensity of emissions per unit of energy has remained much the same. Overall, then, there has been little movement to decarbonize energy sources in this sector.
  • Quebeckers’ enthusiasm for SUVs continues to grow, at the expense of smaller cars.
  • Ride-sharing remains low (10%) in comparison with single drivers (68%).
  • The number of vehicles per 1,000 inhabitants has been growing constantly since 1990. This applies to all Quebec regions and the proportion of light trucks is rising everywhere.
  • In 2016, 54% of the energy travelling through the Quebec energy distribution system was lost and added no value to the economy.
  • In 2018, nearly 94% of the petroleum used in Quebec came from western Canada and the United States, as compared with 14% in 2013.
  • Approximately 57% of √Čnergir’s natural gas this year came from the Dawn supply hub in Ontario and 40% from the Empress hub in Alberta. 

Around The Bakken -- December 17, 2018

EOG's huge Skaar well on the far east side of the Parshall oil field has been updated with full production profile provide. This is a very short lateral, and has produced over 800,000 bbls of crude oil in about ten years. It has also produced 75,000 boe natural gas in that same time period. Natural gas production is increasing, as expected as the well grows older. 

CLR's Pittsburgh wells have been updated. All wells are now completed or on drl status. These are huge wells.

Equinor's Vachal wells have been updated.  These are huge wells and most of the wells show a jump in production after neighboring wells have been fracked.

WPX Mandaree wells in Reunion Bay, section 30-150-93, have been updated. These are huge wells. Two wells were particularly huge. #28983 was drilled three years ago; has produced almost 700,000 bbls of oil:
  • 19603, 332, WPX, Mandaree 30-31H, Reunion Bay, t5/11; cum 542K 10/18; ***
  • 28983, 2,222, WPX, Mandaree 24-13HD, Spotted Horn, t9/15; cum 689K 10/18; ***
The BR Veeder wells in Blue Buttes have been updated. Some of the Veeder wells have produced over 300,000 bbls in one year:
  • 32909, 441, BR, Lillibridge 3B UTFH, Blue Buttes, t9/17; cum 311K 10/18;
  • 32910, 555, BR, Lillibridge 3C MBH, Blue Buttes, t9/17; cum 358K 10/18;
  • 32911, 524, BR, Lillibridge 3D UTFH, Blue Buttes, t9/17; cum 268K 10/18;
  • 32912, 413, BR, Lillibridge-Veeder 3E-MBH-ULW, Blue Buttes, t8/17; cum 327K 10/18;
How does one even begin to calculate break even costs on these wells? Example. Look at the production profile of this well, drilled back in 2011, and not re-fracked, and yet in September, 2017, it was essentially a new well with incredible production; goes from a well producing 1,000 bbls/month to a well producing 12,000 bbls/month, and not re-fracked, according to FracFocus data:
  • 19288, 984, BR, Veeder 14-24H, Blue Butte, t4/11; cum 229K 10/18; recent production profile:
PoolDateDaysBBLS OilRunsBBLS WaterMCF ProdMCF SoldVent/Flare
BAKKEN10-201872380452041870
BAKKEN9-2018130019190
BAKKEN8-2018124880200
BAKKEN7-20182916341515465179417220
BAKKEN6-201830351637711200403339590
BAKKEN5-201831428440661395501549380
BAKKEN4-201830530653231580648064060
BAKKEN3-201831737177631640924191640
BAKKEN2-20182895608695141810626105560
BAKKEN1-2018311186212420229114771146940
BAKKEN12-2017301418813601245716155160810
BAKKEN11-2017301169512466234614173140990
BAKKEN10-201730448840091699366735930
BAKKEN9-201730493652942298389738230
BAKKEN8-201737845815592942870
BAKKEN7-20170000000
BAKKEN6-20172396558433122511680
BAKKEN5-20173115711412690187317960
BAKKEN4-20173012141095826184617720
BAKKEN3-20173111751082936120011960
BAKKEN2-20171440504431891870
BAKKEN1-20171022211441262392380
BAKKEN12-2016318750501101610120
BAKKEN11-20163083511375059869820

Break Even Costs -- How Does One Even Begin? -- December 17, 2018

This page will not be updated. Skunk Creek wells are tracked here.

The well:
  • 20926, 2,686, KOG, Skunk Creek 12-10-11-9H, South Fork; s7/11; t10/11; cum 307K 10/18; not re-fracked; note small production jump in 7/17, but more importantly extended better production for longer period of time:
PoolDateDaysBBLS OilRunsBBLS WaterMCF ProdMCF SoldVent/Flare
BAKKEN10-2018282206217128602416725260
BAKKEN9-20183025132519384331141519107
BAKKEN8-201831257726724384301814590
BAKKEN7-20183125832610381130801306189
BAKKEN6-2018304216413441313280167884
BAKKEN5-201831272426574601336517800
BAKKEN4-20183038803923481830891309248
BAKKEN3-201831311631015446313615628
BAKKEN2-201828281028014816304716310
BAKKEN1-201831322132176543368421020
BAKKEN12-20173132963264690521391798155
BAKKEN11-20173030663143698719531589188
BAKKEN10-20173130333006825019371414341
BAKKEN9-20173031403140456621271195753
BAKKEN8-2017305033505677823509330131
BAKKEN7-201724469750278736337817461493
BAKKEN6-2017377140278654276453
BAKKEN5-2017736637335235726847
BAKKEN4-201730147515121614162514460
BAKKEN3-201731165316441768174915630
BAKKEN2-201728139713961687153313651
BAKKEN1-201731159416521726154913621
BAKKEN12-2016311628159517691515125178

Break Even Costs -- How Does One Even Begin? -- December 17, 2018

Two Equinor wells -- re-fracked. Discussed before.
  • 21046, 2,264, Equinor/Statoil, Jack 21-16 1H, East Fork, 33-105-02260; t5/12; cum 315K 10/18;
  • 21045, 3,205, Equinor/Statoil, Ruth 28-33 1H, East Fork,33-105-02259, re-fracked 8/1/16, 12 stages, 1.5 million lbs, IP of 1,226, t4/12; cum 328K 10/18; very small re-frack for huge return; off line again, as of 10/18;
Now, look at Ruth #3:
  • 30431, 3,256, Equinor, Ruth 28-33 3H, API: 33-105-03952, East Fork, t11/16; cum 216K 10/18; this well was fracked in 2016; not re-fracked; look at huge jump in production in March, 2018; full production profile:
PoolDateDaysBBLS OilRunsBBLS WaterMCF ProdMCF SoldVent/Flare
BAKKEN10-201831920790171242451653770771
BAKKEN9-20181952585150903839212687873
BAKKEN8-2018194008413255863432299995
BAKKEN7-20182767126803799761784876696
BAKKEN6-201822666964258682571014134066
BAKKEN5-201815273527694204317814111652
BAKKEN4-201830623974009235652551261037
BAKKEN3-2018311504314703156161394912933329
BAKKEN2-201825897780691214517897128464205
BAKKEN1-20183193312571996112110522
BAKKEN12-20172347384433942841423513381
BAKKEN11-2017619852289274719061475359
BAKKEN10-20172911050109981380591958553252
BAKKEN9-201728899889281026395879022125
BAKKEN8-20173111049111341172811751112304
BAKKEN7-20173011815127091369311147106480
BAKKEN6-2017281742216698178972010819057201
BAKKEN5-2017311662716549166131574814475699
BAKKEN4-20173010808106519885106369671570
BAKKEN3-2017419852213261816111423125
BAKKEN2-2017251725417255182771743616135571
BAKKEN1-20173127468271543025222611201771429
BAKKEN12-2016327422634323420201719206
BAKKEN11-20163063626266698254004795340

Six Wells Coming Off Confidential LIst -- December 17, 2018

Wells coming off the confidential list this past weekend, Monday --

Monday, December 17, 2018:
  • 34869, SI/NC, Hunt, Halliday 146-93-11-2H-6, Wolf Bay, producing;
  • 34611, 1,387, Petro-Hunt, Klevmoen 153-95-17C-7-2H, Charlson, 49 stages; 10.5 million lbs, a huge well, t10/18; cum 42K at end of first full month:
PoolDateDaysBBLS OilRunsBBLS WaterMCF ProdMCF SoldVent/Flare
BAKKEN10-2018313844038363778758771549243698
BAKKEN9-201823327126061819782598166

Sunday, December 16, 2018:
  • 34203, SI/NC Hess, BB-Chapin-151-95-0506H-7, Blue Buttes, no production data,
Saturday, December 15, 2018:
  • 34868, drl, Hunt, Halliday 146-93-11-2H-5, Wolf Bay, one month of production;
  • 34202, SI/NC, Hess, BB-Chapin-151-95-0506H-6, Blue Buttes, no production data,
  • 32842, SI/NC, BR, Remington 4A MTFH, Blue Buttes, no production data, the Remington wells are tracked here;
Active rigs:

$51.5412/17/201812/17/201712/17/201612/17/201512/17/2014
Active Rigs67534064182

RBN Energy: Part 4 -- D-J Basin production gains spur gas processing projects.
Gross production of natural gas in the Niobrara region topped 5 Bcf/d for the fourth consecutive month in November 2018, according to the Energy Information Administration, and it's estimated that regional output this month will hit another record: nearly 5.2 Bcf/d. These production gains, and the concentration of new wells in or near Weld County, CO — the epicenter of the Niobrara’s Denver-Julesburg Basin — are straining the ability of existing gas processing plants to keep up, and spurring the rapid development of new processing capacity. The scale of the build-out in the D-J is impressive: some 2.7 Bcf/d in new cryogenic plants are either under construction or in various stages of pre-construction planning in northeastern Colorado. Today, we continue our review of Rockies crude oil, gas and NGL production and infrastructure, this time focusing on gas-processing needs in the sky-high D-J.
Previously we discussed the Niobrara’s geography and hydrocarbon production history. By our assessment, the play includes the D-J Basin and the Powder River Basin (PRB), with the heart of PRB in northeastern Wyoming and the D-J taking up much of northeastern Colorado and part of southeastern Wyoming. The Niobrara has been producing oil and gas for more than a century. Total production of natural gas took off there in the late 1990s and early 2000s, and production held relatively steady through most of the 2010s at between 4.3 Bcf/d and 4.9 Bcf/d, breaching the 5-Bcf/d mark only once (in January 2012) until this past August; since then, production has ratcheted up month by month, hitting a record 5.15 Bcf/d in November.
As for crude oil, production in the D-J Basin and PRB took off during the Shale Era, soaring from less than 140 Mb/d in January 2010 to a peak of nearly 500 Mb/d in April 2015. Drilling activity and production sagged with crude prices in 2014-16, and by January 2017, the play’s oil output was down to just a hair above 400 Mb/d. Since then, though, it’s been on a tear — up to 664 Mb/d as of November, again according to EIA. The agency doesn’t specifically track NGL production in the Niobrara, but its data show NGL output rising generally in the Rockies — Petroleum Administration for Defense District (PADD) 4 — by one-third since 2013, with a substantial portion of those gains.