Thursday, March 31, 2016

World's Biggest Oil Market Is Too Tied To Mideast To End Addiction -- March 31, 2016

Bloomberg is reporting:
Mideast:
  • producers have cut official selling prices; defend against other suppliers taking their markets
  • Saudi Arabia is selling Arab Light in Asia for 75 cents below benchmark Middle East prices (compare with $2.75 premium in early 2014)
  • Iran offering its oil at a deeper discount than Saudi Arabia for first time in a decade 
  • strategy working; but IEA has warned there is an increased possibility of oil-security surprises in the "not-too-distant" future
  • with non-OPEC supplies falling, Asian refiners have no choice but to buy Middle Eastern oil: cheaper and available in large volumes
Asia likes Mideast oil:
  • shorter shipping times
  • attractive prices
  • type of crude oil the refineries were optimized for
South Korea:
  • imports from the Middle East climbed last year to the highest level since at least 1980
  • wants to diversity purchases to guard against geopolitical risks tied to some of the world's biggest suppliers 
  • imported 845 million bbls in 2015; high since 1980 when that country started compiling the data
India:
  • refiners are shunning shipments from distant ports, taking more cargoes from Persian Gulf
  • wants to diversity purchases to guard against geopolitical risks tied to some of the world's biggest suppliers
  • but, India's Reliance Industries, owner of the worlds biggest refining complex is shifting from crudes tied to Brent to grades priced against Dubai, the Middle East marker
China:
  • Saudi Arabia and Oman have boosted supplies to China this year as volumes from Venezuela and Colombia have shrunk
  • more than half of the top 10 suppliers were from the Middle East last year

Tesla Model 3 Live Stream Now

https://model3.tesla.com/
  • deliveries begin "next year"
  • EPA mileage: 215 miles on a single charge
  • $35,000; base model comes with most "options"
  • single sheet of glass overhead, front to rear
  • relatively short presentation; 15 minutes?

Connecting The Dots: Shell, Brent, And Saudi Aramco -- March 31, 2016

Updates

April 19, 2016: Saudi Aramco picks JPMorgan and banker Klein for IPO

April 1, 2016: Saudi Arabia plans $2 trillion megafund for post-oil era. Will begin with Saudi Aramco going public. Sort of. Five percent of Saudi Aramco will be "available" for investors.
Saudi Arabia is getting ready for the twilight of the oil age by creating the world’s largest sovereign wealth fund for the kingdom’s most prized assets.
Over a five-hour conversation, Deputy Crown Prince Mohammed bin Salman laid out his vision for the Public Investment Fund, which will eventually control more than $2 trillion and help wean the kingdom off oil. As part of that strategy, the prince said Saudi will sell shares in Aramco’s parent company and transform the oil giant into an industrial conglomerate. The initial public offering could happen as soon as next year, with the country currently planning to sell less than 5 percent.
The sale of Aramco, or Saudi Arabian Oil Co., is planned for 2018 or even a year earlier, according to the prince. The fund will then play a major role in the economy, investing at home and abroad. It would be big enough to buy Apple Inc., Google parent Alphabet Inc., Microsoft Corp. and Berkshire Hathaway Inc. -- the world’s four largest publicly traded companies.
Original Post
 
It's being reported that Shell wants to sell some/all of oil producing assets in the North Sea, including it's Brent field. The story is here.

There are very few comments but this one is interesting:
Saudi Aramco should buy all of Shell. Then turn around and sell the global reserves (Saudi doesn't need more oil that's harder to produce than its own). The proceeds from the oil will equal or exceed the costs of the whole Shell company, which means Saudi Aramco gets Shell's refineries, petchem plants and other downstream physical assets at no costs. 
At least one other comment suggested Saudi Aramco was a player.

With Shell and Saudi Aramco recently splitting up their midstream/downstream assets in the US, presumably to make it easier for Saudi Aramco to monetize its assets, one wonders if the comment above "holds water."

I find it all very interesting.

Also, note that in an earlier post (the same link as above):
After the split, Saudi Aramco wants to buy more US refineries. Reuters is reporting:
Saudi Arabia's national oil company wants to buy more U.S. refining and chemical plants to expand its footprint in the world's largest energy market once the break-up of its joint venture with Royal Dutch Shell Plc is complete.
Ending an often rocky nearly 20-year relationship, Shell and Saudi Aramco announced on Wednesday plans to break up Motiva Enterprises LLC after almost two decades, dividing its assets and leaving Aramco with one plant, the nation's largest crude oil refinery, in Port Arthur, Texas.
Officials from Saudi Refining, the downstream arm of Aramco, told employees following the announcement that the state-owned firm was intent on buying more assets once the Motiva break-up is finished.
I find it "hyperbole" to suggest Saudi Aramco would buy Shell, but at least "everyone" is on the same page when it comes to talking about Saudi Aramco acquiring more refining and chemical plants around the world.

Stay tuned.

For the record and for comparison, enterprise value (in round numbers):
  • XOM: $400 billion
  • Shell: $200 billion
  • COP: $75 billion

New Post-Boom Low For Active Rigs In North Dakota: 29 -- March 31, 2016

From the WSJ:
U.S. gasoline demand hit record levels in March. Government estimates released Wednesday show consumption averaged more than 9.4 million barrels a day in the four weeks that ended Friday. That is a level usually found only during peak summer driving season, and it compares with roughly 8.8 million barrels a day in March of both 2014 and 2015.
Drivers’ rising fuel consumption wasn’t enough to halt a retreat when oil prices dropped by more than 7% from a recent peak on March 22. And gasoline demand alone is unlikely to be enough to spark another oil rally. Gasoline matters less for market sentiment than news about crude supply, said investors, some of whom already have factored strong gasoline demand into their oil forecasts.
But gasoline demand may be the most stable contributor to oil prices. A preliminary deal among Saudi Arabia, Russia and other major oil-producing nations to cap output was the biggest catalyst for crude’s recent surge, many analysts said.
Yet, that production freeze has yet to materialize, and Kuwait’s announcement this week that it could restart production at another oil field cast further doubt that a deal can come together.
Even if it does, Iran’s plans to increase production by 500,000 barrels a day could mean global supply increases. Moreover, U.S. producers have spent seven months holding output steady at about nine million barrels a day, defying the conventional wisdom that low prices will force domestic producers to throttle back substantially.
Gasoline demand, meanwhile, is proving a reliable contributor to the supply-demand equation for oil.
Bloomberg reports that the US is a big importer of oil ... again:
In the three months since the U.S. lifted its 40-year ban on crude oil exports, a curious thing has happened. Rather than flooding global markets, U.S. crude shipments to foreign buyers have stalled. At the same time, imports into the U.S. jumped to a three-year high in what looks to be a reversal of a yearslong decline in the amount of foreign crude brought into the American market.As of March 25, the four-week average of imports was running at 7.9 million barrels a day, 9.8 percent higher than the year before. “That’s not a one-week blip,” says Tim Evans, an energy analyst at Citi Futures. “We’re seeing a consistent pattern.”
During the early years of the U.S. shale boom, the millions of barrels of light, sweet crude had one big problem: no affordable access to refiners on the coasts of Texas and Louisiana. To tap into the cheaper oil pooling in Oklahoma, pipelines that used to bring imported oil up from the Gulf were reversed to take shale oil down to the coast. Refiners in Philadelphia and New Jersey also began buying North Dakota crude instead of foreign oil, moving it by train across the country. By October 2014, U.S. imports had fallen by about 40 percent from a high in 2006.
Analysts say that West Texas Intermediate crude has to be $3 to $5 cheaper than imported oil to pay for those pipeline and transportation costs. From 2011 to 2014, U.S. oil was on average $12.61 cheaper than equivalent foreign oil. The discount slowly narrowed as pipeline projects were completed and U.S. crude began to flow more freely from the middle of the country down to the Gulf Coast. A week before the Senate approved lifting the export ban on Dec. 18, WTI traded around $3 below Brent. Over the next month, the discount disappeared, and, for the first time in six years, WTI traded at a premium to Brent for a few days in January. WTI is now less than a dollar cheaper than foreign barrels available on the Gulf Coast.
So refineries along the coasts are choosing to buy imports instead of WTI. One of the biggest winners is Nigeria, which is regaining lost market share. Imports from Nigeria surged to 559,000 barrels a day in mid-March, compared with an average of 52,000 for all of 2015. Refiners are also taking more heavy oil from Mexico and Venezuela. Not only is it about $9 a barrel cheaper than WTI, it’s also what U.S. refineries prefer to handle.
The irony of the shale boom, and all the light crude it unlocked, is that it came just as U.S. refiners were spending billions to process heavy oil.  
And, of course, the writer of that article conveniently forgets to mention why the US did not have a North American source of heavy oil.

 **********************************
Back To The Bakken

Active rigs:


3/31/201603/31/201503/31/201403/31/201303/31/2012
Active Rigs2999194188206


The drop in the number of active rigs between now and the next six may or may not be due to spring thaw / "road restrictions." If due to "road restrictions," the number of active rigs could drop more than expected, but for a relatively short period of time. 

Four wells coming off confidential list Friday:
  • 30969, SI/NC, EOG, Van Hook 47-3626H, Parshall, no production data,
  • 31628, SI/NC, XTO, Ames Federla 31X-13B, Grinnell, no production data,
  • 31699, SI/NC, Statoil, Shorty 4-9F 4TFH, Stony Creek, no production data,
  • 31849, SI/NC, MRO, Ronald 34-33TFH-2B, Reunion Bay, no production data,
Four (4) new permits:
  • Operator: BR (3), EOG
  • Fields: Camel Butte (McKenzie), Parshall (Mountrail)
  • Comments:
Six (6) permits renewed:
  • BR (3), one Gudcadia and two Gudmunson permits, all three in McKenzie County
  • Whiting (2), one Skunk Creek and one Two Shields Butte permit, both in Dunn County
  • Sinclair, a Nelson permit in Mountrail County
  • Twelve (12) oil and gas wells were transferred from North Plains Energy, LLC, to North Plains Energy II, LLC.

More Solar Energy Approved For Minnesota -- March 31, 2016

From The StarTribune:
Two new solar projects have been approved for the state of Minnesota.
Minnesota regulators on Thursday approved a solar power project near Marshall, MN, that will be the second-largest in the state.
NextEra Energy Resources was cleared to build a 62-megawatt solar generator on 515 acres of farmland three miles east of Marshall. One megawatt is 1 million watts of electricity.
The Minnesota Public Utilities Commission unanimously voted to approve the project, rejecting concerns that it violated state policy against building energy projects on prime farmland.

The other large solar farm, approved in January, is the $180 million, 100-megawatt North Star Solar project on 800 acres southeast of North Branch in Chisago County
Both solar projects are expected to be built this year.
The state is on its way to meeting its citizens' mandate:
By 2020, 1.5 percent of the electricity sold by the state's major utilities — Xcel Energy, Minnesota Power and Otter Tail Power — must come from solar generation.

Back To 30 Active Rigs -- March 31, 2016

Back to 30 active rigs in North Dakota, the post-boom low. I track this data here

*********************
The Apple Page

The new Apple iPhone SE was available for pre-order on March 24th -- last week. Today, the phone is available to be seen and touched in Apple retail stores. I don't know if it's yet available for sale in all retail stores.

***********************
Dash Buttons

My son-in-law alerted me to these things. Quite incredible. The story here:
After last year rolling out the WiFi-connected plastic tabs that can be mounted to the fridge, washing machine or kitchen cupboard, the online retailing giant is increasing the number of brands that can be re-ordered by pushing a button to more than 100.
Simply brilliant. Beats shopping lists for the well-to-do. 
I have visions of our two-year-old granddaughter pushing these buttons non-stop. She loves anything with buttons.

When I was in the service, the most junior enlisted person in the office was responsible for keeping the break room well stocked with coffee, soft drinks, munchies. It was a huge chore lugging in cases of soft drinks every few days, nothing to say of the pain of going to the commissary (with the long lines) to pick up supplies. Secretaries, office managers, and those responsible for stocking break rooms are going to love these. Can you imagine being on the 20th floor of any skyscraper in New York City and constantly having to re-stock the break room? Problem solved. Dash buttons.

The bosses will also love these things. The cost more than makes up for losing a highly paid IT employee while he/she is gone for a couple of hours shopping for diet Coke and Kit Kat bars. By the way, that's why smart employers put break rooms in their own facilities: employee-provided break rooms ensure employees stick around instead of getting lost in some urban jungle. 

******************************
Spin Cycle

From The Boston Globe:
Overall, roughly one of every three workers in the Bay State clocks less than 35 hours a week, according to data from the Economic Policy Institute. While this may seem like a dubious distinction, it’s actually a sign of rare flexibility in the state job market.
For the most part, Massachusetts’ part-time workers aren’t stuck in undesirable gigs, unable to find steady, 40-hour slots. Most of them are content to work less than 35 hours a week, whether to make room for family obligations, deal with a pressing medical issue, or just open more space for the nonwork parts of life.
President Obama understood that -- that folks only wanted to work 35 hours a week. That's why ObamaCare kicks in after 35 hours. LOL. I can't make this stuff up.

I'm going to go look at the new iPhone SE. See you all later.

For The Archives -- Price Of Brent After Saudi Opened The Spigots -- March 31, 2016

I'm posting this not because I'm interested in where Brent is now. I'm posting this for the archives to remind future generations when/how the 2014 price slump played out while it was still playing out.

Occidental's Enhanced Oil Recovery In The Permian -- March 31, 2016

In this update of the Permian, Occidental's enhanced oil recovery was highlighted. Some background from DrillingInfo:
In a conventional reservoir drilled with conventional methods, the expected initial extraction rate of available hydrocarbons maybe as much as 15% – leaving 85+% of hydrocarbons in the reservoir. Pump jacks and initial gas injection or thermal recovery can increase that capture to the 25-30% range. By applying EOR techniques you can extract another 10-15% of the initially available hydrocarbons.

Occidental has been a leader in CO2 flooding in the Permian basin for a number of years, and a number of other big names are involved in Permian EOR.
The Midland Reporter-Telegram reports, back in August, 2014:
Occidental Petroleum this week held a groundbreaking ceremony for its 212,000 square foot Midland Office Complex, now under construction at 6001 Deauville as the first building in the Energy Plaza at Westridge Park.
From an interview reported by that outlet:
Q: Occidental recently spun off its California business, saying it can now focus more on its Texas operations as well as the Middle East and Colombia.  What exactly does this mean for Occidental’s Permian Basin operations?
A: Occidental Petroleum plans to spin off its wholly owned subsidiary, California Resources Corporation, in the fourth quarter of 2014.
The Permian Basin is home to our principal asset, where we have been operating and producing for more than 30 years. Occidental has more than 5 million gross acres with over 12,000 Oxy-operated gross oil and gas wells in the Permian Basin, and we produce from every producible formation here.
Occidental is also the largest operator and largest producer of oil in the Permian Basin thanks to our successful EOR business and continued focus on our unconventional development, which is well positioned to deliver long-term growth. 

Q: What unconventional plays in the Permian Basin is Occidental active in and what emerging plays is the company looking at?
A: We are active at South Curtis Ranch in the Midland Basin, in the Delaware Basin, and in the Wolfcamp A and B benches. We are also transitioning to accelerated development in Barilla Draw.

Q: Occidental has long been one of the Permian Basin’s leading producers and a major operator of tertiary recovery projects. How have the recent shale plays in this region affected those CO2 projects, or have they?
A: Occidental’s recent shale plays have not impacted our CO2 operations. We believe our enhanced oil recovery (EOR) from CO2 will be an ongoing source of cash generation for our unconventional drilling operations. We are applying more than 30 years of experience in CO2 EOR in the Permian Basin in support of our unconventional opportunities. This is a significant competitive advantage for Occidental in our Permian production.
In 2013, Oxy injected more than 650 billion cubic feet of CO2 into oil reservoirs in the Permian. Occidental operates 31 active CO2 projects in the Crossett, Slaughter Field, Welch & Cedar Lake, Wasson Field, Canyon Reef and other areas. We have seen CO2 flooding increase ultimate oil recovery by 10 to 25 percent where applied. Much of our success is due to extensive automation to maximize throughput performance. In recent years, we added a CO2 plant control center, electronic wellhead shutdown devices, an injection distribution system and other features.

Update On The Permian -- March 31, 2016

Updates

March 31, 2016: in the article below, note the prices at which operators in the Permian feel they can still make a profit (the sweet spots in the Bakken are said to be even better with regard to profitability). The numbers presented are $40, $50, and $60 oil. None of that matters to Saudi Arabia. For Saudi Arabia, $60 is better than $40 oil, obviously, but unlike oil companies which can show a profit (barely) on $40 oil in some cases, Saudi needs at least $60 oil to meet their 2016 budget. And that's the yearly average. I can see oil getting back to $60 oil by the end of the year, but it seems impossible for oil to average $60 for the entire year. And with a budget based on $60 oil, Saudi Arabia has cut way back on capital investment in its own country:


This does not include expenditures for the on-going war in Yemen, and foreign aid it provides other Arab countries, notably Palestine. Saudi has deferred/delayed/cancelled its huge plans for solar energy; it has huge desalination needs. And with all that, there is deep concern that Saudi could be a net energy importer in the near future.

But it's not just the price of oil that Saudi is facing; it has lost significant market share for undetermined reasons. I was unable to find any reasons in that article why Saudi is losing market share if deals are made simply on price.

These are the "facts" facing Saudi Arabia when they attend the April 17, 2016, OPEC meeting. I can see Saudi Arabia kicking the can down the road until OPEC's regularly scheduled meeting in June by simply agreeing to a production freeze if others agree but nothing more.
 
Original Post
 
This is a long, long article, but if you are interested in the Permian, this may be the place to start today. Petroleum Economist provides an update on the Permian.

I don't believe Conoco was mentioned in the article: for a note on Conoco in the Permian, see this link.

I track the Permian, Spraberry, Wolfcamp, and Delaware at the sidebar at the right.

This article mentioned Occidental's enhanced oil recovery program in the Permian; for more on that see this link and/or go to Occidental's web page

Some data points that caught my attention:
  • some folks are worried that what happened to natural gas prices will happen to crude oil prices; experts suggest that is nonsense, based on what they are finding in the Permian
  • of the Big Three (the Bakken, Eagle Ford, and the Permian), the Permian was the last to be hit hard by the slump in oil prices
  • the Permian reached record production (at the time) of 2 million bopd in the 1970s (following the Arab oil embargo); but by the late 2000s, production had fallen to less than 1 million bopd -- mostly from stripper wells producing 10 bbls/day
  • during recent boom, back to 2 million bopd; produces about a fifth of total US production
  • EOG estimates well costs at $11.5 million/well; hopes to get costs down to $6.8 million/well this year (compare with Bakken which is clearly in the $7 million/well range)
  • productivity rising: new-well production per rig has jumped from around 100 bopd in 2013 to more than 400 bopd now
  • operators scaling back: Apache -- one of the three largest landholders in the play, with 3.2 million acres now has 10 rigs but will drop to 4 rigs this summer; Apache will complete a quarter of the wells it completed in 2015; output now at 174,000 bopd will fall off
  • Pioneer Natural Resources: 117,000 bopd; has a new $76 million HQ in Midland; will cut all drilling activity in Eagle Ford this year and focus on west Texas; it will pull 6 rigs out of Spraberry and Wolfcamp, bringing rig count down from 18 to 12 by the middle of this year; with all that, Pioneer suggests it will increase production in 2016
  • Cimarex: will reduce its six rigs to two by June; will bring in only 31 new wells this year vs 60 in 2015
  • Chevron may be leading the new charge: it has amassed a huge 2 million-acre position in the Permian; has identified 4,000 wells it could profitably drill in the Permian at an oil price of $50/bbl; though few would be profitable in the mid-$30s; the figure rises to 5,500 wells with an oil price less than $60/bbl; could see output rise 125,000 bbls to between 250K and 350K boepd by 2020
  • Occidental: Permian's biggest producer -- thanks to its huge conventional enhanced-oil-recovery output; sees drilling getting cheaper; at $40/bbl, OXY sees few profitable prospects; but at $50/bbl, nearly 1,200 of the 8,500 identified drilling locations would "return handsomely"; at $6/bbl, it's 3,400; due to falling costs, that's 700 more wells than last year
  • Concho Resources: a top-three Permian producer; pumping about 95,000 bopd; at today's costs, 5,400 of its 18,000 potential drilling sites generate more than a 20% rate of return at $40/bbl
From the article, regarding the current price slump and Saudi's perspective:
From Caracas to Riyadh, rival producers assumed that low oil prices would force out the high-cost American upstarts, allowing more space for their own cheaper-to-extract oil. That was a central tenet of the Saudi-led Opec decision of 2014 to let the market plunge. The plan would only work if US tight oil producers – source of the bulk of global output growth in recent years – yielded in their stubborn battle to keep the pumps moving.

It has taken longer than Opec would have liked. But the sharp downturn in this West Texas oil frontier in early 2016 shows that even the mighty Permian is not immune to low oil prices. By 11 March, the number of rigs drilling for oil had fallen to 150, down by 50 in just three months, and down 75% from the 562-rig peak hit in October 2014. The Permian’s top producers are finally scaling back investment – though most of them did so only after cutting to the bone in other areas. Permian capital expenditure cuts in 2016 will be less than the 50% expected across the US, but investment will likely fall by at least a third unless oil prices recover soon. The US Energy Information Administration (EIA) says output has already flat lined. Petroleum Economist expects the Permian’s production to fall by around 30,000 b/d by the end of 2016 – a sharp reversal of annual growth in recent years of about 200,000 b/d.

Its remarkable rise should have been no surprise, because the Permian has long been at the heart of America’s oil industry. It is vast, stretching through West Texas and into southeastern New Mexico. If a driller imagined his ideal play, this was it. The Permian is flat and sparsely populated; its climate is mostly mild; and the community and political institutions have risen up around the industry. Underground is a complex arrangement of oil-producing rock formations, some stacked one on top of the other, spread out over an area covering around 86,000 square miles, roughly the size of Ghana.
Pricing:

Taken together, the data suggest that oil prices have to rise out of the $30s to see the Permian recover, but not by much. Crude prices around $45/b would likely see roughly flat production. Put the market back in the $60s, though, and activity would go full-bore, and production sharply higher.
Those kinds of numbers will keep rival global producers up at night. But pinning down a price at which the Permian would roar back to life is difficult.  
Much, much more at the link.

Norway Has More Problems Than $40 Oil -- March 31, 2016

Updates

February 4, 2019: Bloomberg update.

January 2, 2019: Norwegian production to fall to 30-year low.

December 8, 2018: from Equinor's website, this date -- Johan Sverdrup—the North Sea giant Johan Sverdrup is one of the five largest oil fields on the Norwegian continental shelf.
With expected resources of between 2.1—3.1 billion barrels of oil equivalents, it will also be one of the most important industrial projects in Norway in the next 50 years. The development and operation of this enormous field will generate revenue and provide jobs for coming generations.
August 6, 2017: Lofoten Islands and $65 billion in oil off-limits to oil companies.

Original Post 

There was a long story yesterday about the problems the Norwegian economy has secondary to the oil and gas industry in their neck of the woods. Here are data points from the original article:

First problem: $40 oil.

Second problem: discovery wells disappointing.
  • 2015: discovery wells off Norway averaged 5 million bbls of oil and gas
  • for past 25 years: discovery wells off Norway have averaged 27 million bbls of oil and gas 
  • dismal results due in part to depletion of the reserves in the North Sea
  • Norway's oil production has shrunk by half since 2000
  • Norway has the world's biggest sovereign wealth fund; in January, 2016, the government made its first withdrawal from the fund since it was set up in the 1990s
Third problem: challenges going where the oil is.
  • operators are giving up on the Arctic around Alaska and Greenland
  • operators now looking to the Arctic areas around Norway and bordering Russian waters
  • Norway planning to award licenses in an area known as the Barents Sea Southeast
  • apparently these Arctic waters are less hostile (due to the Gulf Stream); also shallower and mostly ice-free
  • Barents Sea Southeast
  • bilateral border order agreement reached with Russia in 2010
  • drillers have started drilling discovery wells
  • oil companies will cut spending for third consecutive year
  • will drill only half as many exploration wells in 2016 as in 2015
  • CAVE dwellers not happy
Johan Sverdrup field: not in the Barents Sea, but in the North Sea
  • the largest discovery "in" Norway in recent years; discovered by Lundin in 2010
  • could hold as much as 3 billion bbls of oil (I assume that's "recoverable," not OOIP)

Thursday, March 31, 2016. Wow -- Claims Surge 11,000! There's That Word Again: "Unexpectedly"

Active rigs:


3/31/201603/31/201503/31/201403/31/201303/31/2012
Active Rigs3099194188206

RBN Energy: ports and pipelines delivering East Coast refined products.

On glide path for record gasoline demand this summer. WSJ on gasoline demand.

San Antonio Spurs break record for most home wins to start NBA season. Link over at Bleacher Report.
The Golden State Warriors may be dominating headlines as they pursue the NBA's single-season wins record, but the San Antonio Spurs made history of their own Wednesday night when they broke the 1995-96 Chicago Bulls' record for the most home wins to start an NBA season. 
The Spurs, who look like a virtual lock to capture the Western Conference's No. 2 seed, improved to 38-0 at with a 100-92 win over the New Orleans Pelicans at AT&T Center and secured a spot in the league's record books.
Unemployment claims, first-time: forecast --  an increase of 2,000 claims; up to 267,000 from last week's 265,000.  Actual: first time claims surge 11,000 -- completely unexpected! The four-week average also jumped significantly: it rose 3,500 to 263,250. From Reuters:
The number of Americans filing for unemployment benefits unexpectedly rose last week, but remained below a level associated with a strong labor market.
Initial claims for state unemployment benefits increased 11,000 to a seasonally adjusted 276,000 for the week ended March 26, the Labor Department said on Thursday. The prior week's claims were unrevised. 
Economists polled by Reuters had forecast claims remaining unchanged at 265,000 in the latest week. 
Applications for unemployment benefits have now been below 300,000, a threshold associated with healthy labor market conditions, for 55 weeks, the longest stretch since 1973. With the labor market continuing to tighten, there is little scope for significant further declines in claims. [This is boilerplate; probably written before the numbers were known.]
Tesla Model 3 to be unveiled tonight. Elon Musk promises a car for the masses at $35,000. Will likely come in at higher price than $35,000 initially; doubt "confirmed" price will be announced tonight. No link. Stories everywhere. In fact, it's the headline story over at Yahoo!Finance at the moment.

Wednesday, March 30, 2016

Norway Has More Problems Than Just $40 Oil -- Bloomberg -- March 30, 2016; Iran Won't Be "Moving" As Fast As Earlier Expected

Wow: Over the past 25 years, exploration wells off Norway averaged 27 million bbls -- 27 million bbls/exploration well -- until this past year. This past year, on average, each exploratory well off Norway averaged less than 5 million bbls of oil and gas. 
 
Bloomberg is reporting Norway has more problems than $40 oil:
The collapse of crude prices isn’t the only problem facing energy companies in Norway: Explorers in western Europe’s biggest oil-producing nation also have had their leanest drilling spell in almost a decade.

Companies searching off Norway found less than 5 million barrels of oil and gas for every exploration well drilled last year, the lowest ratio since 2006. That compares with a 27 million-barrel average over the past 25 years.

The dismal results, due in part to the depletion of the North Sea, are bad news for a country whose oil production has shrunk by half since 2000. The slump in prices has already dried up income from crude extraction, which feeds the world’s biggest sovereign wealth fund and has made Norwegians some of the richest people on the planet. In January the government made its first withdrawal from the fund since it was set up in the 1990s as the market rout eroded growth.

The dwindling drilling success has left the country’s top explorers -- Statoil ASA and Lundin Petroleum AB -- impatient to tap an entirely new region of the nation’s Arctic, bordering Russian waters. Norway plans to award licenses in an area known as the Barents Sea Southeast before summer and drilling could begin as soon as 2017.
Much more at the link.

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Iran
Reuters/Rigzone is reporting:
Iran is expected to add half a million barrels of oil supply a day within a year from its existing oilfields after the lifting of sanctions against Tehran in January, but developing new fields would take time, the head of the International Energy Agency said on Wednesday.

Iran, previously OPEC's second-largest exporter, would need to prove that the investment conditions were profitable to the international investors and also that there was predictability in the markets.

[IEA's] estimate of Iran's supply increase from existing oilfields was in line with previous market estimates. And increases in Iranian gas supplies would come after oil.
"It was misleading to believe that there would be a huge amount of new Iranian crude and natural gas production entering market in the short term," [IEA head] said.

"It would take some time in terms of developing new oil fields, finding transmission routes and having the necessary market conditions."
Iranian oil officials were hoping for a quick rebound in oil sales to European clients, which accounted for over a third of Iran's exports, or 800,000 barrels per day, before the European Union imposed sanctions in 2012 over Tehran's nuclear programme.

If Something Is Shut Down For Six Months, Is It Really Needed? -- March 30, 2016

Updates

April 4, 2016: The New York Times is reporting that the nation's capital's subway, only 40 years old, is creaky and at a mid-life crisis --
The Federal Transit Administration has issued a blistering indictment of the system, warning in a June report of “serious safety lapses.”
That month, the National Transportation Safety Board convened hearings revealing that employees of the Washington Metropolitan Area Transit Authority — which runs Metro, as well as a regional bus service — often felt afraid to report safety concerns.
Commuters are frustrated and are abandoning the subway. Weekday ridership declined 6.1 percent in the last half of 2015, Metro officials say, compared with the same period the previous year. Metro’s new general manager, Paul J. Wiedefeld, who shut down service last month for a daylong emergency inspection after a tunnel fire similar to one that killed a passenger in January 2015, concedes that the public is losing faith.
I was unaware of that: more folks have been killed in Washington, DC, metro (subway) fires in recent history than have been killed in the US from CBR explosions/fire during the nine (9) years of the Bakken boom/bust.

I assume Hillary will hear this -- about the lack of safety on light rail, connect the dots with CBR, and propose to ban fracking. She proposed banning fracking as a solution to lead-contamination problem that Flint, MI, has. I can't make this stuff up.

Original Post
 
Uber could get huge Lyft in DC.

The Washington Post is reporting that the city's metro authorities are considering shutting down the entire system for six months for system-wide maintenance.
Metro’s top officials warned Wednesday that the transit system is in such need of repair that they might shut down entire rail lines for as long as six months for maintenance, potentially snarling thousands of daily commutes and worsening congestion in the already traffic-clogged region.
[Authorities] put rail riders on notice about possible extended closures at a high-level conference of local leaders.
The discussion also revealed strong resistance to what Evans said was a “dire” need for more than $1 billion a year in additional funding for Metro.
Yes, six months, not six weeks.

Funny how things work out. The metro authorities couldn't even think of doing this if Uber and Lyft didn't exist.

John Kemp's Weekly Energy Tweets -- March 30, 2016; Payback!

US gasoline stocks, adjusted for demand: 26 days in 2016; 26 days in 2015; 10-yr range 22 - 26 days; average 24 days; at high end of normal, but manageable

US gasoline stocks fell 2.5 million bbl last week; only 6% higher than 2015 at this time; gasoline stocks have come way, way down but still well above historical levels

I talked about US gasoline consumption earlier (at this link); looking for gasoline demand record this calendar year

US commercial crude stocks continue to rise, but perhaps at a slower rate: increased another 2.3 million bbls last week; now at +63 million bbls (+13%) over 2015 level; the graph needs to be reset

US crude oil imports eased back a bit from previous week's very high 8.4 million bopd to a more normal 7.8 million bopd

US refinery throughput accelerated last week to 16.2 million bopd, up by one-half million bopd (+3.2%) compared with 2015

US distillate stock adjusted for consumption (44 days) is still far above 2015 (33 days) but not getting worse

 US distillate consumption is finally back within the 10-year max-min range; but very, very low consumption

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

John Kemp also had several slides showing Saudi Arabia reserve assets in free fall as well as other data points suggesting the crude oil slump is having a very, very big impact on Saudi Arabia. I think we will get a better feeling just how severe the Saudis think this is when the April 17, 2016, meeting is held.

I find this graph particularly interesting; many, many story lines:


************************************
Payback

The feud between Apple and the FBI apparently goes back many years, maybe as far back as 2008, it seems I've read somewhere. Whatever.

The FBI, no doubt, was really, really peeved when Apple would not help them with the most recent high-profile case, the San Bernardino terrorist shooting. Not only was FBI peeved, they were made to look inept not being able to hack a simple telephone.

But now that they have the "key to the magic kingdom" -- or at least access to the Israelis who have access to the "key" -- it looks like the FBI is going to make the most of it. The headline in tonight's Los Angeles Times on-line edition:
FBI Agrees To Help Arkansas Prosecutors Open iPhone After Hack of San Bernardino Device. 
This particular iPhone may hold evidence in an Arkansas murder trial.

Payback.

I have no dog in this fight. This chess game between the FBI and Tim Cook is getting as good as the chess game between Obama and Putin.

Random Update On The Road To Germany -- March 30, 2016

Update

Germany’s switch to renewable energy sources is a success story. [Yes, that's the first line -- Germany's switch to renewable energy sources is a success story. Now the article goes on to say how this appears to be a "trainwreck." If this is how Handelsblatt defines a "success story," I sure hope Germany does not have something they would call a failure. Oh, that's right; they do: open borders.]
Ever since the country dedicated itself to a transformation of its energy supply following Japan’s Fukushima nuclear disaster five years ago, renewables have been booming. Last year, they accounted for a third of the energy consumed in Germany.
But while this success goes far in protecting the climate and environment, it has an economic downside. The electricity market has come apart at the seams.
While wind and solar electricity are being fed into the grid at set prices on a priority basis, natural gas- and coal-fired power plants, and soon nuclear power plants, are being forced off the market.
The price of electricity on the wholesale market has been in freefall for five years, plunging from €60 ($67.37) per megawatt-hour to the current €20.
The situation poses an existential threat for German operators of conventional plants like E.ON and RWE.
According to Trendresearch, a marketing research institute commissioned by Handelsblatt, the use of conventional power plants will continue to decrease. The gas- and coal-fired power plants and the nuclear power plants that remain on the grid will produce around 435,000 gigawatt hours of electricity this year.
Although that’s about two-thirds of the total German electricity production, the power plants were designed for 521,000 gigawatt hours. This means the utilization of their capacity is lagging around 17 percent below what they were designed for. By 2020, the gap between capacity and production is likely to increase to 23 percent.
The plunge in price is putting the heads of E.ON and RWE, Johannes Teyssen and Peter Terium respectively, in a predicament. With prices of €20, restructuring is in danger. When Mr. Teyssen decided to spin off the ailing power plants in 2014, the megawatt-hour of electricity was still at €33.
At the moment, the two executives are watching as their business is virtually imploding. First gas-fired power plants were forced off the market, then the black coal plants, and now low-priced lignite and even nuclear energy is struggling against being shut down.
While consumers are being forced to pay rising prices for electricity because of constantly higher taxes, fees and levies, the quoted rates on the wholesale market for electricity from coal, gas and nuclear power plants have been heading in the other direction for years. In recent weeks, they reached a dramatic low point that no manager would have thought possible.
At times, the price of electricity broke below the €20 per megawatt-hour mark on the futures market. Five years ago, before Germany’s energy transition was stepped up, the price was sometimes over €60. Since then, the market has been flooded with expensive wind and solar electricity.
Much more at the linked article.

The question I have: how does this play out? It appears that Germany runs the risk of conventional power plants being taken off line past the point that intermittent energy (wind, solar) can make up the difference.

What we have is this:
  • German consumers are paying more and more for home electricity
  • their conventional power plants may have to be taken off-line; some conventional providers may go broke
  • at some point, too many conventional plants not on-line, but intermittent energy neither adequate/nor dependable --> brownouts or worse
I honestly don't know how this plays out.

This was the ORIGINAL POST
 
Flashback: this was posted September 21, 2014:
Bloomberg is reporting:
When Germany kicked off its journey toward a system harnessing energy from wind and sun back in 2000, the goal was to protect the environment and build out climate-friendly power generation.
More than a decade later, Europe’s biggest economy is on course to miss its 2020 climate targets and greenhouse-gas emissions from power plants are virtually unchanged.
Germany used coal, the dirtiest fuel, to generate 45 percent of its power last year, the highest level since 2007, as Chancellor Angela Merkel is phasing out nuclear in the wake of the Fukushima atomic accident in Japan three years ago.
The transition, dubbed the Energiewende, has so far added more than 100 billion euros ($134 billion) to the power bills of households, shop owners and small factories as renewable energy met a record 25 percent of demand last year.
RWE AG, the nation’s biggest power producer, last year reported its first loss since 1949 as utility margins are getting squeezed because laws give green power priority to the grids.
“Despite the massive expansion of renewable energies, achieving key targets for the energy transition and climate protection by 2020 is no longer realistic,” said Thomas Vahlenkamp, a director at McKinsey & Co. in Dusseldorf, Germany, and an adviser to the industry for 21 years. “The government needs to improve the Energiewende so that the current disappointment doesn’t lead to permanent failure.”
While new supplies sent wholesale power prices to their lowest level in nine years, consumer rates are soaring to fund the new plants. Germany’s 40 million households now pay more for electricity than any other country in Europe except Denmark, according to Eurostat in Brussels. A decade ago, Belgium, the Netherlands and Italy all had higher bills than Germany.
“Politicians are often trying to kid us,” Claudia Fabinger, a 65-year-old self-employed marketing manager, said in between shopping for groceries on Leipziger Strasse in Frankfurt. “Our power bills keep rising and rising to fund clean energies; on the other hand, we are still polluting the air with old coal plants.” 
The entire article is a must-read. Go to the link to read the full article. As you read the article, remember: Germany accounts for 2.4% of all the CO2 emitted into the atmosphere. A lot of pain for making absolutely no difference. And now it seems, they don't even feel good about it.

The story above ... well, what can I say? It can't be much worse. But, actually it is. Just a few weeks ago, the Germans said this sacrifice was their gift to the world (at the linked post, scroll down to "tilting at windmills") (I can't make this stuff up):
I'm posting this for the archives. I assume no one will read the entirety of the linked article over at The New York Times. The article is on Germany's transition to renewable energy. It is costing the average German a lot of money, and there are questions whether the transition will even succeed. The article concludes:
“Indeed, the German people are paying significant money,” said Markus Steigenberger, an analyst at Agora, the think tank. “But in Germany, we can afford this — we are a rich country. It’s a gift to the world.”
I wonder if the average German is aware how little their efforts will result in anything meaningful. I wonder if the average German has looked at the graphic at the bottom of this article. Because it's always possible that the graphic will disappear some day, here are the data points.
Unrelated, but the thousands of folks who attended today's global warming march in NYC arrived in 500 diesel-burning buses. Not natural gas buses, or propane buses, or electric buses. But diesel buses.

SandRidge Eyes Bankruptcy; WMB To Lay Off !0% Of North American Workforce -- March 30, 2016

Reuters is reporting:
SandRidge confirmed on Wednesday it has hired advisers to evaluate options including a bankruptcy filing, in what could be the most high-profile reorganization yet in U.S. shale oil industry.
Williams (WMB) to lay off 10% of workers in North America.
Tulsa, Okla.-based Williams Cos. has begun laying off workers as part of its 2016 business plan, announced January 25.
The business plan aligns the company’s future growth with the realities of the current market. The company is laying off approximately 10 percent of its total workforce across North America.
Prior to the layoffs, the company employed 6,700 workers. The company began implementing cost reduction initiatives in 1Q 2016, which include postponing salary increases, significantly reducing or eliminating hiring in some areas of the company, reducing the number of contractors and reducing the use of outside services.
Layoffs will be completed this week and Williams will provide severance, including benefits and outplacement services to affected employees.
In September, pipeline giant Energy Transfer Equity announced it would buy Williams Cos. In a recent filing, Energy Transfer stated it plans to consolidate corporate offices in Dallas, which would reduce Williams’ presence in Tulsa and Oklahoma City.
Williams’ recent workforce reductions are “focused solely on sustaining Williams’ future growth and not related to the proposed merger with Energy Equity Transfer.”

Seventeen (17) Permits Renewed; Otherwise Not Much Activity -- March 30, 2016

No wells coming off the confidential list Thursday. There was no 31st day in September, 6 months ago.

Active rigs:


3/30/201603/30/201503/30/201403/30/201303/30/2012
Active Rigs3196194188205

Fifteen (15) wells approved for "tight hole" status, including fourteen (14) CLR Jersey wells.

Seventeen (17) permits renewed:
  • CLR (14), Jersey permits in Mountrail County
  • Whiting (2), two Bartleson permits in Mountrail County
  • Enerplus (1), a Morgan permit in Dunn County
No DUCs were reported as completed.

Saudi Arabia's Official Reserve Assets Fall Another $9 Billion In February, 2016

John Kemp, perhaps the best of the readily accessible energy analysts (with no hidden agendas as far as I can tell), has a number of tweets today with graphics depicting how severely Saudi Arabia has been impacted by the low price of oil. There are probably at least six such tweets with graphics. This one may be the best:


Another depiction, in a different format, cumulative change, has data only through January, 2015, at this post: http://themilliondollarway.blogspot.com/2016/03/one-new-permit-two-more-ducs-march-3.html.

You can see that prior to October, 2014, before Saudi opened the spigots, the +/- fluctuated around "0" suggesting that cash flow from continuing operations were meeting Saudi Arabia government's budgetary demands. However, by December, 2015, the crunch was beginning, with a negative cash flow of around $8 billion for the month.

The upside down "U" shape of the curve between February, 2015, and December, 2015, has me perplexed. I have some ideas, but not many.  It appears the upside down "U" may be starting again.

California CBR -- RBN Energy -- March 30, 2016

Considering CBR makes up only about 3% all oil that reaches California, it seems hardly worth it to go through this RBN Energy article, but there are some interesting data points now, and it's always possible CBR will increase at some point.

Data points from the article, written quickly and without much worry about grammar or format. I went through this quickly; there are likely to be factual and typographical errors. If this information is important to you, go to the source. Do not use these notes to make any financial, investment, travel, or relationship decisions.

Intro
  • neither CBR or terminal build outs have made much a dent in California's crude oil supply
  • December, 2013, height: 36,000 bopd; 2% of the state's 1.9 million bopd refining capacity
  • have since dwindled to a trickle
Recap: this is part 7 in RBN Energy's series on North American CBR in 2016
  • Part 1: CBR declines in response to narrower spreads between WTI/Brent; prior to that, congested pipelines resulted in spreads of $25/bbl which made CBR attractive; CBR grew from 33,000 bopd in January, 2010, to a peak of 928,000 bopd in October, 2014; now pipeline capacity has greatly improved
  • Part 2: looked at the epicenter of the CBR boom in North Dakota; slower-than-expected decline in rail shipments; take-or-pay; some routes to the East Coast and West Coast did not have pipeline
  • Part 3: CBR traffic out of the Niobrara;
  • Part 4: fate of CBR load terminals in western Canada that were overbuilt and underutilized
  • Part 5: CBR market destinations beginning with the East coast
  • Part 6: first of a two-part series looking at CBR unloading on the West coast with the Northwest refineries; those refineries continue to receive fairly significant shipments of CBR from North Dakota in the face of narrowing spreads between West Coast benchmark Alaskan North Slope (ANS) and WTI -- in part because Washington refiners are committed to term throughput contracts and railcar leases
  • Part 7: complete the West Coast review with a look at California CBR traffic and termainals
California
  • CBR incredibly small, even compared to Pacific Northwest
  • to less than 1,000 bopd in December, 2015
  • almost all CBR shipments into California came from PADD 2 -- assumed to be Bakken crude from North Dakota -- but were a trickle -- averaging 2,000 bopd over the year
  • 2013 was the "bumper" year for California CBR from Canada, about 3,700 bopd from the Bakken and 2,600 bopd from the Rockies (WY's Denver Juleburg Basin and Utah)
  • no reported Bakken imports in 2015
  • low spreads between ANS and Canadian benchmark Western Canadian Select pretty much shut off Canada, also
  • the only CBR shipment to California in 2015 came from the Rockies and from New Mexico; CBR shipments to CA from NM actually peaked in December 2014 at 6,400 bopd and likely consisted of Permian crude (WTI or West Texas Sour (WTS)).
California -- an island
  • net importer of crude oil
  • no pipelines from east of the Rockies or from the Northwest
  • CBR seems perfect except CA uses medium grade and heavier crudes vs light shale crudes from ND or west Texas
  • but the principal reason: painfully slow build out of rail unload terminals in California
CA CBR terminals
  •  reviews the five (5) largest CBR facilities
  • for a unit train to be economical, generally requires 100 or more rail cars at a time 
  • of the five terminals, only one is currently operating and is relatively small at 40,000 bopd
  • the other four in some state of limbo
CA terminals for pipeline, barge or truck
  • the list is not comprehensive, but the important ones
  • these terminals just as problematic as the CBR terminals
Bottom line
  • CBR terminals are not welcome in CA and getting a permit "is akin to finding a needle in a haystack"

Gasoline Demand -- On Glide Path To Set US Record This Summer? -- March 30, 2016

I still get a kick out of the Gartman post from yesterday in which Gartman suggested that the greatest "threat" to Big Oil was Uber. There is no question that Uber is the poster child -- or at least one of the poster children -- for disruptive technology. I completely missed how big, how disruptive this concept would become. But it has become huge. It is said that Uber has accounted for one billion miles of automobile driving at this point.

I can see where Gartman is coming from, I suppose. If people start sharing rides, less gasoline will be used. So maybe he's correct. But his statement that millennials don't see the need for automobiles is insane. In fact, the millennials are using Uber automobiles.

One wonders if the biggest casualty because of Uber might not be light rail. Uber is most efficient in the very areas where light rail is also most efficient: high-density urban settings. But Uber to light rail is like CBR to pipelines. Uber and CBR are both flexible and scalable. Light rail is anything but flexible or scalable.

Folks using Uber will help cut gasoline consumption, I suppose, if one argues that the rider/passenger would have otherwise taken his own gasoline-consuming automobile. However, if the rider/passenger would have otherwise taken light rail, then the gasoline-consumption issue is a wash, but the light rail is impacted.

One could also argue that as Uber becomes more mainstream, there will be more Uber drivers, and even more incentive for folks to take Uber rather than light rail.

One wonders if there might also be a slight impact on road tolls, but that's quite a stretch.

I'm still looking for US gasoline demand to hit an all-time record this summer. I wouldn't bet the farm on 10 million bbls of gasoline/day but it could be close.

***********************************************
Gasoline Demand -- A Record-Setting Summer?

From an earlier post:

Back on , January 19, 2015, I wrote:
Has the US ever gone over 9.5 million bpd gasoline demand? Yes, starting back in 2003 there were many periods in which demand for gasoline in the US fluctuated around 9.5 million bopd.
  • fourth week in August, 2003: 9.668 bpd
  • second week in August, 2004: 9.521 bpd
  • third week in August, 2005: 9.471
  • first week in August, 2006: 9.697
  • third week in August, 2007: 9.762
  • the last week of August, 2014: 9.480 million bpd
I am unaware of any weekly period in which gasoline demand went over 9.5 million bpd over the Memorial Day Weekend, but it certainly looks like we could do that later this spring. 
Wow, that was back on January 15, 2015, when I wrote that. How did we do? We won't know for another week, but we went over 9.7 million bopd in the most recent reporting week.

I think that's an all-time record for the fourth week in May; if not an all-time record for the fourth week in May, awfully close.

So, back in January, I predicted that we would go over 9.5 million bpd this past Memorial Day weekend which would be a record. We won't know for another week or so, but at 9,734,000 bbls / day last week, that came close to hitting an all-time record. I think the record is 9,762,000 bbls / day, set in the third week of August, 2007.
Note the chart below: gasoline consumption up 5.0% year-over year.

9,762,000 x 1.05 = 10,250,100 -- so, we'll see.


Less Expensive To Drill; Gasoline Supply / Demand Starting To Narrow -- March 30, 2016

EIA:
The profitability of oil and natural gas development activity depends on both the prices realized by producers and the cost and productivity of newly developed wells.
Costs per well generally increased from 2006 to 2012, demonstrating the effect of rapid growth in drilling activity.
Since 2012, costs per well have decreased because of reduced overall drilling activity and improved drilling efficiency and tools. Changes in costs and well parameters, such as the need to drill deeper or longer lateral wells, have affected the onshore oil plays differently in 2015, with recent per-well costs ranging from 7% to 22% below 2014 levels. --- EIA 
*********************************************
Gasoline Demand

Starting to see supply/demand narrow, from John Kemp:




**************************
Silly Rabbit -- I Thought This Project Was Dead

The Boston Globe is reporting:
The Cape Wind energy project suffered another big blow on Tuesday when a state agency recommended that the developer’s request to extend its permit for two power lines for the proposed offshore wind farm be denied.
A spokesman for Cape Wind Associates noted that this represents the Energy Facilities Siting Board staff’s “tentative decision” and that the board is scheduled to act on that recommendation next week.
Cape Wind had sought to extend a permit for the proposed power lines for two additional years, through May 1, 2017. Cape Wind, which wants to build as many as 130 wind turbines in Nantucket Sound, filed its extension request just weeks before its permit was set to expire last May.
On Tuesday, the board’s presiding officer wrote that Cape Wind Associates has not been able to demonstrate that it will be able to start construction on the project by mid-2017. In particular, the likelihood of project construction has seemed more distant since the developer lost two key contracts with National Grid and Eversource Energy in early 2015. 
At some point, one has to ask: what's driving this Quixotic windmill project. To say the least, something is very, very peculiar.

Misfiled File Report: #22217 File Report Misfiled Among #20491 File -- March 30, 2016

Going to the well file report for #20491, CLR's Charleston 1-22H, in Brooklyn oil field, brings us to the file report for that well to include such data as:
  • Spud date: April 7, 2011
  • TD: May 13, 2011
  • the first well to target the Three Forks formation in this township
  • surface site: 330' FSL, 1080' FWL 22-155-98
Then starting on page 46 of this 161-page file report, inexplicably, #22217, CLR's Barmoen 1-18H, geologist's report is filed. This is a completely different well in a completely different area in North Dakota. The report appears to go through page 67 of the file report.

Starting on page 68, we are back to #20491, the Charleston well. The geologist's report is filed again (a duplicate from above). The rest of the file appears to be #20491 (the correct file).

When one goes to the file report for #22217, the Barmoen well, it has the planning report and the permit, but the file report is missing. It appears to be misfiled among the pages of the Charleston well (#20491).

At least I think that is what I'm seeing.

New Wells Reporting -- 2Q16

Data for 1Q16: 1Q16
Data for 4Q15: 4Q15
Data for 3Q15: 3Q15
Data for 2Q15: 2Q15
Data for 1Q15: 1Q15
Data for 4Q14: 4Q14
Data for 3Q14: 3Q14
Data for 2Q14: 2Q14
Data for 1Q14: 1Q14
Data for 4Q13: 4Q13
Data for 3Q13: 3Q13
Data for 2Q13: 2Q13
Data for 1Q13: 1Q13
Data for 4Q12: 4Q12
Data for 3Q12: 3Q12
Data for 2Q12: 2Q12
  Data for 1Q12: 1Q12   
Data for 4Q11: 4Q11 
Data for 3Q11: 3Q11 
Data for 2Q11: 2Q11 
 Data for 1Q11: 1Q11  
 Data for 2H10: 2H10 
Through 1H10: 1H10

Data for 2Q16 will start to be added here on April 1, 2016. Current data, 1Q16, is here.

Thursday, June 30, 2016: 152 for the month; 252 for this quarter
30281, 3,487, BR, Merton 21-15MBH, North Fork, 26 stages; 5.2 million lbs, t9/16; cum 320K 7/18;
32003, 2,640, BR, CCU Zephyr 34-34 TFH, Corral Creek, t2/17; cum 265K 7/18; offline in 2018;
31330, 527, Oasis, Johnsrud 5198 12-18 7B, Siverston, 36 stages, 4 million lbs; t6/16; cum 214K 7/18;
31331, 648, Oasis, Johnsrud 5198 12-18 8T2, Siverston, Three Forks Second Bench, 36 stages, 4 million lbs, t6/16; cum 171K 7/18;

Wednesday, June 29, 2016: 148 for the month; 248 for this quarter
30835, 408, XTO, TAT State Federal 14X-36H, Bear Creek, Three Forks, 49 stages, 11 million lbs, t10/16; cum 206K 7/18;

Tuesday, June 28, 2016: 147 for the month; 247 for this quarter
30282, 2,806, BR, Jerome 21-15MBH, North Fork, 4 sections, 27 stages, 5 million lbs, t9/16; cum 239K 7/18;

Monday, June 27, 2016: 146 for the month; 246 for this quarter
29514, 569, Liberty Resources, ND State 158-95-21-28-4TFH, McGregor, 50 stages, 4.4 million lbs; t1/16; cum 187K 7/18;

Sunday, June 26, 2016: 145 for the month; 245 for this quarter
None.

Saturday, June 25, 2016: 145 for the month; 245 for this quarter
25202, 1,536, BR, Jerome 21-15TFH 3SH, North Fork, Three Forks, 4 sections, 22 stages; 10 million lbs, t9/16; cum 263K 7/18;

Friday, June 22, 2016: 144 for the month; 244 for this quarter
32392, 598, Statoil, Jack 21-16 5TFH-R, East Fork, Three Forks, 49 stages; 5.9 million lbs, t12/16; cum --

Thursday, June 22, 2016: 143 for the month; 243 for this quarter
25201, 3,360, BR, Merton 21-15TFH 3NH, North Fork, 4 sections, Three Forks, 27 stages, 12 million lbs, t8/16; cum 114K 2/17
29516, 379, Liberty Resources, ND State 158-95-21-28-3TFH, McGregor, 4 sections, 50 stages, 4.5 million lbs, t1/16; cum 33K 4/16;

Wednesday, June 22, 2016: 141 for the month; 241 for this quarter
29571, 1,471, HRC, Fort Berthold 148-94-33D-28-6H, McGregory Buttes, 30 stages, 4.5 million lbs, t12/15; cum 36K 4/16; taken off-line 3/16; only produced 21 days 2/16; and one day 3/16;
31072, 1,582, Enerplus Resources, Tackle 149-95-36C-25H TF, Eagle Nest, t10/19; cum 109K 2/17;
31933, 1,155, Hess, HA-Grimestad-LW-152-95-3031H-1, Clear Creek, 4 sections, Three Forks, 50 stages, 3.5 million lbs, t7/16; cum 129K 2/17;

Tuesday, June 21, 2016:138 for the month; 238 for this quarter
25200, 1,776, BR, Jerome 21-15MBH 2SH, North Fork, 4 sections, 24 stages, 4.7 million lbs, t8/16; cum 95K 2/17;
31932, 1,233, Hess, HA-Grimestad-152-95-3031H-6, Hawkeye, t7/16; cum 134K 7/18;

Monday, June 20, 2016:136 for the month; 236 for this quarter
26902, 510, Petro-Hunt, Marinenko 145-97-30B-31-3H,  Little Knife, t7/16; cum 136K 7/18;
29515, 534, Liberty Resources, ND State 158-95-21-28-3MBH, McGregor, 50 stages, 4.6 million lbs, t1/16; cum 58K 4/16; only 25 days in 4/16; choked way back?
31071, 2,200, Enerplus, Bait 149-95-36C-25H, Eagle Nest, t10/16; cum 315K 7/18;
31931, 1,343, Hess, HA-Grimestad-152-95-3031H-5, Hawkeye, t7/16; cum 175K 7/18;

Sunday, June 19, 2016:132 for the month; 232 for this quarter
25199, 2,928, BR, Merton 21-15MBH 2NH, North Fork, t8/16; cum 378K 7/18;
31930, 630, Hess, HA-Grimestad-152-95-3031H-4, Hawkeye, t7/16; cum 154K 7/18;
32076, PNC, BR, CCU Badger 1-3-14TFH, Corral Creek, no production data,

Saturday, June 18, 2016:129 for the month; 229 for this quarter
32230, A, Denbury Onshore, CHSU 43A-21NH 15, Cedar Hills, a Red River B well,
32341, 998, Enerplus Resources, Quillfish 149-95-36C-25H-TF-LLW, Eagle Nest, t10/16; cum 271K 7/18;

Friday, June 17, 2016: 127 for the month; 227 for this quarter
31996, 943, Hess, CA-Stangeland-155-95-2128H-8, Capa, t8/17; cum 65K 7/18;
32077, PNC, BR, CCU Badger 2-3-14MBH, Corral Creek, no production data, 
32177, 623, XTO, Tobacco Garden 31X-29D, Tobacco Garden, t8/16; cum 225K 7/18;


Thursday, June 16, 2016: 124 for the month; 224 for this quarter
31997, 332, Hess, CA-Stangeland-155-95-2128H-9, Capa, t7/17; cum 142K 7/18;
32078, PNC, BR, CCU Badger 2-3-14TFH, Corral Creek, no production data,
32236, TA, Petro-hunt/SM Energy, William 4B-28HN, Ambrose, no production data,

Wednesday, June 14, 2016: 121 for the month; 221 for this quarter
31898, 1,003, XTO, JMB 14X-15B, Capa, t11/17; cum 162K 7/18;
31998, 971, Hess, CA-Stangeland-155-95-2128H-10, Clear Creek, t8/17; cum 88K 7/18;
32176, A, XTO, Tobacco Garden 31X-29CXD, Tobacco Garden, t--; cum 233K 7/18;
32260, 507, Statoil, Enderud 9-4 7TFH, Banks, t8/18; cum --

Tuesday, June 13, 2016: 121 for the month; 221 for this quarter
31897, 582, XTO, JMB 14X-15E, Capa, t9/17; cum 54K 7/18;
32079, PNC, BR, CCU Badger 3-3-14 MBH, Corral Creek, no production data,
32175, 1,090, XTO, Tobacco Garden 31X-29C, Tobacco Garden, t7/16; cum 176K 7/18;
32237, TA, Petro-Hunt/SM Energy, Bella 4B-28HS, Ambrose, no production data,
32270, TA, Statoil, Enderud 9-4 3TFH, Banks, no production data,
32342, 306, Hess, BL-Davidson-156-96-3526H-7, Beaver Lodge, a Devonian well (Three Forks), 50 stages, 3.5  millions lbs, t4/16; cum 92K 7/18; 
Monday, June 13, 2016: 115 for the month; 215 for this quarter
24090, TA, Statoil, Sax 25-36F 8TFH, Banks, no production data,
30426, 1,206, Hess, HA-Sanford-LW-152-96-1819H-1, Westberg, t8/16; cum 211K 7/18;
31896, 1,531, XTO, JMB 14X-15A, Capa, t11/17; cum 200K 7/18;

Sunday, June 12, 2016: 112 for the month; 212 for this quarter
30425, 836, Hess, HA-Sanford-152-96-1819H-10, Westberg, t8/16; cum 95K 7/18;
31895, 1,433, XTO, JMB 14X-15EXH, Capa, t11/17; cum 52K 7/18;

Saturday, June 11, 2016: 110 for the month; 210 for this quarter
24089, TA, Statoil, Sax 25-36F 7H, Banks, no production data,
30424, 926, Hess, HA-Sanford-152-96-1819H-9, Westberg, t8/16; cum 137K 7/18;
31795, 2,218, Whiting, Chameleon State 21-16-1H, Banks, 35 stages, 7.3 million lbs, t12/15; cum 114K 4/16;
31796, 2,186, Whiting, Chameleon State 21-16-1TFH, Banks, 35 stages, 7.3 million lbs, t12/15; cum 65K 4/16;
31797, 1,467, Whiting, Chameleon State 21-16-2H, Banks, 35 stages, 7.3 million lbs, t12/15; cum 117K 4/16;
31894, 1.420, XTO, JMB 14X-15AXD, Capa, t11/17; cum 177K 7/18;

Friday, June 10, 2016: 104 for the month; 204 for this quarter
30423, 932, Hess, HA-Sanford-152-96-1819H-8, Westberg, t8/16; cum 97K 7/18;
30773, 477, XTO, FBIR Grinnell 34X-33A, Heart Butte, t2/17; cum 91K 7/18;
30853, 1,452, Whiting, Ronna 21-4TFH,  Stockyard Creek, t1/16; cum 66K 4/16;

Thursday, June 9, 2016: 101 for the month; 201 for this quarter
30422, 1,279, Hess, HA-Sanford-152-96-1819H-7, Westberg, t8/16; cum 192K 7/18;
30772, 634, XTO, FBIR Grinnell 34X-33E, Heart Butte, t2/17; cum 65K 7/18;

Wednesday, June 8, 2016: 99 for the month; 199 for this quarter
30771, 403, XTO, FBIR Grinnell 34X-33B, Heart Butte, t2/17; cum 81K 7/18;
30852, 2,954, Whiting, Connie 21-4H, Stockyard Creek, total middle Bakken pay zone thickness estimated at 45 feet; a trip gas of 3,475 units with a 6 - 8 foot flare, 37 stages, 6.6 million lbs; t12/15; cum 137K 4/16;
30892, 1,390, Oasis, Andersmadson 5201 43-24 7B, Camp, 36 stages, 4.1 million lbs, t2/16; cum 51K after 42 days;
30893, 984, Oasis, Andersmadson 5201 43-24 8T, Camp, 36 stages, 4.1 million lbs, t2/16; cum 22K after 52 days;
30894, 1,668, Oasis, Andersmadson 5201 43-24 9B, Camp, 36 stages, 4.1 million lsb, t2/16; cum 48K after 2 months;
30895, 869, Oasis, Andersmadson 5201 43-24 10T, Camp, t3/16; cum 15K after 42 days;
31053, 606, Oasis, Andersmadson 5201 42-24 3B, Camp, 36 stages, 4.1 million lbs, t1/16; cum 48K 4/16;
31054, 1,341, Oasis, Andersmadson 5201 42-24 4T, Camp, t1/16; cum 38K 4/16 but only about 20 days/month;
31055, 1,941, Oasis, Andersmadson 5201 42-24 5B, Camp, t1/16; cum 77K 4/16;
31056, 1,259, Oasis, Andersmadson 5201 42-24 6T, Camp, t1/16; cum 45K 4/16;

Tuesday, June 7, 2016: 89 for the month; 189 for this quarter
30421, 1,060, Hess, HA-Sanford-152-96-1819H-6, Westberg, t7/16; cum 164K 7/18;
30846, 3,017, Whiting, P Lynch 155-99-14-33-28-2H, Epping, t12/15; cum 111K 4/16;
30848, 2,249, Whiting, P Lynch 155-99-14-33-28-3H, Epping, t12/15; cum 126K 4/16;
30850, 2,015, Whiting, Marty 31-4H, Stockyard Creek, t12/15; cum 104K 4/16;
31078, 1,901, HRC, Fort Berthold 147-94-2B-11-8H, McGregory Buttes, t12/15; cum 122K 4/16;
Monday, June 6, 2016: 84 for the month; 184 for this quarter
31077, 1,910, HRC, Fort Berthold 147-94-2B-11-7H, McGregory Buttes, 33 stages, 9.8 million lbs, t12/15; cum 75K 4/16; 

Sunday, June 5, 2016: 83 for the month; 183 for this quarter
None

Saturday, June 4, 2016: 83 for the month; 183 for this quarter
31656, 1,167, Hess, BB-Budahn-150-95-0506H-6, Blue Buttes, t5/16; cum 219K 7/18;

Friday, June 3, 2016: 82 for the month; 182 for this quarter
31657, 1,532, Hess, BB-Budahn 150-95-0506H-7, Blue Buttes, t5/16; cum 265K 7/18;
32204, TA, Petro-Hunt/SM Energy, Bison 2B-28HN, Ambrose, no production data,

Thursday, June 2, 2016: 80 for the month; 180 for this quarter
32200, 1,297, Hess, BB-Budahn-LS-150-95-0506H-1, Blue Buttes, t5/16; cum 236K 7/18;
31076, 2,237, HRC, Fort Berthold 147-94-2B-11-6H, McGregory Buttes, t12/15; cum 109K 4/16;

Wednesday, June 1, 2016: 78 for the month; 178 for this quarter
25620, PNC, WPX. Mandan 13-14HY, Reunion Bay,
25621, PNC, WPX. Mandan 13-14HX, Reunion Bay,
25622, PNC, WPX. Mandan 13-14HB, Reunion Bay,
25623, PNC, WPX. Mandan 13-14HW, Reunion Bay,
32203, TA, Petro-Hunt/SM Energy, Bobcat 2-28HN, Ambrose, no production data,

Tuesday, May 31, 2016: 77 for the month; 177 for this quarter
None. November was six months ago and there is no "31st" day in November.

Monday, May 30, 2016: 77 for the month; 177 for this quarter
30709, 991, QEP, State 8-25-24BH, Spotted Horn, 4 sections, t2/16; cum 14K 3/16; only 23 days in 3/16;
30710, 139, QEP, State 4-25-24T2H, Spotted Horn, 4 sections, t2/16; cum --
30711, 670, QEP, Stte 9-25-24BH, Spotted Horn, 4 sections, t2/16; cum --
30712, 817, QEP, State 5-25-24TH, Spotted Horn, 4 sections, t2/16; cum --
30904, 2,024, QEP, State 5-36-1TH, Spotted Horn, 4 sections, t2/16; cum 32K 3/16;
30905, 2,385, QEP, State 9-36-1BH, Spotted Horn, 4 sections, t3/16; cum 27K in 31 days;
32202, TA, Petro-Hunt/SM Energy, Antelope 2B-28HS, Ambrose, no production data,

Sunday, May 29, 2016
: 70 for the month; 170 for this quarter
31080, 2,088, HRC, Fort Berthold 147-94-2B-11-9H, McGregory Buttes, t12/15; cum 63K 4/16;
32223, 905, Hess, EN-Uran A-LE-154-93-2215H-1, Robinson Lake, t5/16; cum 135K 7/18;
32289, 2,491, Statoil, Cheryl 17-20 1H-R, Banks, t11/16; cum 168K 7/18;

Saturday, May 28, 2016: 67 for the month; 167 for this quarter
None.

Friday, May 27, 2016: 67 for the month; 167 for this quarter
26903, 516, Petro-Hunt, Marinenko 145-97-30B-31-5H, Little Knife, t7/16; cum 125K 7/18;
32225, 626, Hess, EN-Uran A-LE-154-93-2214-2, Robinson Lake, t5/16; cum 91K 7/18;

Thursday: 65 for the month; 165 for this quarter
32224, 1,100, Hess, EN-Ruud-LE-154-93-2735H-2, Robinson Lake, t6/16; cum 140K 7/18;

Wednesday: 64 for the month; 164 for this quarter
None.

Tuesday, May 24, 2016: 64 for the month; 164 for this quarter
31223, 1,474, XTO, Harley Federal 24X-15F, Sand Creek, t10/16; cum 135K 7/18;
31837, 1,558, XTO, Lund 21X-17AXD, Sand Creek,t12/17; cum 112K 7/18;
32226, 765, Hess, EN-Ruud-LE-154-93-2734H-1, Robinson Lake, t6/16; cum 109K 7/18; 

Monday, May 23, 2016: 61 for the month; 161 for this quarter
31224, 1,242, XTO, Harley Federal 24-15B, Sand Creek, t11/16; cum 145K 7/18;
31785, 995, XTO, Lund 21X-17E, Siverston, t12/17; cum 54K 7/18;

Sunday, May 22, 2016: 59 for the month; 159 for this quarter
31199, 1,838, XTO, Kaye Federal 13X-3H, Lost Bridge, t5/16; cum 130K 7/18;
31786, 1,826, XTO, Lund 21X-17A, Siverston, t12/17; cum 97K 7/18;

Saturday, May 21, 2016: 57 for the month; 157 for this quarter
31200, 1,139, XTO, Kaye Federal 13X-3D, Lost Bridge, t6/17; cum 33K 7/18;
31225, 444, XTO, Harley Federal 24X-15E, Sand Creek, t12/16; cum 139K 7/18;

Friday, May 20, 2016: 55 for the month; 155 for this quarter
31787, 1,528, XTO, Lund 21X-17F,  Siverston, t12/17; cum 77K 7/18;

Thursday, May 19, 2016: 54 for the month; 154 for this quarter
27685, 872, Oasis, Logan 5601 11-26 8T, Tyrone, t11/15; cum 43K 3/16;
27689, 1,325, Oasis, Logan 5601 13-26 4T, Tyrone, t11/15; cum 63K 3/16;
29042, 914, Oasis, McCauley Logan 5601 11-26 6T29, Tyrone, t12/15; cum 40K 3/16;
29133, 918, Hess, BW-Erler-LE-149-99-1522H-1, Cherry Creek, t5/16; cum 150K 7/18;
31201, 1,505, XTO, Kaye Federal 13X-3G, Lost Bridge, t6/17; cum 123K 7/18;
31226, 1,509, XTO, Harley Federal 24X-15A, Sand Creek, t1/17; cum 185K 7/18; 
31788, 1,401, XTO, Lund 21X-17B, Siverston, t12/17; cum 136K 7/18; 
31881, 1,600, CLR, Corsican Federal 8-15H2, Sanish, t7/17; cum 259K 7/18;

Wednesday, May 18, 2016: 46 for the month; 146 for this quarter
None.

Tuesday, May 17, 2016: 46 for the month; 146 for this quarter
24963, 1,936, Enerplus, Banjo 149-94-02B-01H- TF, Mandaree, t11/15; cum 124K 3/16;
29132, 863, Hess, BW-Erler-149-99-1522H-5, Cherry Creek, t5/16; cum 170K 7/18;
30622, 310, Crescent Point Energy, CPEUSC Aldag 4-36-35-164N-100W, West Ambrose, 4 sections, t1/16; cum 197K 7/18;
31202, 1,083, XTO, Kaye Federal 13X-3C,  Lost Bridge, t6/17; cum 132K 7/18;
31880, 1,276, CRL, Corsican Federal 7-15H, Sanish, t7/17; cum 141K 7/18;

Monday, May 16, 2016: 41 for the month; 141 for this quarter
31879, 1,460, CLR, Corsican Federal 6-15H1, Sanish, t7/17; cum 187K 7/18;

Sunday, May 15, 2016: 40 for the month; 140 for this quarter
29131, 876, Hess, BW-Erler-149-99-1522H-4, Cherry Creek, t41/6; cum --
31878, 972, CLR, Corsican Federal 5-15H, Sanish, t7/17; cum 174K 7/18;
32037, 2,981, Newfield, Skaar Federal 153-96-30-4H, Sand Creek, t2/16; cum 54K after 41 days;

Saturday, May 14, 2016: 37 for the month; 137 for this quarter
32038, 2,202, Newfield, Skaar Federal 153-96-30-3H, Sand Creek, t2/16; cum 54K after 44 days;
Friday, May 13, 2016: 36 for the month; 136 for this quarter
24962, 1,957, Enerplus, Grassy Knoll 2-11H, Mandaree, t11/15; ucm 127K 3/15;
26362, 1,215, MHA 6-28-29H-148-92, Heart Butte, t7/16; cum 127K 7/18;
30970, 1,283, BR, Gudmunson 4-1-26TFH, Elidah, t12/16; cum 194K 7/18;
31060, 3,473, MRO, Heather USA 13-35TFH, Antelope, t5/16; cum 326K 7/18;
31877, 727, CRL, Corsican Federal 4-15H2, Sanish, t7/17; cum 186K 7/18;
32039, 2,308, Newfield, Skaar Federal 153-96-30-2H, Sand Creek, t2/16; cum 50K after 46 days

Thursday, May 12, 2016: 30 for the month; 130 for this quarter
26363, 1,260, QEP, MHA 8-28-29H-148-92, Heart Butte, t7/16; cum 130K 7/18;
30971, 1,042, BR, Gudmunson 3-1-26MBH, Elidah, t12/16; cum 250K 7/18;
31023, 1,647, Whiting, P Berger 156-100-14-7-19-13H, East Fork, t11/15; cum 101K 3/16;
31025, 1,832, Whiting, P Berger 156-100-14-7-19-14H, East Fork, t11/15; cum 84K 3/16;
31061, 2,942, MRO, Juanita USA 13-35H, Antelope, t7/16; cum 384K 7/18;
31876, drl, CLR, Corsican Federal 3-15H, Sanish, no production data,
32040, 2,347, Newfield, Skaar Federal 153-96-30-1H, Sand Creek, t2/16; cum 42K after 46 days;

Wednesday, May 11, 2016: 23 for the month; 123 for this quarter
24046, 1,661, Petro-Hunt, State 154-94-31C-32-2H, Charlson, t1/16; cum 42K 3/16;
31875, 777, CLR, Corsican Federal 2-15H1, Sanish, t6/17; cum 205K 7/18;
32041, 1,229, Newfield, Skaar Federal 153-96-30-5HLW, Sand Creek, t2/16; cum 36K after 46 days

Tuesday, May 10, 2016: 20 for the month; 120 for this quarter
30972, 1,964, BR, Gudmunson 1-1-26MBH, Elidah, t12/16; cum 188K 7/18;
31059, TA, MRO, Ethel USA 13-35TFH-2B, Antelope, no production data,

Monday, May 9, 2016: 18 for the month; 118 for this quarter
30973, 2,325, BR, Gudmuri 1-1-26TFH-ULW, Elidah, t12/16; cu 224K 7/18;
31058, 3,661, MRO, Clarks Creek USA 14-35H, Antelope, t5/16; cum 344K 7/18; (50K well)
31874, 1,561, CLR, Corsican Federal 1-15H, Sanish, t8/16; cum 297K 7/18;

Sunday, May 8, 2016: 15 for the month; 115 for this quarter
31057, 3,490, MRO, Charmaine USA 14-35TFH, Antelope, t6/16; cum 393K 7/18; (50K well)

Saturday, May 7, 2016: 14 for the month; 114 for this quarter
None

Friday, May 6, 2016: 14 for the month; 114 for this quarter
29413, 2,705, Whiting, P Berger 156-100-14-7-6-4H, East Forks, t11/5; cum 102K 3/16;
29414, 2,399, Whiting, P Berger 156-100-14-7-6-4H3, East Forks, t11/15; cum 91K 3/16;
29416, 1,374, Whiting, P Berger 156-100-14-7-6-3H, East Forks, t11/15; cum 84K 3/16;

Thursday, May 5, 2016: 11 for the month; 111 for this quarter
30686, 747, XTO, Rink 12X-4D, Garden, t5/17; cum 135K 7/18;

Wednesday, May 4, 2016: 10 for the month; 110 for this quarter
29735, 2,506, WPX, Wells 32-29HZ, Reunion Bay, t10/16; cum 269K 7/18;
30574, 587, XTO, Rink 12X-4H, Garden, t5/17; cum 145K 7/18;
31598, 336, Hess, EN-Cvancara-155-93-1522H-6, Alger, t5/16; cum 8K after 29 days;

Tuesday, May 3, 2016: 7 for the month; 107 for this quarter
None.

Monday, May 2, 2016: 7 for the month; 107 for this quarter
30573, 1,040, XTO, Rink 12X-4C,  Garden, t5/17; cum 168K 7/18
31599, 466, Hess, EN-Cvancara-155-93-1522H-5, Alger, t5/16; cum 64K 7/18;

Sunday, May 1, 2016: 5 for the month; 105 for this quarter
29736, 2,375, WPX, Wells 32-29HD, Reunion Bay, t10/16; cum 328K 7/18;
29737, 2,248, WPX, Wells 32-29HY,  Reunion Bay, no t10/16; cum 164K 7/18;
31600, 1,388, Hess, EN-Cvancara-LE-155-93-1522H-1, Alger, t5/16; cum 29K after 31 days;
32121, 901, EOG, Austin 437-2635H, Parshall, t51/6; cum 23K after 30 days;
32122, 601, EOG, Austin 436-2635H, Parshall, t5/16; cum 1K after 2 days;

Saturday, April 30, 2016: 100 for the month; 100 for this quarter
32049, 277, SM Energy, Hay Farms 14B-20HN, Skabo, t5/16; cum 8K after 47 days;
32096, 888, Hess, EN-Cvancara-LE-155-93-1523H-2, Alger, t5/16; cum 23K after 26 days

Friday, April 29, 2016: 98 for the month; 98 for this quarter
31949, 463, Petro-Hunt, Glovatsky 145-98-24D-13-1HS, Little Knife, t7/16; cum 164K 7/18;
32120, 871, EOG, Austin 438-2635H, Parshall, t5/16; cum 128K 7/18;


Thursday, April 28, 2016: 96 for the month; 96 for this quarter
18664, 746, Whiting, Eide 5-13H, Truax, t81/10; cum 230K 2/16;
30951, PA, EOG, Van Hook 70-1411H,


Wednesday, April 27, 2016: 94 for the month; 94 for this quarter 
31556, 319, Hess, HA-Chapin-152-95-2932H-6, Hawkeye, t3/16; cum 147K 7/18;

Tuesday, April 26, 2016: 93 for the month; 93 for this quarter
30770, 494, XTO, FBIR Grinnell 34X-33F, Heart Butte, t2/17; cum 60K 7/18;,
31513, 371, SM Energy, Larson Federal 15-34H, West Ambrose, t3/16; cum --

Monday, April 25, 2016: 91 for the month; 91 for this quarter
30769, 531, XTO, FBIR Grinnell 34X-33G, Heart Butte, t7/18; cum 48K 7/18;
31097, 127, Crescent Point Energy, CPEC Elgaard 2-31-32-164N-100W, Colgan, t1/16; cum 12K7/18;
31557, 1,275, Hess, HA-Chapin-152-95-2932H-7, Hawkeye, t3/16; cum 332K 7/18;

Sunday, April 24, 2016: 88 for the month; 88 for this quarter
21111, 1,427, Enerplus, Anna G. Baker 6B-7-2H TF, Moccasin Creek, t6/16; cum --
30768, 612, XTO, FBIR Grinnell 34X-33D, Heart Butte, t1/17; cu 69K 7/18;
31558, 1,432, Hess, HA-Chapin-152-95-2932H-8, Hawkeye, t3/16; cum --
31679, 472, SM Energy, Mo Farms 15-21HS, Musta, t5/16; cum 5K after 20 days;

Saturday, April 23, 2016: 84 for the month; 84 for this quarter
31314, TATD, Sinclair, Porcupine 2-19H, Little Knife, no production data,
31559, 572, Hess, HA-Chapin-152-95-2932H-9, Hawkeye, t3/16; cum --
31934, 2,245, BR, CCU Atlantic Express 41-30MBH, Corral Creek, t2/16; cum 7K after 13 days;

Friday, April 22, 2016: 81 for the month; 81 for this quarter
31005, 1,957, QEP, Henderson 36-25-35-26T2H, Three Forks 2nd Bench, 49 stages, 10 million lbs, Grail, t11/5; cum 25K after 46 days;
31006, 1,906, QEP, Henderson 36-25-35-26BH, 48 stages, 9.7 million lbs, Grail, t11/15; cum 27K after 49 days;
31007, 2,557, QEP, Henderson 1-12-2-11BH, Grail, 48 stages, 9.3 million lbs, t11/15; cum 33K after 51 days;
31008, 2,725, QEP, Henderson 1-12-2-11T2H, Grail, Three Forks 2nd Bench, 49 stages, 8.1 million lbs, t11/15; cum 41K after 47 days;
31560, 1,115, Hess, HA-Chapin-152-95-2932H-10, Hawkeye, t3/16; cum --
31680, 630, SM Energy, Mo Farms 15-21HN, Musta, t5/16; cum 8K after 22 days;
31908, TATD, Statoil, no production data,
32052, 601, Enerplus, Town Hall 148-93-31C-30H, McGregory Buttes, t6/16; cum --

Thursday, April 22, 2016: 73 for the month; 73 for this quarter
29130, 773, Hess, BW-Johnson-149-99-1003H-6, Cherry Creek, t4/16; cum 32K after 1.5 months; 
31569, 471, Crescent Point Energy, CPEUSC Fairholm 4-33-34-164N-100W, West Ambrose, t1/16; cum 14K after 41 days;
31909, SI/NC, Statoil, Enderud 9-4 XE 1TFH, Banks, no production data,
31935, 521, BR, CCU Plymouth 11-29TFH, Corral Creek, t2/16; cum -- 

Wednesday, April 20, 2016: 69 for the month; 69 for this quarter
30947, 1,928, Whiting, P Bibler 155-99-15W-31-7-14H, Stockyard Creek, a big well, the P Bibler wells are tracked here, t10/15; cum 94K 2/16;
31936, 2,204, BR, CCU Plymouth 11-29MBH, Corral Creek, 2/16; cum 6K over 9 days;
32051, 2,066, Enerplus, Dance Hall 14793-06B-07H, Moccasin Creek, t6/16; cum --

Tuesday, April 19, 2016: 66 for the month; 66 for this quarter
29129, 977, Hess, BW-Johnson-149-99-1003H-5, Cherry Creek, t3/16; cum 37K after two months;
31568, 600, Crescent Point Energy, CPEUSC Elgaard 4-32-31-165N-100W, Colgan, middle Bakken, t1/16; cum 20K over 46 days

Monday, April 18, 2016: 64 for the month; 64 for this quarter
29128, SI/NC, Hess, BW-Johnson-149-99-1003H-4, Cherry Creek, no production data,
31639, SI/NC, BR, Old Hickory 43-32 MBH-R, Sand Creek, no production data,
31937, 481, BR, CCU Plymouth 21-29TFH, Corral Creek, 7" casing point reached November 23, 2015; TD reached November 29, 2015; 1st bench, 27 stages, 7.1 million lbs, in drilling target footage, 95.85%; below drilling target footage, 4.15%; lateral gas show with a high of 3,511 units; t2/16; cum --; 

Sunday, April 17, 2016: 61 for the month; 61 for this quarter
None.

Saturday, April 16, 2016: 61 for the month; 61 for this quarter
30227, SI/NC, BR, SunNotch 42-32TFH, Sand Creek, no production data,
31910, SI/NC, Statoil, Sax 25-36F 2TFH, Banks, no production data,

Friday, April 15, 2016: 59 for the month; 59 for this quarter
29499, 1,081, Oasis, Brier 5200 43-22 12T, Camp, ICO, 46 stages, 11.8 million lbs, t12/15; cum 55K 2/16;
29500, 1,618, Oasis, Brier 5200 42-22 11T2, Camp, ICO, 1600 acres, second bench, 46 stages, 4.8 million lbs, t12/15; cum 63K 2/16; only 23 days in February;
29501, 2,158, Oasis, Brier 5200, 42-22 10B, Camp, ICO, t11/15, 46 stages, 5.1 million lbs; cum 92k 2/16; only 20 days in 2/16;
29502, 1,644, Oasis, Brier 5200, 42-22 9T, Camp, ICO, first bench, t11/15; cum 83K 2/16; only 26 days in 2/16;
30226, SI/NC, BR, Old Hickory 42-32TFH, Sand Creek, no production data,
30687, 1,841, Whiting, Flatland Federal 11-4-2H, Twin Valley, 31 stages, 4.2 million lbs, t10/15; cum 103K 2/16; only 24 days in 2/16;
30950, drl-->loc, EOG, Van Hook 71-1411H, Parshall, no production data, in a 4/18/16 sundry form, EOG requests to "plug and abandon the well...EOG intends to use the well bore in the future."
32032, SI/NC, Hess, EN-Pederson-LW-154-94-0408H-8, Alkali Creek, no production data,

Thursday, April 14, 2016: 51 for the month; 51 for this quarter
30225, 2,640, BR, Sun Notch 42-32MBH, Sand Creek, 31 stages; 9.7 million lbs, t10/16; cum 35K 2/17;
30951, drl, EOG, Van Hook 70-1411H, Parshall, no production data,
31981, 109, Denbury, CHSU ML24014SH 15, Cedar Hills, a South Red River B well, t12/15; cum 10K 2/16;
32031, 1,275, Hess, EN-Pederson-LW-154-94-0408H-7, Alkali Creek, 50 stages, 3.5 million lbs, t2/16; cum 19K over 13 days;
Wednesday, April 13, 2016: 47 for the month; 47 for this quarter
31911, SI/NC, Statoil, Enderud 9-4 6H, Banks, no production data,
32030, 917, Hess, EN-Pederson-LW-154-94-0408H-6, Alkali Creek, 4 sections, 35 stages, 2.5 million lbs, t2/16; cum 20K 2/16; only 19 days in 2/16;
Tuesday, April 12, 2016: 45 for the month; 45 for this quarter
31179, 2,124, BR, CCU Atlantic Express 13-19 TFH, Corral Creek, 46 stages, 8 million lbs, t2/16; cum 15K after 27 days;
31180, 3,287, BR, CCU Atlantic Express 23-19 MBH, Corral Creek, 45 stages, 5.1 million lbs, t2/16; cum 13K after 24 days;
32029, 1,258, Hess, EN-Pederson-LW-154-94-0408H-5, Alkali Creek, 4 sections, Three Forks, 50 stages, 3.5 million lbs,  2/16; cum 33K after 25 days;
Monday, April 11, 2016: 42 for the month; 42 for this quarter
30224, 2,544, BR, Old Hickory 42-32MBH, Sand Creek, 34 stages; 5.2 million lbs, t1/17; cum 13K after 22 days; 
31178, 2,044, BR, CCU Pacific Express 12-19TFH, Corral Creek, 46 stages, 8.1 million lbs, t2/16; cum 12K 2/16;
31984, 800, EOG, Austin 439-2326H, Parshall, t5/16; cum 9K after 29 days;

Sunday, April 10, 2016: 39 for the month; 39 for this quarter
31545, 695, Hess, CA-Russell Smith-155-96-2425H-7, Capa, Three Forks, 49 stages, 4.9 million lbs, t7/17; um 48K 2/17;
32050, 2,246, MRO, Martinez USA 24-8H, Wolf Bay, t1/16; cum 42K over 43 days;

Saturday, April 9, 2016: 37 for the month; 37 for this quarter
31174, 1,027, WPX, Peterson 6-5-4 HZL, Van Hook, t8/16; cum 120K 2/17;
31544, A, CA-Russell Smith-155-96-2425H-6, Capa, no test date (probably 5/16); cum 17K after 16 days;
31816, drl, St Croix Operating, Badger 1, Wildcat, no production data,
31983, 708, EOG, Austin 440-2326H, Parshall, 34 stages, 13.31 million lbs; t5/16; cum 101K 2/17;

Friday, April 8, 2016: 33 for the month; 33 for this quarter
30606, 1,090, QEP, Boggs 3-29-32T2HD, Grail, t10/15; cum 100K 2/16; production held back;
30607, 1,000, QEP, Boggs 8-29-32BHD, Grail, t10/15; cum 96K 2/16; 
30608, 1,995, QEP, Boggs 2-29-32T2HD, Grail, t10/15; cum 78K 2/16; production held back; only 8 days in January, 2 days in February;
30609, 2,053, QEP, Boggs 29-32-30-31T3HD, Blue Buttes, t10/15; cum K 2/16; production held back; only 7 days in December, 5 days in January;
30610, 2.202, QEP, Boggs 29-32-30-31THD, Blue Buttes, t10/15; cum 93K 2/16; production held back; 21 days in December, 21 days in January;
30776, 1,345, Whiting, Flatland Federal 11-4-3TFH, Twin Valley, Three Forks 2nd cycle, 31 stages, 4.2 million lbs, t10/15; cum 134K 2/16; only 24 days in February, 16 days in November, 8 days in October. Drilled to vertical depth and the curve in five days. Total depth of the south lateral was reached in ten days from spud. Gas: 800 to 1,000 units. Connection gases as high as 7,958 units, with a 3' to 5' flare. At 21,505 feet it's a lot of pipe.
31543, 592, Hess, CA-Russell Smith-155-96-2425H-5, Capa, t5/16; cum 6K after 11 days;

Thursday, April 7, 2016: 26 for the month; 26 for this quarter
31173, 829, WPX, Peterson 6-5-4 HD, Van Hook, t8/16; cum 93K 2/17;
31542, 323, Hess, CA-Russell Smith-155-96-2425H-5, Capa, t5/16; cum 2K after 4 days;
31703, SI/NC, Statoil, Shorty 4-9F 8TFH, Charlson, no production data,
31982, 689, EOG, Austin 441-2326H, Parshall, 35 stages, 13.55 million lbs, t5/16; cum 161K 2/17;

Wednesday, April 6, 2016: 22 for the month; 22 for this quarter
30688, 1,392, Whiting, Flatland Federal 11-4-2TFH, Twin Valley, 35 stages, 4.2 million lbs, t10/15; cum 108K 2/16; not even full months of production since coming on line;
30774, 1,844, Whiting, Flatland Federal 22-4-5TFH, Twin Valley, 35 stages, 5.8 million lbs, t10/15; cum 214K 2/16; not even full months of production since coming on line;
30775, 175, Whiting, Flatland Federal 11-4-4THF, Twin Valley, 31 stages, 4.5 million lbs, t10/15; cum -- ; 7 days of production back in 10/15; none since;
31172, 1,763, WPX, Peterson 6-5-4 HQ, Van Hook, 61 stages; no proppant data posted, t10/16; cum 97K 2/17;
31236, 1,172, Whiting, Carscallen 31-14-1TFH, Truax, spud August 15, 2015; cease drilling, August 29, 2016; t10/15; cum 51K; production cut way back past two months;
31238, 2,744, Whiting, Carscallen 31-14-3TFH, Truax, spud July 30, 2015; cease drilling, August 12, 2015; 10/15; cum 110K 2/16; not even full months of production since coming on line;
31541, 1,217, Hess, CA-Russell Smith-155-96-2425H-3, Capa, t6/16; cum 25K after 20 days;

Tuesday,  April 5, 2016: 15 for the month; 15 for this quarter
31171, 1,657, WPX Peterson 6-5-4 HC, Van Hook, t10/16; cum 96K 2/16;
31540, 304, Hess, CA-Russell SMith-155-96-2425H-2, Capa, 35 stages, 3.5 million lbs, t5/16; cum 46K 2/17;
31702, SI/NC, Statoil, Shorty 4-9F 7H, Stony Creek, no production data,

Monday,  April 4, 2016: 12 for the month; 12 for this quarter
31539, 373, Hess, CA-Russell Smith -155-96-2425H-1, Capa, t5/16, cum 8K after 8 days;
31625, SI/NC, XTO, Ames Federal 31-13FXG, Grinnell, no production data,
31701, SI/NC, Statoil, Shorty 4-9F 6TFH, Stony Creek, no production data,

Sunday, April 3, 2016: 9 for the month; 9 for this quarter
30968, SI/NC, EOG, Van Hook 48-3626H, Charlson, no production data,
31626, SI/NC XTO, Ames Federal 31-13BXC, Grinnell, no production data,
31700, SI/NC, Statoil, Shorty 4-9F 5H, Stony Creek, no production data,

Saturday, April 2, 2016: 6 for the month; 6 for this quarter
31184, 370, CLR, Addyson 5-23H, Brooklyn, 4 sections, 30 stages, 7.4 million lbs, t2/16; cum 99K 10/16;
31627, SI/NC, XTO, AmesFederal 31X-13G, Grinnell, no production data,

Friday, April 1, 2016: 4 for the month; 4 for this quarter
30969, 1,255, EOG, Van Hook 47-3626H, Parshall, t5/17; cum 170K 7/18;
31628, 375, XTO, Ames Federal 31X-13B, Grinnell, t5/17; cum 87K 7/18;
31699, 133, Statoil, Shorty 4-9F 4TFH, Stony Creek, t3/18; cum 20K 7/18;
31849, 2,470, MRO, Ronald 34-33TFH-2B, Reunion Bay, produced 29K first 24 days while still on SI/NC status (checked April 5, 2017); t2/17; cum 113K 7/18;