The Bakken and North Dakota production data fir May is in.

Bakken production was up 33,352 bpd and North Dakota production was up 32,114 bpd. This is quite a shocker. I had not expected production to be up this much. Bakken barrels per day, in May, stood at 1,142,034 and all North Dakota barrels per day was at 1,201,159.

Wells Producing Bakken All N.D. Non Bakken Apr-15 9,527 12,123 2,596 May-15 9,704 12,264 2,560 Change 177 141 -36

From the Director’s Cut:

Apr Sweet Crude Price = $38.33/barrel

May Sweet Crude Price = $44.70/barrel

Jun Sweet Crude Price = $47.73/barrel

Today’s Sweet Crude Price1 = $40.75/barrel (all-time high was $136.29 7/3/2008)

Apr rig count 91

May rig count 83

Jun rig count 78

Today’s rig count is 73 (lowest since November 2009 when it was 63)(all-time high was 218 on 5/29/2012)

The drilling rig count dropped 8 from April to May, 5 more from May to June, and has since fallen 5 more from June to today. Operators continue to experiment with running 1 to 2 fewer rigs than their planned 2015 minimum to see if drill times and efficiencies will continue to improve. This has resulted in a current active drilling rig count that remains 5 to 8 rigs below what was operators indicated would be their 2015 average if oil price remained below $65/barrel. The number of well completions rose slightly from 102(final) in April to 114(preliminary) in May but initial production rates are increasing 10-20% per month as drilling and completions focus more and more on the best portion of the core Bakken and Threeforks area.

Renewed oil price weakness anticipated to last into next year is by far the main reason for the continued slow-down. There was one significant precipitation event in the Williston and Dickinson areas and a separate one in the Minot area, 7 days with wind speeds in excess of 35 mph (too high for completion work), and no days with temperatures below -10F.

Over 98% of drilling now targets the Bakken and Three Forks formations.

At the end of May there were an estimated 925 wells waiting on completion services, the same as at the end of April. To maintain production near 1.2 million barrels per day, 110-120 completions must be made per month.

The EIA’s Short-Term Energy Outlook came out a few days ago. That is where they try to guess the future production and price for oil, for the USA as well as the world. As of late they seem to be getting a little timid with their predictions. They are saying not much growth is happening until the fourth quarter of 2016, and only a slight bump then.

This chart is Non-OPEC Total Liquids in million barrels per day. Production of N.O Liquids surged upwards from September of 2012 until December 2014, gaining 6.38 million barrels per day in those 27 months. That’s an average increase of 236,000 barrels per day per month. But then in January 2015 there was a drop of 800,000 bpd.

Non-OPEC total liquids still have not reached that December high again but the EIA thinks they will by August. I have my doubts. I also think they have their April and May liquids production estimates a little too high here. I have their predictions here starting in June though the EIA starts their projection in July. But there is no way that June production is anything but a guess here, and a bad guess at that.

For four and one half years, US Total Liquids increased by an average of over 100,000 barrels per day per month. Now the EIA says US Liquids have reached a plateau where they will remain through September of 2016. Then for some unknown reason the US will resume it upward surge.

Notice the huge decline of 460,000 bpd in January 2015. But then there was an increase of 160,000 bpd in February, 390,000 bpd in March and 190,000 bpd in April. That’s an increase of 740,000 barrels per day over three months when the US rig count was falling dramatically. I look for those numbers to be revised in the next couple of months.

The EIA STEO has Quarterly US C+C production climbing steadily right through the second quarter of 2015. But then they have C+C production falling through the first quarter of 2016 before leveling out and then climbing again in the fourth quarter of 2016.

The EIA expects prices to stay low through 2016. In the fourth quarter of 2016 they have production increasing but prices falling. There seems to be a contradiction there somewhere.

The EIA has US C+C peaking in 2015. Of course I am sure they expect the increase to continue in 2017 and possibly taking out the 1970 high either in 2017 or soon thereafter. I believe that all depends on the price of oil. If prices stay low I think shale production will continue to collapse.

China Peak Oil: 2015 Is the Year

Intense focus on the North American shale boom, Saudi Arabia, and ISIS obscures an important emerging energy trend: China’s oil production is peaking. This has profound implications for the world oil market, because China is not just a massive importer of crude; it is also among the world’s five largest oil producers, trailing only the U.S., Russia, and Saudi Arabia, and virtually neck-in-neck with Canada.

Daqing’s oil production has declined relentlessly, despite PetroChina’s significant increase in drilling activity in the field during recent years. This suggests a significant risk that production could fall faster than planned. For reference, PetroChina drilled 1,975 development wells in 2002 when oil production averaged 1.079 million barrels per day, but was forced to boost this to 4,498 development wells in 2014, when oil output at Daqing averaged 792,000 barrels per day. In short, the number of development wells drilled increased by nearly 250 percent while oil production fell by roughly 27 percent.

Daqing is the perfect example of what infill drilling can do, and what it can’t do. Infill drilling slowed the decline rate of Daqing but increased the depletion rate. I believe if the infill drilling drops off to what it was before the program began, then production will drop a lot faster than they show in this chart.

Changqing, China’s second largest oil field peaked in 2014.

Despite some recent announcements of additional tight oil discoveries, Changqing’s slowing production growth rate over the past three or four years contrasts sharply with the hyperbolic production growth seen during the booms in world-class tight oil plays like the Bakken and Eagle Ford shales in the U.S. This difference is critically important because to offset production declines and propel significant net growth in a mature oil province like China or the U.S. requires multiple massively robust unconventional fields.

China offshore production will not save the day. A 55% increase in development wells resulted in a 3% increase in production.

China and Russia, two of the world’s five largest crude oil producers peaks in 2015. The US, the world’s third largest producer also peaks in 2015, at least temporarily. And it is very likely that Saudi is at maximum production also. 2015 will be the year of peak oil.

Shale drillers’ safety net is vanishing

The insurance protecting shale drillers against plummeting prices has become so crucial that for one company, SandRidge Energy Inc., payments from the hedges accounted for a stunning 64 percent of first-quarter revenue.

Now the safety net is going away.

The insurance that producers bought before the collapse in oil — much of which guaranteed minimum prices of $90 a barrel or more — is expiring. As they do, investors are left to wonder how these companies will make up the $3.7 billion the hedges earned them in the first quarter after crude sunk below $60 from a peak of $107 in mid-2014.

“A year ago, you could hedge at $85 to $90, and now it’s in the low $60s,” said Chris Lang, a senior vice president with Asset Risk Management, a hedging adviser for more than 100 exploration and production companies. “Next year it’s really going to come to a head.”

The hedges staved off an acute shortage of cash for shale companies and helped keep lenders from cutting credit lines, many of which are up for renewal in October. With drillers burdened by interest payments on $235 billion of debt, $89 billion of it high-yield, a U.S. regulator has warned banks to beware of the“emerging risk” of lending to energy companies.

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