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James Stafford

James Stafford

James Stafford is the Editor of Oilprice.com

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North Dakota No Longer Attractive For Drillers Or Refiners

North Dakota No Longer Attractive For Drillers Or Refiners

The performance of Blood & Oil, a soap opera based on the North Dakota oil boom, is not going well. The show saw its episodes trimmed by ABC amid tepid viewer interest. But the real life Bakken is also suffering from a lack of interest, a development that doesn’t bode well for the oil-producing region.

The Bakken had been a key part of the U.S. shale boom over the past half-decade. But production peaked at 1.22 million barrels per day in December 2014. Since then production has bounced around, with month-to-month fluctuations, but is slightly down from that high point reached almost a year ago.

The EIA expects the Bakken’s production to drop by 23,000 barrels in November, a decline second only to the Eagle Ford in terms of size. Related: Oil Megaprojects Won’t Stay On The Shelf For Long

But falling production is contributing to another problem for the region. Several East Coast refiners are losing interest in Bakken crude, instead preferring to import oil from abroad to use in their refineries. According to Reuters, it is now cheaper for East Coast refiners to import oil from South America, Africa, or the Middle East, than it is to buy oil from North Dakota. The transit costs of moving crude by rail from North Dakota across the country tips the balance in favor of foreign oil.

The U.S. had managed to significantly cut its dependence on imported oil over the past decade, but the share of imports has stopped declining as foreign oil is cheap again. Related: Low Oil Prices Could Persist Through 2016

PBF Energy, Philadelphia Energy Solutions Inc., and Monroe Energy are looking to cut their purchases of oil from North Dakota to their lowest levels in over two years, Reuters reported. After investing in rail links in order to improve access to the Bakken, PBF Energy is slashing its purchases. PBF is opting to import from Colombia, for example, even though it has to pay fees to rail companies after promising to take deliveries of 85,000 barrels per day. PBF has to pay $2 per barrel per day ($170,000 per day) even if it no longer wants deliveries. Still, importing from abroad apparently makes sense.

Philadelphia Energy Solutions has already cut its purchases of oil from North Dakota by 80 percent, switching to imports from Nigeria, Chad and Azerbaijan.

The problem is that the drop off in production has eliminated the discount that Bakken oil traded at to WTI, making it more expensive than oil from other areas that are still suffering from excess supply. Transporting oil by rail can add $10 to the price of a barrel of oil, but importing by tanker only adds $2 to $3 per barrel. The rail transport costs have made North Dakota unattractive for refiners. Related: Putin Is Taking A Big Risk With China Gas Deals

“They are looking for the lowest cost supplies,” Sandy Fielden of RBN Energy told Reuters, referring to refiners. “A few years ago, that was North Dakota, but not today.”

To make matters worse for North Dakota, upstream companies are also finding the region less attractive. Occidental Petroleum announced at the end of October that it was pulling up its stakes and leaving the state. Occidental’s oil fields in North Dakota were losing money and the company saw little prospect of turning things around. Instead, Occidental will focus on the Permian Basin in West Texas, where production is still profitable. Occidental says it sold its North Dakota assets, which it believes will bring in $600 million.

In its third quarter earnings call, Occidental CEO Steve Chazen said that North Dakota simply isn’t as attractive as other shale basins. “We just can't see a situation where we would invest in it…we just don't see how it competes for capital inside the Company in any reasonable price scenario that we can come up with,” Chazen said, referring to North Dakota. Chazen says it is a no brainer to pull out and shift its sights to West Texas. “For us, this $600 million, we could run four rigs in the Permian Basin for a year with this money, or five, somewhere in that range, and generate more production than we would get out of the Bakken.”

By James Stafford of Oilprice.com

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  • Lee James on November 04 2015 said:
    The Bakken was a ticking time bomb for marginal profitability. Investor hype kept it going as product flow was confused with profitability. In addition to all the usual production costs, Bakken investment in piping for gathering the gas by-products of oil drilling never quite materialized. The cost in planetary pollution was always unacceptable. The state of North Dakota was in the process of tightening flaring and venting guidelines. Then ... too late. Potential state revenue will be lost.
  • Daniel Pearson on November 09 2015 said:
    As oil analyst & professional geologist Art Berman pointed out in his recent Forbes article, 'Only 1% of the Bakken Play Breaks Even at Current Oil Prices'. Berman's research has been ongoing for years, and includes horizontal Bakken wells drilled since 2000. His data driven analyses is far reaching and incorporates multiple driving factors in the development history of the Bakken Play. A number of popular media hypes regarding the shale oil boom are dispelled by his incorporation of data to back up his research conclusions. If you are a investor, it would be well worth your time to read his Forbes articles, or articles from his blog site. Previously, I dispelled his work due to not wanting to hear the message he was delivering. I'm a professional Geologist, and I was wrong in ignoring his message regarding the shale oil boom, but his data driven conclusions are spot on. Regards

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