Baker Hughes: US Oil Drillers Add Rigs Even As Prices Dive Anew

Baker Hughes: US Oil Drillers Add Rigs Even As Prices Dive Anew
US energy firms add oil rigs for a fourth straight week, according to data that highlights how a period of stable prices earlier this summer lull some drillers into stepping up spending.


Aug 14 (Reuters) - U.S. energy firms added oil rigs for a fourth straight week, according to data that highlights how a period of stable prices earlier this summer lulled some drillers into stepping up spending just before a second oil market slump.

Reflecting plans announced in May and June, when U.S. crude futures averaged $60 a barrel, drillers added two oil rigs in the week ended Aug. 14, bringing the total count up to 672, the highest since early May, oil services company Baker Hughes Inc said in its closely followed report.

They may now regret those moves as U.S. crude has tumbled nearly $20 a barrel to reach a new 6-1/2-year low under $42, prompting a new round of spending and job cuts across the beleaguered global oil industry.

Many forecasters including Australian bank Macquarie expect the rig count to resume drifting lower through the second half of the year as weaker prices bite.

While the number of rigs is still 58 percent lower than it was at its peak last October, the slight rebound over the past month suggests U.S. oil production may be slightly higher than earlier expected, although the effect will take time to see. It can take up to six months for a new well to begin pumping crude.

Drillers added oil rigs in two of the four major U.S. shale oil basins, with five in the Eagle Ford in South Texas and one in the Niobrara in Colorado and Wyoming. They removed two rigs in the Bakken in North Dakota and Montana, while the number of rigs in the Permian in West Texas and eastern New Mexico held steady.

U.S. crude oil prices were on track for a seventh straight weekly loss, the longest losing steak since January, on continued oversupply worries from mostly U.S. and OPEC producers and slumping demand from China and much of the rest of the world.

The last time oil prices collapsed, from around $107 a barrel in June 2014 to under $44 in January, energy firms slashed spending, cut thousands of jobs and idled around 60 percent of the record high 1,609 oil rigs that were active in October.

Production has started to show signs of decline. U.S. crude output dipped to 9.4 million barrels per day last week from 9.5 million bpd in the prior week, according to government data. That is down from average production from mid May to late June of 9.6 million bpd, the most since the early 1970s.

(Reporting by Scott DiSavino, editing by Marguerita Choy)


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Philippe  |  August 18, 2015
It appears those analysts are looking at the drilling as per the standard oil or gas play. What I mean is the reservoir is identified through 3D analysis. Than the wells are strategically locate so the reservoir pressure is balanced. Second the level of heavies with water must be controlled. Third you locate the injection wells to maintain the pressure over the design life of the reservoir. This may involve 10 or 20 or more wells. Once they are drilled, the rigs may do work over, that the extent of the drilling. Shale play using fracking technology is totally opposite. First there is no reservoir, just a geological mass that has been identified as containing oil and/or gas, including NGL. Each well will be fracked to liberate the crude, gas or NGL. At first, for the first 12 month, named Initial Production (IP) will be high. Over time the fracked mass will lose pressure and the rate of production called Estimated Ultimate Recovery (EUR) will be 50% less than the IP production. When this happen, new wells are drilled and old EUR wells are retired. The idea is to keep an average production by mixing the IP versus EUR wells. Looking at the shale play in the US, we can see that the price crash happen 9 to 12 month ago. This is the length of time for an IP well to move into a EUR well. The shale play producers have to start drilling new IP wells to keep their production rate stable. If they don’t, the maintenance cost will not be supported by the earning of the EUR wells only. So yes you can see a couple of rigs going back to work. But this does not mean the bottom is at reach. It means that the producer shutdown the production, or try to stay in business.

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