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Visualizing Permian oil & gas production (through February 2019)

ShaleProfile, Visualizing Permian oil & gas production

Permian – update through February 2019

This article contains interactive dashboards also available in the original blog post.

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These interactive presentations contain the latest oil & gas production data from all 20,349 horizontal wells in the Permian (Texas & New Mexico) that started producing since 2008/2009, through February 2019.

The breakneck growth in Permian production during the past 2 years appears to have taken a breather, at least temporarily. I expect that after revisions, production in February will come in 5-10% higher than shown here, or about 3.2-3.3 million bo/d. This would represent just a modest gain from the end of last year. Gas production is now above 10 Bcf/d.

We sometimes get questions about whether our oil numbers include NGLs. That is not the case; many states do not require operators to report NGLs, and we therefore do not publish them either. If condensate is reported separately, we add it to the oil figures.

The “Well quality” tab shows the production profiles of these 20 thousand horizontal wells. They are grouped and averaged by the year in which production began. You can easily see there that initial well productivity has increased further in the past 2 years, although less than in the period from 2013 and 2016. The wells that started in 2018 are on a path to recover almost 150 thousand barrels of oil in the first year on production, on average.

However, this does not take into account that laterals have gotten longer, and that more proppants are used nowadays. If you normalize for either of these factors, as is possible in our advanced analytics service, you’ll find that well productivity already topped out in the middle of 2016.

The ‘Advanced Insights’ presentation is displayed below:

This “Ultimate recovery” overview shows the average production rate for these wells, plotted against their cumulative recovery. Wells are grouped by the quarter in which production started.

As you can see here, peak rates are still going up. The more than a thousand wells that started in the final quarter of 2018 peaked at 880 bo/d, on average. They’re on a path to recover each around 300 thousand barrels of oil, before they’ve declined to a rate of 50 bo/d.

The following screenshot (also from our advanced analytics service) shows how total oil production has developed in the top 8 producing counties in the Permian.

Output in each of these counties has risen strongly in the past three years. The locations of the related horizontal wells are shown on the map.

Later this week we will have a post on the Eagle Ford. Tomorrow at noon (ET) we will present a briefing on all the major shale oil basins in the US, in our ShaleProfile channel on enelyst. If you’re interested, register here for free: enelyst registration page.

Production data is subject to revisions.

Note that a significant portion of production in the Permian comes from vertical wells and/or wells that started production before 2008, which are excluded from these presentations.

For these presentations, I used data gathered from the following sources:

  • Texas RRC. Oil production is estimated for individual wells, based on a number of sources, such as lease & pending production data, well completion & inactivity reports, regular well tests, and oil proration data.
  • OCD in New Mexico. Individual well production data is provided.
  • FracFocus.org
Enno Peters's picture

Thank Enno for the Post!

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Discussions

Matt Chester's picture
Matt Chester on Jun 3, 2019 11:45 pm GMT

As you can see here, peak rates are still going up. The more than a thousand wells that started in the final quarter of 2018 peaked at 880 bo/d, on average. They’re on a path to recover each around 300 thousand barrels of oil, before they’ve declined to a rate of 50 bo/d.

Enno-- what would you say is most responsible for these ever-increasing peaks?

Enno Peters's picture
Enno Peters on Jun 6, 2019 8:25 am GMT

Hi Matt,

One important factor behind that is the increase in proppant loading. There may be other factors as well, hopefully someone with more knowledge about well completions will chime in.

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