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Visualizing Permian Oil & Gas Production (Through August 2021)

Enno Peters's picture
CEO ShaleProfile

Background in AI, worked on developing Supply Chain Planning & Optimization solutions for Quintiq, setting up its business in China. Focus on company direction and the technical development...

  • Member since 2018
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  • Nov 17, 2021

This article contains still images from the interactive dashboards available in the original blog post. To follow the instructions in this article, please use the interactive dashboards. Furthermore, they allow you to uncover other insights as well.

Visit ShaleProfile blog to explore the full interactive dashboard

This interactive presentation contains the latest oil & gas production data from all 32,787 horizontal wells in the Permian (Texas & New Mexico) that started producing from 2008/2009 onward, through August.

Total Production

Permian tight oil production is slowly accelerating and in August rose to about 4.2 million b/d (after upcoming revisions, horizontal wells only), the highest since April 2020 and less than 300 thousand b/d below the peak in March 2020. Natural gas production is already setting new records every month, and came in at 16.6 Bcf/d in August.

Supply Projection

The horizontal rig count in the basin has increased to 258 as of last week (according to Baker Hughes), which is already sufficient to sustain further growth in the coming months and years, assuming that well & rig productivity can be maintained:

Tight oil outlook in the Permian, by state, based on a constant horizontal rig count of 258 and current well/rig productivity.


This image was taken from our Supply Projection dashboard.

Completion designs

Well productivity in the US tight basins has greatly changed in the past 2 decades, especially driven by longer laterals and larger proppant loadings. Here we show how these 2 parameters have changed in the Permian Basin:

Completion designs in the Permian Basin


This year, wells were completed with 20 million pounds of proppants, on average, for the first time. However, as laterals increased in proportion to proppant loadings since 2018, the proppant intensity (proppants / lateral length) has hovered around a level of 2 thousand pounds per lateral ft since 2017, as the bottom chart reveals.

Well productivity

In this post we’ll take a closer look at well productivity trends in the southern part of the Delaware basin:

Well productivity in the southern part of the Delaware Basin. Horizontal oil wells with a first production start >= 2014 only.


On the map you can find the almost 8 thousand horizontal wells included in our analysis, by county. On the right, you can find the production profiles for these wells, by vintage year of first production, normalized by lateral length (rate vs. cumulative production, per 1,000 ft of lateral length).

As you can see, well productivity as measured by this metric has fallen since 2016.

This could be an explanation of why production has fallen sharper in Reeves and Loving, compared with other top-producing counties in the Permian Basin:

Tight oil production in the top 6 counties in the Permian Basin

Top operators

In the final tab (“Top operators”) the production and well positions are displayed for the 15 largest producers in the Permian.


We will have a new post on the Eagle Ford later this week.

Production and completion data are 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 production data.
  • OCD in New Mexico. Individual well production data is provided.

Visit our blog to read the full post and use the interactive dashboards to gain more insight:

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