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Visualizing Eagle Ford Oil & Gas Production (Through April 2021)

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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 25,761 horizontal wells in the Eagle Ford region, that have started producing from 2008 onward, through April.

Total production

Tight oil production in the Eagle Ford was flat month over month in April at close to 1.1 million b/d. Year over year, output fell by just over 200 thousand b/d.

Supply projection

The number of horizontal oil-directed rigs active in the Eagle Ford basically hasn’t changed in the last 3 months and stayed at 38 as of last week (according to Baker Hughes).

Our Supply Projection dashboard shows what would happen if drilling activity would remain at this level:


Tight oil outlook in the Eagle Ford, based on current drilling activity & well productivity, by county

Unlike in the Permian, where we expect to see renewed growth, output should continue to decline here in the coming period, as is shown in the bottom chart, unless completion activity picks up.

Well performance

Not factoring in the changes in well completion designs, well productivity was unchanged since 2017, as you’ll find in the “Well quality” overview. However, after normalizing for the increase in lateral length, we see that in the core 3 counties in the oil window (Karnes, DeWitt & Gonzales) well results have deteriorated, especially in the past 2 years:


The location and performance of all horizontal oil wells in Karnes, DeWitt and Gonzales, since 2012. Average cum. oil production vs. months on production, by vintage.

The chart on the right reveals that on this normalized basis, the peak in productivity (average cumulative oil recovered per 1k feet of lateral length) was reached in 2017 and that in the last 2 years results have fallen short. I believe that the shut-ins since the start of the pandemic offer only a partial explanation for that (this became apparent after grouping the wells by quarter, instead of year of first production).

Top operators

The output and location of the 10 largest operators in the basin are displayed in the final tab. ConocoPhillips has narrowed the gap with EOG, the number 1, by completing more wells since the start of this year.


Production data for May is already available in our subscription services for about 95% of the wells in Texas.

Our next post will be on Pennsylvania, which just released May production data (also already available in our analytics & data services).

Production and completion data is subject to revisions, especially for the last few months.


For this presentation, I used data gathered from the following sources:

  • Texas RRC. Production data is provided on lease level. Individual well production data is estimated from a range of data sources, including regular well tests, and pending lease reports.


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

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