This group brings together those who are interested in topics around oil and gas exploration, drilling, refining, and processing.

Post

Visualizing Eagle Ford Oil & Gas Production (Through June 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
  • 223 items added with 487,826 views
  • Sep 23, 2021 2:56 pm GMT
  • 815 views

Your access to Member Features is limited.

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.

EF-956757.png

Visit ShaleProfile blog to explore the full interactive dashboard

This interactive presentation contains the latest oil & gas production data from all 25,879 horizontal wells in the Eagle Ford region, that have started producing from 2008 onward, through June.

Total production

Tight oil production in the Eagle Ford was flat for the 3rd consecutive month in June, at 1.1 million b/d (Hz. wells only, after upcoming revisions). The first time the Eagle Ford produced at this level was 8 years earlier, when WTI was almost at $100/bbl. Natural gas production fell in June to about 5.6 Bcf/d.

Supply projection

The number of horizontal rigs in the Eagle Ford has remained at 40 during the past month (according to Baker Hughes). Only 3 of those rigs are drilling in Karnes County, the lowest number in more than a decade, and down from 10 earlier this year. This county is still responsible for 30% of the oil produced in the Eagle Ford. Our Supply Projection dashboard shows what would happen if the rig count would remain at 3 in Karnes:

Karnes.png

The horizontal rig count & tight oil outlook in Karnes County, based on current drilling activity & well productivity, by year of first production

As the bottom graph here shows, 3 rigs would only be able to sustain a long-term output of not much more than 100 thousand b/d, given current well & rig productivity, compared with 300 thousand b/d currently.

Well performance

Can poorer well results explain the reduced interest in Karnes? From our Production Profiles dashboard:

Karnes-well-productivity-1.png

Well productivity (oil rate vs. cum.) in Karnes, by vintage year of first production. Horizontal oil wells only (refrac’s excluded).

The chart on the right shows that average well productivity has fallen since 2017. All vintages are trending towards an EUR of less than 300 thousand barrels of oil, before hitting a production rate of 10 b/d. On the map the well locations of all the included wells are visible, and colored by operator.

The well performance picture becomes worse after we normalize for lateral length:

Karnes-well-productivity-normalized-1.pn

 

Well productivity in Karnes, normalized for lateral length. Horizontal oil wells only (excl. refracs).

This chart shows how average performance, as measured by the cumulative oil recovered in the first year on production, normalized for lateral length, has evolved over time. The wells that were completed in 2020, and have produced for at least a year, recovered only 22.3 thousand barrels of oil, per 1,000′ of lateral length.

Analyzing the data in more detail doesn’t indicate that the abnormal shut-ins during the last 1.5 years were responsible for this deterioration.

Top operators

The output and well locations of the 10 largest operators in the basin are displayed in the final tab. ConocoPhillips and Marathon were both producing at a 1-year high in June. Devon Energy’s production is down by over 75% since the start of 2016.

Finally

Our next post will be on Pennsylvania, which released July production data a while back. The other 2 states in Appalachia recently reported Q2 production data, which is available in our subscription services.

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

Sources

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.
  • FracFocus.org

Visit our blog to read the full post and use the interactive dashboards to gain more insight: https://bit.ly/3i2BaOR

Follow us on Social Media:

Twitter: @ShaleProfile

LinkedIn: ShaleProfile

Facebook: ShaleProfile

Enno Peters's picture
Thank Enno for the Post!
Energy Central contributors share their experience and insights for the benefit of other Members (like you). Please show them your appreciation by leaving a comment, 'liking' this post, or following this Member.
More posts from this member
Discussions
Spell checking: Press the CTRL or COMMAND key then click on the underlined misspelled word.

No discussions yet. Start a discussion below.

Get Published - Build a Following

The Energy Central Power Industry Network is based on one core idea - power industry professionals helping each other and advancing the industry by sharing and learning from each other.

If you have an experience or insight to share or have learned something from a conference or seminar, your peers and colleagues on Energy Central want to hear about it. It's also easy to share a link to an article you've liked or an industry resource that you think would be helpful.

                 Learn more about posting on Energy Central »