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About this blog

Visualizing US shale oil & gas production

The blog contains still images from interactive dashboards available on each blog post.
To follow the instructions detailed in every post, use the interactive dashboards. You can also explore the dashboards to uncover different insights and trends.

Entries in this blog

North Dakota – update through May 2018

This interactive presentation contains the latest oil & gas production data through May from all 13,545 horizontal wells in North Dakota that started production since 2005. May oil production in North Dakota came in at 1,245 kbo/d, after a month-on-month increase of 1.6%. This pushed production higher than the previous all-time high in December 2014.   Recent wells are closely tracking the performance of the wells that started in 2017 (see the bottom graph in the ‘Well quality’ tab), on average.   In May 109 new wells started flowing, the highest since September 2015 (see the ‘first flow’ status in the ‘Well status’ overview).     In the final tab (‘Top operators’) you’ll find that ConocoPhillips has grown production the most in the past 1.5 year (percentage wise), to almost 100 thousand barrels of oil per day, making it the 3rd largest producer in this state, behind Continental Resources and Whiting.   The ‘Advanced Insights’ presentation is displayed below: This “Ultimate recovery” overview shows how all these horizontal wells are heading towards their ultimate recovery, with wells grouped by the year in which production started.   More wells started in 2017 than in 2016 (970 vs 724), and their initial performance was also substantially higher, as the plot above shows. They recovered on average almost 100 thousand barrels of oil in the first 6 months on production, a level that took almost 12 months for wells that started 2 years earlier. If you group the wells by the quarter in which they started (using the ‘Show wells by’ selection), you’ll see that the initial performance of the wells that started in the 3rd quarter last year was especially high, with close to 150 thousand barrels in the first 9 months.   Although not so profitable, associated gas production rose even more, which becomes visible if you change the ‘Product’ selection to ‘Gas’. This is displayed in more depth in the 9th tab (‘Gas oil ratio’), where you can see in the bottom graph that this ratio has risen almost uninterruptedly in the past decade.   As mentioned in my last posts, next week we will be present at the URTeC  in Houston, so if you like to know more about our upcoming analytics services, I’ll be more than happy to show you our vision and give you a demo. We’ll start posting again in the week after.   Production data is subject to revisions.For these presentations, I used data gathered from the following sources: DMR of North Dakota. These presentations only show the production from horizontal wells; a small amount (about 30 kbo/d)  is produced from conventional vertical wells. FracFocus.org Visit our blog to read the full post and use the interactive dashboards to gain more insight https://shaleprofile.com/index.php/2018/07/19/north-dakota-update-through-may-2018   Follow us on Social Media: Twitter: @ShaleProfile
Linkedin: ShaleProfile
Facebook: ShaleProfile

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Eagle Ford – update through March 2018

This interactive presentation contains the latest oil & gas production data through March from 20,615 horizontal wells in the Eagle Ford region (TRRC districts 1-4), that started producing since 2008. Growth is tepid in the Eagle Ford basin, and recent oil output remains well below the high set in March 2015, even after upcoming upward revisions.   Although well productivity has also improved in this basin, as shown in the ‘Well quality’ tab, the effect has been more modest. After normalizing for the increase in lateral length, it almost disappears, despite that the amount of proppants used has doubled over the past 4 years. EOG is the largest oil producer in this area with ~ 250 thousand bo/d operated production capacity (see the ‘Top operators’ tab).   The ‘Advanced Insights’ presentation is displayed below: In this “Ultimate Recovery” overview the relationship between production rates, and cumulative production is revealed. Wells are grouped by the quarter in which production started.   For example, the thick blue curve, representing the 1,024 horizontal wells that started in Q3 2013 peaked on average at a rate of 361 bo/d, and are now just below 24 bo/d, after having recovered 133 thousand barrels of oil and 0.5 Bcf (you can click on this group in the color legend to highlight the related curve). In comparison, the 474 wells that started in Q4 2017 peaked at double the rate. But will they also double the ultimate oil & gas recovery? It’s too early to tell for sure, but noting that the decline behavior has been relatively predictable in the past, it appears they will fall short of that.   Later this week I will have a post on all 10 covered US states, followed by an update on North Dakota. We will be present at the URTeC  in Houston later this month, so if you would like to meet us, or learn more about our upcoming analytics services, I hope to see you there. You can follow me here on Twitter: https://twitter.com/ShaleProfile Production 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 data reports. FracFocus.org   Visit our blog to read the full post and use the interactive dashboards to gain more insight https://shaleprofile.com/index.php/2018/07/09/eagle-ford-update-through-march-2018/   Follow us on Social Media: Twitter: @ShaleProfile
Linkedin: ShaleProfile
Facebook: ShaleProfile

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Eagle Ford - update through December 2018

This interactive presentation contains the latest oil & gas production data from all 22,067 horizontal wells in the Eagle Ford region, that started producing since 2008, through December. Visit ShaleProfile blog to explore the full interactive dashboards December oil production, close to 1.3 million bo/d, barely changed y-o-y. Just over 1,800 new horizontal wells were able to counter the ~45% decline in legacy production in 2018. Gas production hovered last year just below 6 Bcf/d. Initial well performance in the 2 main formations (Eagle Ford & Austin Chalk) was basically unchanged in 2018, as the bottom graph in ‘Well quality’ tab reveals. The over 3,500 horizontal wells that started since 2017 are on a path to recover 150 thousand barrels of oil in the first 2 years on production, on average, in addition to about 0.7 Bcf of natural gas. The leading operator in this basin, EOG, has been increasing output throughout 2018, and exited the year at twice the rate than the number 2, ConocoPhillips (see “Top operators”).   The ‘Advanced Insights’ presentation is displayed below: In this “Ultimate Recovery” overview, the relationship between production rates and cumulative production is revealed. Wells are grouped by the quarter in which production started. You can see here that the bulk of the wells that began production since 2011 are going to recover on average between 150 and 200 thousand barrels of oil, before hitting a production rate of 10 bo/d. This does however also include a significant number of gas wells. Filtering on well type (oil/gas) is a subscriber-only feature. The 4th tab ranks operators by the average cumulative oil production in the first 2 years. Of the larger operators (>100 operated horizontal wells), Devon, ConocoPhillips and Encana are showing the best results according to this metric. If you missed our briefing on all the major tight oil basins on enelyst last Tuesday, you can still read the full update by entering our channel here: ShaleProfile channel on enelyst. Registering is free: enelyst registration page. Early next week we will have a post on all the 11 states that we publicly cover in the US (Oklahoma is currently for subscribers only).   Production 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. FracFocus.org   Visit our blog to read the full post and use the interactive dashboards to gain more insight http://bit.ly/2HZjpQa   Follow us on Social Media: Twitter: @ShaleProfile
Linkedin: ShaleProfile
Facebook: ShaleProfile

North Dakota – update through July 2018

These interactive presentations contains the latest oil & gas production data from all 13,628 horizontal wells in North Dakota through July, that started production since 2005. July oil production in North Dakota came in at 1,269 kbo/d, after a month-on-month rise of 3.4%, setting a new record for the state. Visit ShaleProfile blog to use and explore interactive dashboards   An important factor behind this jump were the 141 new wells that started production, the highest number in 3 years. Completion activity was higher in the first 7 months of this year compared with last year (649 vs 525 wells).   Several operators set new production records, including Continental Resources and ConocoPhillips, which just surpassed Whiting as the 2nd largest producer in this area (see ‘Top operators’).   The ‘Advanced Insights’ presentation is displayed below: This “Ultimate recovery” overview shows how all these horizontal wells are heading towards their ultimate recovery, with wells grouped by the quarter in which production started. It shows that so far the wells that started in Q3 2017 had the best start; after 11 months they recovered on average 169 thousand barrels of oil. Although lateral lengths haven’t changed much in North Dakota, proppant loadings have doubled in the past 4 years, to close to 1,000 lb/ft. In our online analytics service, these trends can be easily analyzed by play and operator. Request a free trial here! Next week I plan to have a new post on the Marcellus.   For these presentations, I used data gathered from the following sources: DMR of North Dakota. These presentations only show the production from horizontal wells; a small amount (about 30 kbo/d)  is produced from conventional vertical wells. FracFocus.org   Visit our blog to read the full post and use the interactive dashboards to gain more insight http://bit.ly/2MIA8oV     Follow us on Social Media: Twitter: @ShaleProfile
Linkedin: ShaleProfile
Facebook: ShaleProfile

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Marcellus (PA) – update through May 2018

This interactive presentation contains the latest gas (and a little oil) production data through April, from all 8,137 horizontal wells in Pennsylvania that started producing since 2010. After the significant jump in output at the end of last year, gas production has remained fairly steady at a level around 16 Bcf/d, and just like in the past 3 years there was a small dip in May. Only 252 horizontal wells started production in Pennsylvania in the first 5 months of this year, which was the lowest number since 2010. The initial performance of these new wells is similar to the ones that started in 2017, which were the best to date (see the bottom graph in the ‘Well quality’ tab).   Cabot has taken over the lead from Chesapeake as the largest gas operator in this area, as you’ll see in the ‘Top operators’ tab. The top 5 operators shown there operate more than half of total unconventional gas production in this state. The ‘Advanced Insights’ presentation is displayed below: This “Ultimate Return” overview shows the relationship between gas production rates, and cumulative gas production, averaged for all horizontal wells that started producing in a certain year. The ~600 wells that started in 2010 have now recovered on average 3.3 Bcf, and are now at a flow rate of 600 Mcf/d. By extrapolating the 2014 curve, you’ll see that these wells are likely to recover about double this number by the time they’ve declined to this flow rate. In the 6th tab (‘Productivity map’), you’ll find which areas in Pennsylvania  are the most productive, as measured by the average cumulative gas production in the first 2 years.   Last week we launched the ShaleProfile Analytics portal at the URTeC, in which the performance of more than 100 thousand horizontal wells in the US can be analyzed in even more detail than here on the blog. This portal also allows you to see the detailed location of all these wells, and analyze how changing lateral lengths and proppant loadings has affected well performance, among many other capabilities. We’ll have soon more information about this on our webpage. If you’re interested you can already find some brief information, and the possibility to request a trial license, in this link. Next week I plan to have new updates on the Permian and the Eagle Ford. Production data is subject to revisions. For this presentation, I used data gathered from the following sources: Pennsylvania Department of Environmental Protection FracFocus.org Visit our blog to read the full post and use the interactive dashboards to gain more insight https://shaleprofile.com/index.php/2018/08/02/marcellus-pa-update-through-may-2018/   Follow us on Social Media: Twitter: @ShaleProfile
Linkedin: ShaleProfile
Facebook: ShaleProfile    

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Marcellus (PA) – update through July 2018

This interactive presentation contains the latest gas (and a little oil) production data, from all 8,298 horizontal wells in Pennsylvania that started producing since 2010, through July. It also contains the production data from Ohio & West Virginia, but as these states have a greater lag in their reporting, only Pennsylvania is preselected in most views.   Visit ShaleProfile blog to explore the full interactive dashboards As you can see, unconventional gas production from horizontal wells set a new record in July, at 16.4 Bcf/d. In June just over 100 wells started production (compared with an average level of ~60 wells per month so far this year), which explains this sudden jump. The cumulative production profiles, shown in the bottom graph of the ‘Well quality’ tab, reveal that well performance improved significantly in 2017, but that it has not made further strides so far in 2018. A typical well recovers 2.7 Bcf in the first 12 months on production now, a level that took more than 4 years for a well that started in 2012.   Of the largest operators in this area, Chesapeake showed the biggest gain in output in July, narrowing the gap with Cabot, which recently took over the lead (see “Top operators”).   The ‘Advanced Insights’ presentation is displayed below: This “Ultimate Return” overview shows the relationship between gas production rates, and cumulative gas production, averaged for all horizontal wells that started producing in a certain quarter. If you click on the wells that started in Q4 2013 (in the color legend), you’ll see that this group of wells has so far recovered most gas, on average, at 4.4 Bcf per well. Declines are low (compared with oil), and I belief that the current level of completions (~ 2 wells per day), can sustain a higher gas production capacity. Later this week I plan to have a new update on the Niobrara, followed by one on the Permian early next week. Production data is subject to revisions. For this presentation, I used data gathered from the following sources: Pennsylvania Department of Environmental Protection FracFocus.org   Visit our blog to read the full post and use the interactive dashboards to gain more insight http://bit.ly/2Q5P0jg     Follow us on Social Media: Twitter: @ShaleProfile
Linkedin: ShaleProfile
Facebook: ShaleProfile  

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Permian – update through April 2018

This interactive presentation contains the latest oil & gas production data through April from all 15,532 horizontal wells in the Permian (Texas & New Mexico) that started producing since 2008/2009. The graph above shows the rapid growth of unconventional oil production from horizontal wells in the Permian where total oil output doubled in the past 2 years. As usual for this region, recent data is incomplete, and I expect that after revisions April production has set another record to over 2.2 million bo/d.   In the “well quality” tab the production profiles for all these  wells can be analyzed. The bottom graph shows that average well performance strongly increased from 2013 to 2016, and has not much changed since then.     The 3 leading operators, Pioneer, Concho and EOG, have more than tripled their operated production in the past 4 years (see the ‘top operators’ overview).   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.   Here you can see that recent wells track quite closely the performance of the wells that started in Q2 2016 (the light green curve), which have in 2 years recovered on average 180 thousand barrels of oil and are now at a production rate of 132 bo/d. The graph in the 5th tab (‘Productivity over time’) displays how well productivity, as measured by the average cumulative production in the first 2 years, has evolved over time. You’ll note that this metric almost tripled from 2013 to 2016, to more than 180 thousand barrels of oil.  The next update will be on the Eagle Ford, followed by a post on all 10 covered states in the US. Within the next week we are launching here our new online analytics service, with which the data and trends for more than 100 thousand horizontal wells in the US can be analyzed in user-friendly dashboards. You can already find a bit of information on the following page for this, where also a trial account can be requested: ShaleProfile Analytics   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   Visit our blog to read the full post and use the interactive dashboards to gain more insight https://shaleprofile.com/index.php/2018/08/07/permian-update-through-april-2018/   Follow us on Social Media: Twitter: @ShaleProfile
Linkedin: ShaleProfile
Facebook: ShaleProfile

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Eagle Ford - update through June 2018

This interactive presentation contains the latest oil & gas production data from all 21,081 horizontal wells in the Eagle Ford region, that started producing since 2008, through June. Visit ShaleProfile blog to explore the full interactive dashboards In the first half of this year, oil production from horizontal wells has hovered just above 1.2 million bo/d, while gas output stood at about 5.8 Bcf per day.   Unlike the Permian, production growth is rather timid in this area. Although the ‘Well quality’ tab shows that well productivity has improved in the last couple of years, the rate of improvement is lower, and EURs are as well. That may be the reason that just ~80 rigs are drilling horizontal wells here, versus more than 400 rigs in the Permian.   The final tab (‘Top operators’) shows that the 2 of the 5 largest operators, EOG & ConocoPhillips are producing at or near their all-time high.   The ‘Advanced Insights’ presentation is displayed below:   In this “Ultimate Recovery” overview the relationship between production rates, and cumulative production is revealed. Wells are grouped by the quarter in which production started. The 538 wells that started production in Q4 2017 are so far showing the best results; they have recovered on average 162 thousand barrels of oil in their first 7 months on production. You can see that many wells (close to 80% of the total) are now below a production rate of 50 bo/d.   The Eagle Ford has also a significant gas window, so the results can be quite different geographically. If you look only at the heart of the play, in Karnes and DeWitt counties, you will find significantly better results. However, here it appears that since 2014 wells are declining steeper than before, despite starting at higher initial rates. This can be seen in the following screenshot from our ShaleProfile Analytics service, in which the production profiles are shown for the wells that started producing between 2014 and 2017: Normalizing for the slight increase in average lateral length over these years (or the far larger increase in proppants per foot), this effect becomes stronger.   Early next week I will have a post on all 10 covered US states. Production 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 data reports. FracFocus.org   Visit our blog to read the full post and use the interactive dashboards to gain more insight http://bit.ly/2QogXTe     Follow us on Social Media: Twitter: @ShaleProfile
Linkedin: ShaleProfile
Facebook: ShaleProfile

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US - update through July 2018

This interactive presentation contains the latest oil & gas production data from 95,093 horizontal wells in 10 US states, through July. Cumulative oil and gas production from these wells reached 9.3 Gbo and 102.9 Tcf. Ohio and West Virginia are deselected in most dashboards, as they have a greater reporting lag. Visit ShaleProfile blog to explore the full interactive dashboards Oil and gas production from horizontal wells kept setting new records through the first 7 months of this year. The 5,600 new producers contributed ~2.2 million bo/d and 10.4 Bcf/d in July, versus 4,600 new producers in the same period last year (which contributed 1.6 million bo/d and 9.1 Bcf/d in July last year).   The steady increases in well productivity between 2012 and 2017 are clearly visible in the 2nd tab, ‘Well quality’, where the oily basins have been preselected. Almost 12 thousand wells were completed in these plays in 2014, more than in any other year, which is why this curve is drawn with the greatest thickness. The final tab shows the production and location of the wells operated by the largest operators, as measured by their cumulative production in the past decade. The ‘Advanced Insights’ presentation is displayed below: This “Ultimate recovery” overview shows the relationship between production rates and cumulative production over time. The oil basins are preselected, and wells are grouped by the year in which production started. You can see in the graph above that the 7,600 wells that started in 2017 recovered on average almost 100 thousand barrels of oil in the first 8 months on production, while declining from 600 bo/d to 274 bo/d. More recent and granular data can be seen by grouping the wells by the quarter or month in which production started.   The 2nd tab, ‘Cumulative production ranking’, ranks all counties with horizontal production based on cumulative oil production. McKenzie and Mountrail counties, both in North Dakota, are in the lead, but Karnes (Eagle Ford) and Weld (Niobrara) are catching up on the number 2. Early next week I will have a new post on North Dakota, which will soon release September production data. In our ShaleProfile Analytics service we keep all data up-to-date on a daily basis, and for most states we already have August or even September production in. If you’re interested, you can request a demo or trial here. Production data is subject to revisions. For these presentations, I used data gathered from the sources listed below. FracFocus.org Colorado Oil & Gas Conservation Commission Louisiana Department of Natural Resources. Similar as in Texas, lease/unit production is allocated over wells in order to estimate their individual production histories. Montana Board of Oil and Gas New Mexico Oil Conservation Commission North Dakota Department of Natural Resources Ohio Department of Natural Resources Pennsylvania Department of Environmental Protection Texas Railroad Commission. Individual well production is estimated through the allocation of lease production data over the wells in a lease, and from pending lease production data. West Virginia Department of Environmental Protection West Virginia Geological & Economical Survey Wyoming Oil & Gas Conservation Commission   Visit our blog to read the full post and use the interactive dashboards to gain more insight http://bit.ly/2DBiiE9     Follow us on Social Media: Twitter: @ShaleProfile
Linkedin: ShaleProfile
Facebook: ShaleProfile

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Marcellus (PA) – update through April 2019

This interactive presentation contains the latest gas (and a little oil) production data, from all 8,915 horizontal wells in Pennsylvania that started producing from 2010 onward, through April. Visit ShaleProfile blog to explore the full interactive dashboards With March revisions in, it has become clear that another record was set, at 18.4 Bcf/d. April natural gas production was at a similar level. New wells recover on average more than 4 Bcf of gas in the first 2 years on production (‘Well quality’ tab). It took each of the ~1,300 horizontal wells, that began production in 2013, more than 5 years to reach that level. The top 4 natural gas producers in Pennsylvania all set new output records this year (‘Top operators’). We still list EQT and Rice Drilling as 2 separate entities. The ‘Advanced Insights’ presentation is displayed below:   This “Ultimate Return” overview shows the relationship between gas production rates and cumulative gas production, averaged for all horizontal wells that began production in a certain quarter. Improvements in initial well productivity have not yet stalled; the 195 wells that started production in Q4 last year had so far the best start, recovering 1.7 Bcf in the first 5 months, on average. You can also find here that many wells from the 2010 vintage have now declined to below 500 Mcf/d, while recovering about 3.2 Bcf. The wells from the 2017/2018 vintages are on a trajectory to triple that number, on average.   Tomorrow, Tuesday July 2nd at noon (ET), we will present a 20 minute briefing on all the major tight gas basins in the US, in our ShaleProfile channel on enelyst. Registering is free: enelyst registration page.   Later this week we will have a post on the Permian, and next week on the Eagle Ford. The latest Texas data is already available in our online analytics service. For just $52 per month, you can already always access the latest production data with the Analyst version of ShaleProfile Analytics. This is a monthly subscription service that you can cancel at any time.   Production data is subject to revisions. For this presentation, I used data gathered from the following sources: Pennsylvania Department of Environmental Protection FracFocus.org     Visit our blog to read the full post and use the interactive dashboards to gain more insight http://bit.ly/2XkuPpP   Follow us on Social Media: Twitter: @ShaleProfile
Linkedin: ShaleProfile
Facebook: ShaleProfile

Marcellus (PA) – update through June 2018

This interactive presentation contains the latest gas (and a little oil) production data through June, from all 8,236 horizontal wells in Pennsylvania that started producing since 2010. Gas production from these wells has hovered around a level of 16 Bcf/d in the first half of 2018. During this period, 351 horizontal wells started production versus 299 in the year before.   In the ‘Well quality’ tab, the production profiles of all these wells can be found, averaged by the year in which they started. If you group them by county instead (using the ‘Show wells by’ selection), you will see in the bottom graph that wells in 3 counties in the north east of Pennsylvania have the best average performance: Wyoming, Susquehanna and Sullivan.   The final tab (‘Top operators’) shows the output and location of the 5 leading operators in this area; Chesapeake, Cabot, Range Resources, EQT and Southwestern Energy. It also reveals that Chesapeake appears to follow a strategy to ramp up gas production before each winter, before letting it decline again.   The ‘Advanced Insights’ presentation is displayed below: This “Ultimate Return” overview shows the relationship between gas production rates, and cumulative gas production, averaged for all horizontal wells that started producing in a certain quarter. It shows that well productivity has steadily risen over time, and that there was a significant jump in performance in Q4 2016. Since then, the improvements have leveled off.   Later this week I plan to have a new update on the Permian, followed by one on the Eagle Ford early next week. Production data is subject to revisions. For this presentation, I used data gathered from the following sources: Pennsylvania Department of Environmental Protection FracFocus.org Visit our blog to read the full post and use the interactive dashboards to gain more insight http://bit.ly/2NmJ44d     Follow us on Social Media: Twitter: @ShaleProfile
Linkedin: ShaleProfile
Facebook: ShaleProfile

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Permian – update through January 2019

These interactive presentations contain the latest oil & gas production data from all 20,021 horizontal wells in the Permian (Texas & New Mexico) that started producing since 2008/2009, through January 2019. Visit ShaleProfile blog to explore the full interactive dashboards The chart above shows the massive growth in Permian production, as well as the underlying decline. Preliminary oil production for January came in at 3.1 million bo/d, which after revisions will be closer to 3.5 million bo/d. That means that all the wells that started before 2018 only contributed 1/3rd of total production in January. Natural gas production, most of it associated with the production of oil, has also risen strongly. It is now well over 10 Bcf/d, placing the Permian above the Haynesville and the Utica, both in absolute numbers, and production growth. 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. Although activity has steeply increased, there has not been a negative impact on well performance so far. The ~5 thousand horizontal wells that started in 2018 peaked at a rate of 730 bo/d, more than 100 bo/d higher than the wells that began in the previous year. Still, after the rapid improvements in performance in the years up to 2016, a slowdown is apparent. The final tab gives an overview of the 5 largest operators. Pioneer Natural Resources and Concho are now both above 250 thousand bo/d. Occidental and Anadarko are also in this list. Occidental recently made a higher bid than Chevron in the scramble for Anadarko’s assets. 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 year in which production started. This chart also illustrates the steadily increasing well performance in the Permian, as the curves are trending to gradually higher recoveries. The 2,247 horizontal wells that began in 2016, represented by the light brown curve, recovered 182 thousand barrels of oil in their first 2 years on production. They are on a trajectory to recover close to 400,000 barrels of oil, before they decline to a level of 20 bo/d. Early next week we will have a post on all covered states in the US. 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 Visit our blog to read the full post and use the interactive dashboards to gain more insight http://bit.ly/2VpW5Cm Follow us on Social Media: Twitter: @ShaleProfile
Linkedin: ShaleProfile
Facebook: ShaleProfile

North Dakota – update through June 2018

This interactive presentation contains the latest oil & gas production data through June from all 13,628 horizontal wells in North Dakota that started production since 2005. June oil production in North Dakota came in at 1,246 kbo/d, after a month-on-month drop of ~1.5%. As shown in the below graph, wells that started production since 2017 contributed about half of total oil production in June.   If you switch to gas, you’ll see that natural gas production has risen strongly in North Dakota in the past 1.5 years.   In the ‘Well status’ overview the historical status of all these wells can be seen. The bottom graph there shows that in June just over 1,200 horizontal wells (9% of total) produced more than 200 bo/d, which was good for more than half of total oil production. About 60% of the wells are now at a rate below 50 bo/d.   Of the leading operators, only ConocoPhillips set a new record in June, at just below 100 thousand barrels of oil per day. Continental Resources, although still in the lead, has not drilled many additional wells in the past 1.5 years, and has now depleted its DUC count by half since March last year.   The ‘Advanced Insights’ presentation is displayed below: This “Ultimate recovery” overview shows how all these horizontal wells are heading towards their ultimate recovery, with wells grouped by the quarter in which production started. Here you can see that on average initial well performance has improved since 2015. However, you can now also find areas where it has actually fallen.   An interesting case is Oasis. If you select only this operator (in the ‘Operator’ selection), you can see that the shape of the decline has changed radically for recent wells; although they started at a high initial flow rate, after about 8 months on production the decline is steeper than seen before. It may well be that these wells will eventually recover less oil than many of its earlier wells.   Next week I plan to have a post on the Marcellus, followed by one on the Permian. If you want to have always access to the latest data for all states, please consider our online analytics service, which was just launched. Besides being able to see all the individual horizontal wells, it also allows you to analyze trends in lateral lengths and proppant loadings. You can find more information, including the possibility to request a free trial, here on our products page. For these presentations, I used data gathered from the following sources: DMR of North Dakota. These presentations only show the production from horizontal wells; a small amount (about 30 kbo/d)  is produced from conventional vertical wells. FracFocus.org Visit our blog to read the full post and use the interactive dashboards to gain more insight http://bit.ly/2Lo3ckL     Follow us on Social Media: Twitter: @ShaleProfile
Linkedin: ShaleProfile
Facebook: ShaleProfile  

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Niobrara (CO & WY) - update through May 2018

This interactive presentation contains the latest oil & gas production data through May, from all 7,962 horizontal wells that started production in the Niobrara region (Colorado & Wyoming) since 2009/2010. As shown in the graph below, 2017 was a similarly strong year for oil production growth as 2013, with more than 150 thousand bo/d added. Since end of last year, production from unconventional horizontal wells has remained just below half a million bo/d. In May about 70% of total oil production came from wells that started since the beginning of 2017. Gas production has now reached a level of 2.5 Bcf/d (set ‘Product’ to ‘gas’).   Completion activity is still a bit behind the record levels seen at the end of 2014, with ~120 wells per month added (vs. ~160 in the 2nd half of 2014). A big factor behind the recent output levels is then also improved well productivity, as shown in the ‘Well quality’ tab. Wells that started in 2017 performed better than earlier wells; on average they reached the 100 thousand barrel mark within the first year of production, while this took at least 1.5 years for earlier vintages.   Anadarko and Noble Energy are the largest operators in this region (see “Top operators”), but Extraction Oil & Gas is catching up rapidly.   The ‘Advanced Insights’ presentation is displayed below: In this “Ultimate Recovery” graph, the average cumulative production of all these horizontal wells is plotted against the production rate. Wells are grouped by the quarter in which production started.   The jump in performance since Q4 2016 is clearly visible here. Since then however no further improvement is seen. If you group the wells by month, to see more recent and granular data, you’ll note that the best performance so far is shown by wells that started in Dec 2016. Many of the wells here are already at or close to stripper well status. Wells that started before 2014 are producing now on average at a level of 15 bo/d or lower. More dashboards, with other types of data (completion sizes, lateral lengths, etc) and more up-to-date data are available in our online analytics tool, for which you can request a free trial. We just started a YouTube channel in which we are sharing some movies on how you could perform particular analyses using this new tool: ShaleProfile Analytics on YouTube The following is a screenshot from a dashboard that shows a map with the gas-oil ratio (GOR) of all wells in the heart of the DJ-Niobrara basin, in their most recent month. On the right side you can see their ultimate recovery curves, with the related GOR plotted below. Also in this basin you can find areas where the GOR is rising faster for more recent wells, and that this is negatively impacting long-term recovery rates (not shown here below). [right-click and view/download to see a higher resolution version] Early next week I have an update on all 10 covered states in the US. Production data is subject to revisions. For this presentation, I used data gathered from the following sources: Colorado Oil & Gas Conservation Commission Wyoming Oil & Gas Conservation Commission FracFocus.org   Visit our blog to read the full post and use the interactive dashboards to gain more insight http://bit.ly/2x25WQp     Follow us on Social Media: Twitter: @ShaleProfile
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Eagle Ford - update through May 2018

This interactive presentation contains the latest oil & gas production data through May from 20,900 horizontal wells in the Eagle Ford region, that started producing since 2008. In the first 5 months of this year, oil production from these wells has hovered around a level of 1.2 million barrels of oil per day. This was a few percent above the output 12 months earlier, but lower than the level reached in Q4 last year.   Although well performance has also steadily shown improvements here over the past years, most of it has come from better initial (<12 months) productivity, as shown in the ‘Well quality’ tab. The 1,602 wells that started producing in 2012, in the Eagle Ford or Austin Chalk formations, peaked at ~300 bo/d, while the 1,687 wells that started 5 years later did so at more than double this rate. Completion activity is still well below the peak in 2014 (~150 wells/month in 2018, vs. over 350 wells/month in 2014).   The ‘Advanced Insights’ presentation is displayed below: In this “Ultimate Recovery” overview the relationship between production rates, and cumulative production is revealed. Wells are grouped by the year in which production started.   If you select only the Austin Chalk formation (using the ‘Formation’ selection), you’ll see that this formation is receiving more attention recently, with almost 100 wells completed in 2017, and that since 2016 their performance is better than comparable Eagle Ford wells.   Later this week I will have a new post on the Niobrara region. We just added a new dashboard in our ShaleProfile Analytics service, with which it is easy to see the gas/oil ratio across a basin, how this ratio has changed over time, and whether it has affected well productivity. See here a screenshot for this dashboard with the Eagle Ford selected (click and view or download to see the high-resolution version):   Production 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 data reports. FracFocus.org   Visit our blog to read the full post and use the interactive dashboards to gain more insight http://bit.ly/2NcikGU     Follow us on Social Media: Twitter: @ShaleProfile
Linkedin: ShaleProfile
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US - update through April 2018

This interactive presentation contains the latest oil & gas production data through April, from 90,168 horizontal wells in 10 US states. Cumulative oil and gas production from these wells reached 8.7 Gbo and 96.7 Tcf. The number of well completions in the 2nd half of 2017 was about 60% higher than the average level in 2016, which explains most of the rise in output over the past year. Average initial well productivity in the oily basins did not change much over this period, as shown in the ‘Well quality’ tab.   EOG, with an operated production capacity of almost half a million bo/d, is the largest shale oil producer in the US (see the ‘Top operators’ overview).   The ‘Advanced Insights’ presentation is displayed below: This “Ultimate recovery” overview shows the relationship between cumulative production, and production rates, over time. Also here the oil basins are preselected, and wells are grouped by the year in which production started.   By changing the ‘Show wells by’ selection to ‘Quarter of first flow’, you’ll see more recent and granular data. It also reveals that since Q4 2016, the average production profile hasn’t changed as much as before, as noted before. The 1,323 horizontal wells that started in Q4 2016 have recovered each on average just over 140 thousand barrels of oil through April, and declined to a production rate of 140 bo/d.   Later this week I will have a new post on North Dakota, which just released June production. Production data is subject to revisions. For these presentations, I used data gathered from the sources listed below. FracFocus.org Colorado Oil & Gas Conservation Commission Louisiana Department of Natural Resources. Similar as in Texas, lease/unit production is allocated over wells in order to estimate their individual production histories. Montana Board of Oil and Gas New Mexico Oil Conservation Commission North Dakota Department of Natural Resources Ohio Department of Natural Resources Pennsylvania Department of Environmental Protection Texas Railroad Commission. Individual well production is estimated through the allocation of lease production data over the wells in a lease, and from pending lease production data. West Virginia Department of Environmental Protection West Virginia Geological & Economical Survey Wyoming Oil & Gas Conservation Commission   Visit our blog to read the full post and use the interactive dashboards to gain more insight http://bit.ly/2ORa9Nn   Follow us on Social Media: Twitter: @ShaleProfile
Linkedin: ShaleProfile
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Eagle Ford - update through April 2018

This interactive presentation contains the latest oil & gas production data through April from 20,207 horizontal wells in the Eagle Ford region, that started producing since 2008. Despite significant future upwards production revisions, which are typical for Texas, it appears that total oil and gas production has declined in the Eagle Ford since December.   It also appears that the wells that started producing in 2018 are so far closely tracking the performance of wells from last year (see the ‘Well quality’ tab). However, on closer inspection (by selecting to show wells by ‘Quarter of first flow’), you can see that there were some minor improvements since the 2nd half of 2017.   All leading operators have been unable to grow production here since early 2015, although EOG is close to its previous high (‘Top operators’ tab). Devon Energy shows the largest decline among them, with a ~60% drop.   The ‘Advanced Insights’ presentation is displayed below: In this “Ultimate Recovery” overview the relationship between production rates, and cumulative production is revealed. Wells are grouped by the year in which production started.   For example, the 1,850 horizontal wells that started in 2011 (represented by the red curve) are now at an average rate of 15 bo/d, after having recovered 130 thousand barrels of oil and 0.8 Bcf (switch ‘Product’ to gas to see this).   Based on average cumulative production in the first 2 years, Devon Energy is still showing the best results (at 220 thousand bo/d) of the operators with at least 100 wells, while EOG is the number 5 (‘Productivity ranking’ dashboard). Later this week I will have a post on all 10 covered US states, followed by an update on North Dakota early next week. As you will have noticed, we have performed a major upgrade of our website. Besides this free blog, we now offer two services with which the developments in the shale oil & gas industry can be closely monitored: ShaleProfile Analytics, an online portal with similar user-friendly dashboards as shown here on the blog, but with new dashboards, and access to more up-to-date data, such as lateral positions, proppant loadings, and lateral lengths. You can request here a free trial. ShaleProfile Data, where you can subscribe to our underlying data platform, and receive monthly updates with the latest data. You can bookmark https://shaleprofile.com/blog/ , if you wish to get quick access to the latest blog posting here. Please tell me what you like and especially don’t like about this new setup! Production 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 data reports. FracFocus.org   Visit our blog to read the full post and use the interactive dashboards to gain more insight https://shaleprofile.com/2018/08/14/eagle-ford-update-through-april-2018/   Follow us on Social Media: Twitter: @ShaleProfile
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US - update through May 2018

This interactive presentation contains the latest oil & gas production data through May, from 91,810 horizontal wells in 10 US states. Cumulative oil and gas production from these wells reached 8.9 Gbo and 98.6 Tcf. Their total oil production was close to 5.5 million bo/d in May, or more than half of total US oil supply, while gas production topped 50 Bcf/d.   If you group this total oil production by ‘production level’, using the ‘Show production by’ selection, you will find that in May ~4 million bo/d came from just ~12 thousand wells that each produced over 100 bo/d. All other wells combined (~80k) produced just the remaining 1.5 million bo/d, although that also includes gas wells.   The ‘Well status’ tab shows the status of all these wells over time. Looking at the ‘First flow’ status, or wells that have just started production, reveals that since the 2nd half of 2017 between 800 and 1,000 new horizontal wells were brought into production each month (taking into account upcoming revisions), versus less than 600 in 2016.   The ‘Advanced Insights’ presentation is displayed below: This “Ultimate recovery” overview shows the relationship between cumulative production, and production rates, over time. The oil basins are preselected, and wells are grouped by the year in which production started. As the curves show, well productivity improved each year since 2012. The ~5.3 thousand horizontal wells that started in 2016 recovered each on average 134 thousand barrels of oil in the first 18 months, and they are on a trajectory to recover one more time that amount, before declining to level of ~20 bo/d.   Early next week I will have a new post on North Dakota. We are still handing out free trial accounts for our ShaleProfile Analytics service, which covers more dashboards and up-to-date data. If you’re interested, you can apply for a trial here. Production data is subject to revisions. For these presentations, I used data gathered from the sources listed below. FracFocus.org Colorado Oil & Gas Conservation Commission Louisiana Department of Natural Resources. Similar as in Texas, lease/unit production is allocated over wells in order to estimate their individual production histories. Montana Board of Oil and Gas New Mexico Oil Conservation Commission North Dakota Department of Natural Resources Ohio Department of Natural Resources Pennsylvania Department of Environmental Protection Texas Railroad Commission. Individual well production is estimated through the allocation of lease production data over the wells in a lease, and from pending lease production data. West Virginia Department of Environmental Protection West Virginia Geological & Economical Survey Wyoming Oil & Gas Conservation Commission   Visit our blog to read the full post and use the interactive dashboards to gain more insight http://bit.ly/2CJiam9     Follow us on Social Media: Twitter: @ShaleProfile
Linkedin: ShaleProfile
Facebook: ShaleProfile

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Niobrara (CO & WY) - update through July 2018

This interactive presentation contains the latest oil & gas production data through July, from all 8,221 horizontal wells that started production in the Niobrara region (Colorado & Wyoming) since 2009/2010. Although we had a post on this region just 3 weeks ago, as we now have reliable data up through July, I wanted to share another update. A few percent of the wells were not yet reported in July, so there will be some upward revisions.   Visit ShaleProfile blog to explore the full interactive dashboards Total oil production from horizontal wells in these 2 states increased by about 50% since early 2017, to close to half a million barrels of oil per day. In July, the wells that started in this period (>= 2017) contributed around 75% to this production. Completion activity is still a bit behind the record levels seen at the end of 2014, with ~120 wells per month added (vs. ~160 in the 2nd half of 2014).   In the “Well quality” tab we can see that the wells that started in 2017 clearly outperformed any earlier wells, on average. The ones that started in 2018 appear to be slightly behind in terms of initial performance.   Anadarko, the leading operator here with close to 20% of total oil output, was above 100 thousand barrels of oil per day of gross production again in July, as the last tab shows. The average gas oil ratio for its wells in Weld County is rising rapidly (>40% in the past 3 years), and there are some signs that this is impacting long-term recovery potential. As shown also in my previous update on North Dakota, we recently added a new dashboard in our analytics tool (for which you can request a trial here), in which these trends can be analyzed in all detail.   The ‘Advanced Insights’ presentation is displayed below: In this “Ultimate Recovery” graph, the average cumulative production of all these horizontal wells is plotted against the production rate. Wells are grouped by the quarter in which production started. Although average well productivity in general increased until early 2017, this plot shows that since then it appears to have fallen slightly. Recent wells may on average fall just short of recovering 140 thousand barrels of oil, before becoming stripper wells (< 15 bo/d).   In the ‘Productivity ranking’ overview, operators are ranked according to the average cumulative oil production in the first 2 years. Of the large operators (>100 operated wells), EOG has the best performance with 125 thousand barrels for this metric. If you click on its result, you will see in the map below that most of its wells are located in Campbell County (WY).   Next week we will have updates on both the Permian and the Eagle Ford. Production data is subject to revisions. For this presentation, I used data gathered from the following sources: Colorado Oil & Gas Conservation Commission Wyoming Oil & Gas Conservation Commission FracFocus.org   Visit our blog to read the full post and use the interactive dashboards to gain more insight http://bit.ly/2QdcmDv     Follow us on Social Media: Twitter: @ShaleProfile
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Permian – update through March 2019

These interactive presentations contain the latest oil & gas production data from all 21,384 horizontal wells in the Permian (Texas & New Mexico) that started producing since 2008/2009, through March 2019. Visit ShaleProfile blog to explore the full interactive dashboards Oil production from horizontal wells in the Permian set another record in March, at over 3.2 million bo/d, even before upward revisions. As the blue areas indicate, in March more than 2/3rd of total production came from wells that began production since 2018. Gas production also set a new record at close to 11 Bcf/d (switch “Product” to gas), although not all of it is wanted due to sometimes negative pricing. As the “Well quality” tab reveals, initial performance has increased since 2016, but nowhere near the gains seen in the 2013-2016 time frame. This also doesn’t take into account that laterals kept increasing, as did proppant loadings. The biggest change was in the number of well completions; in 2018, on average more than 400 horizontal wells came online each month, versus less than 200 in 2016. The final dashboard, “Top operators”, displays the production history of the 5 largest operators. They all set new output records in 2019. 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 year in which production started. The 2,254 horizontal wells that started production in 2016 have so far recovered the most oil, on average: 200 thousand barrels of oil. They are still producing at an average rate just north of 100 bo/d, and they may recover another 200 thousand barrels before they are down to 20 bo/d (extrapolate the curve to arrive at roughly this number). The following screenshot (from our advanced analytics service) shows how initial well productivity has evolved in the 6 top-producing counties in the Permian.   Click on the image to see a high-res version of it. The graph shows the average oil recovery in the first year on production, by county and production start date. Increases in lateral length and proppant use greatly boosted initial productivity in the past 6 years. The best well performance is now seen in Midland and Lea. Interestingly, performance dropped somewhat in Reeves County in the last year. The WSJ recently published 2 articles about the Permian, for which they also found use in our analytics service (behind paywall): A Leader of America’s Fracking Boom Has Second Thoughts (last week) A Fracking Experiment Fails to Pump as Predicted (today)   Later this month, we will be at the URTeC in Denver, from July 22nd until the 24th. Drop by our booth, #951, if you are in the area, for a chat and a personalized demo! Early next week we will have a post on the Eagle Ford, followed by an update on all covered states in the US.   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   Visit our blog to read the full post and use the interactive dashboards to gain more insight http://bit.ly/2XsKCCQ   Follow us on Social Media: Twitter: @ShaleProfile
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