WTI Crude

Loading...

Brent Crude

Loading...

Natural Gas

Loading...

Gasoline

Loading...

Heating Oil

Loading...

Rotate device for more commodity prices

Peter Tertzakian

Peter Tertzakian

Peter Tertzakian is Chief Energy Economist and Managing Director at ARC Financial Corp., Canada’s largest energy-focused private equity firm. His career began as a geophysicist…

More Info

Is The Oil Production Efficiency Boom Coming To An End?

Roughneck at work

“How much more productive can these new wells get?” I asked my host who had kindly invited me on a field trip to some of western Canada’s most prolific oil fields.

Looking down the aisle of bobbing pump jacks, seven in a row on one side of the immaculate gravel pad, the veteran oil executive replied, “We can get up to 1,000 barrels a day out of some of the new ones, but that’s not a limit; we’re improving the economics and productivity with each new well.”

Impressive I thought, subconsciously nodding my head in sync with the leading pump jack.

“Back when I was in field exploration,” I said sounding like a grey-haired guy, “we used to high-five if a new well put out 100 barrels a day.”

The stats certainly show that the industry’s ability to pull oil out of the ground from parts of North America has recently improved by an order of magnitude. In other words, ‘rig productivity’ – the amount of new oil production that an average rig can bring on in one month of drilling– has increased 10-fold in the last 6 years.

Both of us stood marvelling at the operation in front of us, tacitly thinking the same questions. What are the limits to this remarkable energy megatrend: 1,000? 2,000? 5,000 barrels per day per well?

“All this appears amazing,” I said, “like some sort of Moore’s Law for guys in hard hats and overalls.”

Moore’s Law – the observation that the number of transistors on a computer chip doubles about every two years – is the gold standard for benchmarking innovation. But at the same time I explained to my host that I’m always cautious about being duped by exuberant technology, trends and numbers. For example, we’ve all subscribed to “high-speed” Internet services that claim dozens of Megabits per second, but grinds to a fraction of the advertised rate when half the neighborhood is binge-watching Netflix. “The notion of ‘rig productivity’ has to be taken with caution,” I noted. “We can’t assume that the best posted performance in the field is the norm for all wells.” Related: How Storage Could Transform The U.S. Power Grid

My thoughts turn to the US Energy Information Agency (EIA), which every month publishes a report on rig productivity.

July data from the Eagle Ford play in Texas – one of the most prolific in North America – shows that rig productivity in the area is now over 1,000 B/d per rig, similar to the Canadian play area I’m visiting. The rate of innovation has been impressive; between 2007 and 2014, when oil prices were above $100/B, rig productivity was increasing by 110 B/d per rig, every year.

(Click to enlarge)

But a curious thing is noticeable at the end of 2014: Rig productivity suddenly kicked up in all the US plays. The Eagle Ford was particularly impressive, going from 550 to 1,100 B/d per rig. I did a double take. Really? A doubling every 18 months? That’s better than Moore’s law! Related: Iran Undecided On Joining OPEC’s Production Meeting

The well pad I’m standing on is a testament to ongoing innovation, but there is a statistical distortion at play. Starting in late 2014, the severe downturn in oil prices forced the industry to park three-quarters of their rigs and “high-grade” their inventory of prospects. Producers focused on only their best rocks, drilling with only the most efficient rigs. All the low productivity stuff was culled out of the statistical sampling, skewing the average productivity numbers much higher.

(Click to enlarge)

It’s only an estimate, but the average productivity in the Eagle Ford using a wider spectrum of rocks is probably at least 30% less, in the 700 B/d per rig range. Higher oil prices are needed to attract rigs to those lesser quality locations. The much-vaunted Permian only averages about 350, despite showing 500 B/d per rig in the EIA data.

But top-end numbers like 700 B/d per rig should still be a cold-shower wake up call to high-cost oil companies, or to the champions of rival energy systems trying to supplant oil. Notwithstanding the high-grading of the rig sample to premium “sweet spots”, the average productivity in the best North American plays is still improving by about 100 B/d per rig per year, with several years of running room left. It’s not exponential like Moore’s Law, but the pace of innovation is on par with many trends in the tech world.

“We’ve got some of the best acreage and best practices in Western Canada,” said the CEO, looking into the distance and panning his hand across the company’s leased land.

“Yeah, it’s amazing, by the numbers you’re as good as or better than some of the best in North America,” I replied. “But ‘best’ also reminds me to consider that other areas are not as good.”

By Peter Tertzakian for Oilprice.com

More Top Reads From Oilprice.com:




Back to homepage


Leave a comment
  • DannyB on August 18 2016 said:
    Easy to keep squeezing those extra barrels out when your service companies are running at a loss just to hang onto to a rig or two and stay alive until better times.

    These production gains are not economically viable in the long term.
  • Lee James on August 18 2016 said:
    I see a lot of techno-hope expressed in this article. Volume hydraulic fracturing was in its infancy 6 years ago -- you'd expect the technology to mature. At the same time, we continue to add up the overhead cost of this technology on clean air and water. We do not currently pay all fracturing related costs in the present day.

    Another thing to track in the article is the timing of measured rig output. Initial production is quite high, but it tapers off rapidly.
  • Lee James on August 18 2016 said:
    I see a lot of techno-hope expressed in this article. Volume hydraulic fracturing was in its infancy 6 years ago -- you'd expect the technology to mature. At the same time, we continue to add up the overhead cost of this technology on clean air and water. We do not currently pay all fracturing related costs in the present day.

    Another thing to track in the article is the timing of measured rig output. Initial production is quite high, but it tapers off rapidly.
  • Bob on August 18 2016 said:
    While there certainly has been technological advances in finding and delivering oil, it's not clear if efficiency is the right term that describes the gains.

    It seems that much of the recent gains relate to concentrating on the easiest finds with simply more effort.

    Effort like pumping more fracking fluid at higher pressures, closer and closer rig spacing, more and longer lateral wells from rig pads. Is more oil from more effort actually that much greater efficiency?

Leave a comment




Oilprice - The No. 1 Source for Oil & Energy News