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Digital Oil & Gas Solutions We provide low-cost, remote monitoring and control of oil and gas assets.

Focusing on the needs of our customers, we leverage the power of cloud computing, AI, machine learning and field data capture technology for solutions fit for your business model.

At what point does a well become too expensive to watch? Nobody actually adds this up. Here's a version you can use: Ann...
10/20/2026

At what point does a well become too expensive to watch?

Nobody actually adds this up. Here's a version you can use:

Annual monitoring cost =

- All the visits per year
- Labor + vehicle fuel per visit
- Admin/data-entry time
- Cost of missed issues

Then compare that number to the well's annual margin.

If monitoring costs more than the well earns, that's not a maintenance problem.

That's an economic problem.

With AI being implemented everywhere, the real question is: "Will this well pay me back?" Almost any asset can be automa...
10/15/2026

With AI being implemented everywhere, the real question is: "Will this well pay me back?"

Almost any asset can be automated. Not all of them should be, or at least not yet.

That's an economic question, and it has to be answered asset by asset, not fleet-wide.

Swipe through the variables that actually decide the answer →

Which of your wells would actually pay this back?

Exxon just automated its rig floor in the Permian. Robotic arms, fewer people near heavy equipment, and drilling records...
10/13/2026

Exxon just automated its rig floor in the Permian.

Robotic arms, fewer people near heavy equipment, and drilling records broken along the way.

Most operators will never build anything close to that.

And the reality is that they don't need to.

Automation requires one task that meets a few conditions:

→ It happens on a fixed schedule, whether anything has changed or not
→ The reading is stable more often than not
→ Visits cost more than the information is worth

A manual gauge check usually meets all three. A judgment call about why a well is behaving strangely usually doesn't.

That's the goal: to optimize operational cost and your team’s time.

Most operators don't think of monitoring as having "levels." It's either working or it isn't. But there's a real progres...
09/16/2026

Most operators don't think of monitoring as having "levels." It's either working or it isn't.

But there's a real progression, from driving out to check an asset to systems that can predict a failure before it happens.

The wide majority of marginal wells in the industry are still stuck in the earliest stages of asset monitoring, mainly because moving up has historically meant expensive overhauls that don't make sense for low-producing assets.

But we know firsthand that small to medium operators don't need fancy tech to improve their operations. Only the right tools.

The U.S. just became the world's #1 oil exporter, pumping a record 5.4 million barrels of crude per day. That's a massi...
09/10/2026

The U.S. just became the world's #1 oil exporter, pumping a record 5.4 million barrels of crude per day.

That's a massive opportunity, but it's also a massive operational test.

When global demand is this high, every hour of downtime and every inefficient well becomes more expensive. The operators capturing this moment are the ones with real-time visibility into their operations, not the ones simply producing more and hoping the math works out.

Swipe through to see what's driving this shift, and what it means for production efficiency going forward →

In 2019, it took manufacturers an average of 49 minutes to get production back online after unplanned downtime. By 2024,...
09/08/2026

In 2019, it took manufacturers an average of 49 minutes to get production back online after unplanned downtime. By 2024, that number had grown to 81 minutes.

That's what happens when monitoring only catches the obvious problems.

Partial visibility, a sensor here, a manual check there, was enough when failures were simple and predictable. But the easy problems have mostly been solved. What's left are the harder ones:

The ones that hide in the gaps between checkpoints

Or the ones that don't show up until something has already gone wrong

Every blind spot in your monitoring setup is a recurring cost waiting to happen. Not because operators aren't paying attention, but because partial monitoring was never designed to catch what falls between the gaps.

Comprehensive, real-time visibility is the baseline operators need to keep pace with assets that don't leave room for guesswork.

Do you know where your blind spots are?

Source: Siemens, The True Cost of Downtime 2024

Hurricane season opened with Tropical Storm Arthur making landfall near the Texas coast. There are three remaining month...
09/04/2026

Hurricane season opened with Tropical Storm Arthur making landfall near the Texas coast.

There are three remaining months of extreme heat, storm activity, and the kind of equipment stress that doesn't show up on a basic alarm until something has already failed.

The Gulf of America alone accounts for 13% of all U.S. crude oil production. When a major storm moves through, operators don't just lose a day of output — they lose visibility into what the storm did to their assets while no one was watching.

Heat degrades fluid viscosity. Storms leave hidden damage. And the wells that looked fine on the last site visit may not be fine anymore.

Continuous monitoring doesn't eliminate extreme weather, but it does eliminate the blind spot that comes after it.

Swipe through to see what hurricane season actually does to upstream operations and what operators can do about it →

"Success isn't about flashy tech. It's about safer operations, higher staff productivity, more consistent production, an...
09/02/2026

"Success isn't about flashy tech. It's about safer operations, higher staff productivity, more consistent production, and improved asset reliability that keeps wells economic for years longer."

That's how Billy Barbier, Director of Operations at Digital Oil & Gas Solutions, thinks about deployments.

Not dashboards. Not buzzwords. Just whether an asset is better off than it was before.

He's seen that philosophy play out firsthand. On a recent deployment with a Texas operator managing about 40 low-producing wells, the team had budgeted for ROI in 12 to 18 months. Well Manager delivered a 3:1 return in under 6 months.

"We measure success the same way operators do, through hard dollars and sustained performance, not just dashboard metrics."

What made the difference was starting with a focused pilot, getting data quality right from day one, and putting AI-driven alerts to work immediately, catching three potential tank spill events in the first quarter alone.

That's the kind of result that doesn't show up in a sales deck. It shows up in the field.

Oil prices swung from $105 to $70, near pre-war levels in under 60 days. For operators, that kind of swing means the rev...
08/26/2026

Oil prices swung from $105 to $70, near pre-war levels in under 60 days.

For operators, that kind of swing means the revenue side of the equation just got smaller, but the cost side didn't.

Companies can't control the oil price, what OPEC decides, what happens in the Strait of Hormuz, or where Brent closes on Friday. But there's one variable that stays within reach: what it actually costs to produce each barrel.

The operators who come out of a down-price environment with their economics intact are the ones who knew exactly which wells were carrying weight and which ones were quietly bleeding OPEX.

We know from experience that real-time cost visibility doesn't change the market.

It changes what you can do about it.

08/19/2026

"If automation can save us one trip a week per well, it pays for itself."

That's what one operator told us after deploying Well Manager across their marginal wells.

A truck roll to check a low-producing well in the middle of nowhere, just to verify everything's working normally, is a costly decision. Most operators know this, but the visibility just isn't there to prevent it.

Traditional automation was built for high-volume assets, not for mature and marginal wells. Without continuous monitoring:

- Problems get caught after a site visit, not before one.
- Maintenance stays reactive.
- And every unplanned trip eats into a margin that was already thin.

This video walks you through how Well Manager closes that gap, giving operators continuous visibility into well performance, even in the most remote locations.

🎬 Watch how it works:

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