Digital Oil & Gas Solutions

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.

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:

The IEA's Global Methane Tracker 2026 puts a number on what operators are leaving behind.100 bcm of gas recoverable thro...
07/29/2026

The IEA's Global Methane Tracker 2026 puts a number on what operators are leaving behind.

100 bcm of gas recoverable through methane abatement. Another 100 bcm from the end of non-emergency flaring. 200 bcm of product that's already being extracted, just not captured.

Operators often lose that value because they don't have real-time visibility into where emissions are occurring, when they spike, or why.

The companies getting ahead of this are building digital infrastructure that turns emissions data into decisions: real-time capture, time-series analysis, and operational context that explains WHY it happened.

Measurement without action is just documentation. Treating methane as an operational priority means capturing the value that others are venting.

You can't control Brent, but you can control how quickly your operation sees and responds to waste, downtime, and avoida...
07/28/2026

You can't control Brent, but you can control how quickly your operation sees and responds to waste, downtime, and avoidable field activity.

The IEA's oil market report shows global supply balances tightening again. And with ongoing uncertainty around the Strait of Hormuz (where roughly 20% of the world's oil passes through daily) price volatility isn't going away anytime soon.

The operators who survive are the ones who know their true operating costs in real time. 💰️

- How much does an unplanned truck roll cost you?
- How many hours of production did you lose last month that you didn't catch until the invoice showed up?
- What's the actual per-barrel cost on your marginal wells right now?

If those answers take days to pull together, volatility hurts more than it should.

An alert that doesn't change a decision is just noise. 📣 A pressure reading outside a generic threshold tells you someth...
07/23/2026

An alert that doesn't change a decision is just noise. 📣

A pressure reading outside a generic threshold tells you something changed. But it doesn't tell you whether that change matters for that specific well, under which operating conditions, and at what point in the production cycle.

Field teams stop trusting alerts when alerts no longer mean anything. And when trust breaks down, real problems get dismissed along with the false ones.

Context is what separates signal from noise. When the system knows what normal looks like for each individual asset, teams respond faster — not because they have more notifications, but because the ones they get are worth acting on.

Alerts are only useful if they're calibrated to the well.

See how we can help here: https://www.digitaloilandgas.solutions/en/what-we-do/well-manager -section

Most reporting problems start when a field reading gets written on paper and transcribed two days later, or when the ERP...
07/22/2026

Most reporting problems start when a field reading gets written on paper and transcribed two days later, or when the ERP says one thing and the spreadsheet says something else.

By the time finance needs a cost-per-barrel figure or engineering wants to compare well performance, nobody trusts the numbers. So they rebuild the analysis from scratch every time.

The root of it is data architecture, and that's a different problem with a different fix.

And it's exactly what our Data Management Services solve.

We help operators build a unified data layer that connects field data, production records, maintenance logs, and financial systems.

As well as invoice automation, legacy data migration, BI reporting, and dashboards that pull from one source instead of five.

🚨 If your team spends more time reconciling numbers than acting on them, that's a data architecture problem. Here's the fix: https://www.digitaloilandgas.solutions/en/what-we-do/data-management

Some site visits solve problems. Others only confirm that nothing changed.The problem with fixed visit schedules is that...
07/16/2026

Some site visits solve problems. Others only confirm that nothing changed.

The problem with fixed visit schedules is that they're built around time, not need. The well gets checked because it's Tuesday, not because anything indicated it needed checking.

Remote visibility flips that logic.

When you know the status of every asset before the truck leaves the yard, visits become exception-based, and your team goes where they're needed, not where the calendar says to be.

The expertise gets redirected toward work that actually changes the outcome.

🚨 Curious what exception-based visits could save your team in truck rolls? Send us your well count and average visit frequency, we'll run the math!

75% of U.S. producing wells are marginal wells. 🛢️ Most run without continuous monitoring. A manual check once a day (so...
07/15/2026

75% of U.S. producing wells are marginal wells. 🛢️

Most run without continuous monitoring. A manual check once a day (sometimes less) on assets where a few hours of undetected drift can erase the margin that makes the well worth running.

That's a revenue leak hiding in plain sight.

Pressure drifts. Flow drops. Pump behavior shifts.

None of it was dramatic enough to flag on a single visit. All of it is visible on a trend line.

Operators running continuous monitoring on marginal assets report up to a 50% reduction in OPEX, with most savings coming from catching small problems before they become costly.

How are you currently catching pressure drift on your marginal wells: through daily rounds or through automation? Let us know in the comments! 💬

Address

Tulsa, OK

Telephone

+13214364684

Website

Alerts

Be the first to know and let us send you an email when Digital Oil & Gas Solutions posts news and promotions. Your email address will not be used for any other purpose, and you can unsubscribe at any time.

Shortcuts

Share