Locus Bio-Energy

09/23/2026

Huge thank you to The Chemical Cowboy Show for having Locus Bio-Energy SVP Marty Shumway on their second episode.

Marty discusses biosurfactants, their role in oilfield chemistry, and how Locus is scaling their use across real-world applications in major oil and gas basins.

Check out the full episode here:

In this episode of The Chemical Cowboy Show, host Brandon Wamsley s...

09/15/2026

A common objection to frac surfactants is that an early production gain may simply reflect faster depletion of the same accessible resource, rather than an increase in recovery.

The 12 month Delaware Basin Wolfcamp A data gives that question more time to resolve. Treated wells maintained their advantage through one full year of operation, with higher cumulative oil and gas production relative to untreated controls.

If the treatment were only accelerating depletion from the initial fracture network, the treated and control wells would be expected to move closer together as that early resource depleted. Sustained separation over time is consistent with the treated wells continuing to access and mobilize hydrocarbons beyond what the controls recovered on the same timeline.

For operators evaluating completion chemistry, the more relevant question is how long the production response persists and what that duration suggests about reservoir access and ultimate recovery.

09/08/2026

Frac surfactants have a long history of mixed field results, so operator skepticism is understandable.

Part of that history comes down to where the chemistry can work and for how long. In tight shale, many conventional surfactant systems are concentrated around the initial fracture network, while a significant amount of recoverable oil remains deeper in the matrix. The value of the chemistry depends on its ability to reach that resource and maintain useful interfacial activity as the well moves beyond early fracture dominated production.

SUSTAIN® is designed around that problem. Its nanoscale biosurfactant chemistry can access tight pore space, lower interfacial tension and shift wettability within the reservoir.

In Delaware Basin Wolfcamp A wells, the impact continued well beyond early flowback, with approximately 20% more cumulative oil after 12 months and projected EUR expansion of more than 15%.

When completion programs are already highly optimized, the chemistry deserves to be evaluated by the reservoir access and sustained recovery it can create over time.

08/20/2026

Completion crews measure their work in days. Chemistry gets measured in years.

Twelve months after completion, wells treated with SUSTAIN® SF101 biosurfactant frac chemistry in the Delaware Basin are producing roughly 20% more cumulative oil than their offsets. The divergence from offset wells held through month twelve.

The mechanism is access. Biosurfactant micelles are small enough to enter pores below 40 nanometers, where conventional surfactants cannot. Treating more of the reservoir at the frac stage shows up in the production curve long after the pad is quiet.

The chemistry decision made during completion is still paying out a year later. Full 12-month field results are in our case study.

https://hubs.ly/Q04tdF5x0

08/18/2026

There is a gap between the zone where frac chemistry is easiest to evaluate and the pore space where a larger share of remaining oil can still be trapped.

Near-wellbore treatment gets most of the attention because the response is easier to measure. Flowback behavior, short-term rate uplift and early production data come back quickly, which makes them useful, but also easy to overvalue when judging recovery chemistry.

The matrix is harder to reach and harder to prove. It is also where chemistry has to create contact if the goal is durable recovery improvement beyond early cleanup. That requires movement past the near-wellbore zone and into the rock itself.

Locus Bio-Energy’s biosurfactant-based technology approaches recovery as a matrix access problem, with chemistry designed to travel into the formation rather than stop at the easiest part of the system to measure.

08/13/2026

The first thing a well shows you after a surfactant treatment is more water.

That early water is flowback — the injected volume returning. Cleanup follows, then oil cut climbs and incremental production shows above baseline. When production trends back toward baseline, that is the retreatment window opening, not a verdict on the chemistry.

Field results for AssurEOR STIM® in the Bakken: more than 70% production uplift and over 1,700 incremental barrels per well.

Reading the curve on the chemistry's timeline is the difference between abandoning a working treatment and capturing the next one. Both mistakes cost barrels.

08/12/2026

Capillary pressure traps mobile oil within the unpropped microfracture network. To influence recovery, the chemistry first has to physically reach that pore space.

Wolfcamp A pore throats are typically under 40 nm. Conventional surfactant micelles are typically ~100 nm.

They simply don't fit.

SUSTAIN® micelles are approximately

08/05/2026

When it comes to EOR, candidate selection changes the economics of the whole program.

Chemical stimulation returns more when the well still has more to give. More remaining resource, more pressure support, more for the chemistry to work with.

To get the most from your stimulation program, treat early.

07/30/2026

The first 90 days of production indicate the ex*****on quality of your completion program, but it takes much longer to estimate ultimate recovery.

Two wells can track nearly identically in early production curves and diverge sharply once boundary-dominated flow sets in, exactly when reservoir behavior begins to matter most.

Evaluating a change to your completion program after 90 days is like writing a review after reading only the first chapter of a book.

The 12-month data is where the story actually shows up

07/29/2026

What if EOR in shale starts on day one?

The industry typically treats enhanced recovery as a late-life intervention, but capillary forces that trap hydrocarbons are active from the moment flowback starts. If completion chemistry can reduce those forces during initial flowback, enhanced recovery starts long before the well reaches decline.

At 1 gpt, SUSTAIN® delivers ~20% cumulative oil uplift 12 months post-frac, measured against analog wells from public state filings.

Day one. That's when you should consider improving your production.