The U.S. shale industry has spent the better part of two decades refining how to drill and complete wells with greater mechanical efficiency. Operators have extended lateral lengths, increased proppant loading, and fine-tuned fluid volumes — all aimed at maximizing wellbore contact with the reservoir.
Yet despite these advances, recovery factors remain stubbornly low, typically between 5% and 15%. That leaves roughly 90% of the original oil in place (OOIP) stranded in the formation. At the same time, investor pressure is mounting. For operators executing high-volume development, capital discipline is the priority. Improving returns through mechanical optimization gains in hydraulic fracturing has largely been implemented and realized.
According to Bain & Company estimates, a single percentage point of additional recovery can expand estimated ultimate recovery by up to 15% — turning marginal wells into clear winners and letting operators grow value, not just defend break-even, even in a low-cost construction environment.
Major operators like ExxonMobil and Chevron agree, adopting new innovations and applications to improve hydrocarbon recovery.
Mechanical efficiency has reached its practical limit. The next gains must come from chemistry.
Shifting From Access to “Effective SRV”
For years, the industry has operated under a simple assumption: more access leads to more recovery.
Access alone does not guarantee recovery — especially in tight shale formations where pore throats are measured in nanometers. In the Wolfcamp shale, for example, the majority of organic pore-throat sizes are below 50 nm. At this scale, production is governed by surface phenomena like interfacial tension, capillary pressure, and wettability. Conventional surfactants deliver a short-lived production response because their micelles — typically ~100 nanometers — are too large to penetrate the tightest pore networks, leading to limited production impact.
SUSTAIN® biosurfactant-based technologies are engineered to solve this physical limitation in several ways.
- Nanoscale Penetration: SUSTAIN forms highly stable, ultra-compact nano-micelles as small as 3–5 nanometers, allowing them to more easily penetrate tight shale pore networks.
- Promoting Sustained Fluid Release: SUSTAIN nano-micelles move deep into the un-propped micro-fracture network to physically mitigate capillary trapping by altering rock wettability and lowering interfacial tension.
- Expanding the Effective Stimulated Reservoir Volume (SRV) for Lasting Impact: While massive sand and fluid volumes create the geometric fracture network, SUSTAIN expands the “Effective SRV” — increasing the volumetric portion of the network that actively and continuously transmits hydrocarbons to the wellbore.
The Diagnostic Proof: Multiphase Flow Efficiency
SUSTAIN’s ability to improve the chemical efficiency of hydraulic fracturing was validated in strictly controlled A/B multi-well pad trials in the Delaware Basin. Specifically, the operator selected SUSTAIN® for the trials, based on its superior performance versus 19 other surfactants from multiple vendors in third-party qualification testing. The full results are detailed in the 12-month Delaware Basin Wolfcamp A case study.
The early stage of the trials (Months 1–6) was marked by a fracture-controlled flow period, during which fluid moved from the tighter rock matrix directly into the high-permeability natural or hydraulic fractures before reaching the wellbore. During this period, treated wells exhibited a 20% early-time oil-rate uplift.
The most compelling story is what happened as the wells transitioned to boundary-dominated flow, a later-stage period where the entire boundary volume contributes simultaneously to production. In this stage, untreated wells will experience a uniform drop in reservoir pressure and a stable, predictable decline in well production rates.
At 12 months, SUSTAIN-treated wells continued to outperform non-treated wells with:
- 20% higher cumulative oil production
- 23% higher cumulative gas production
- 18% lower water-oil ratio (WOR)
Proving Incremental Recovery
Sustained rate separation from early-time fracture-controlled flow into later-time boundary-dominated flow proves that this uplift is not simply accelerated production. Furthermore, multiphase diagnostics show a systematically lower WOR and moderate gas-oil ratio (GOR) escalation in the SUSTAIN-treated wells. This confirms that SUSTAIN is fundamentally improving near-fracture fluid mobility rather than inducing aggressive depletion.
Capital Efficiency & Asset Economics
SUSTAIN offers a proven low-risk capital efficiency lever that generates immediate cash flow while expanding estimated ultimate recovery by more than 15%.
Based on reported production data, financial metrics per well under typical Delaware Basin operating conditions are compelling.
- Incremental Completion Cost: Less than $200,000
- Rapid Payback: Less than 30 days based on initial rate uplift
- Net Present Value (10% discount) Contribution: ~$1.7M–2.8M per well
- Return on Incremental Investment: 13x – 18x (Year 1)
- Reduction in Lease Operating Expenses (LOE): Lower WOR reduces lifting, transport, and disposal costs — estimated to be $1–$3/bbl reduction in LOE.
Scaling the Value
For multi-well pad development, these per-well economics scale linearly. A 50-well program at $60/bbl WTI, for example, could generate approximately $100MM in incremental net present value. This revenue is unlocked entirely through chemical efficiency.
As the industry shifts its focus from access to recovery, the message is clear: chemistry is no longer optional. It is the next frontier for unlocking real, lasting value in unconventional reservoirs.
See the full results. Read the 12-month Delaware Basin Wolfcamp A case study to see how treated wells performed against an offset control set across a full year of production.