Advanced Enhanced Oil Recovery
through Nanoscopic Viscosity Engineering
A next-generation chemical stimulation platform designed to restore flow in high-viscosity and low-permeability reservoirs.
Executive Summary
Next-generation chemical stimulation technologies allow to overcome fluid deliverability barriers in conventional and unconventional reservoirs. By integrating sub-nanometer particles with advanced surfactants, the system fundamentally alters the physical properties of trapped hydrocarbons to restore flow in high-viscosity and low-permeability environments.
Key Performance Goals
The Physics of Flow: Darcy's Law & Viscosity
The operational efficiency of any oil well is governed by Darcy's Law, which defines the relationship between reservoir characteristics and production rates.
Q — Flow Rate (deliverability)
k — Permeability of the rock matrix
μ — Viscosity of the fluid
L — Flow length
ΔP — Pressure differential
The relationship between flow (Q) and viscosity (μ) is inverse and linear. Theoretically, reducing oil viscosity by 50% results in a 100% increase in flow rate.
While Darcy's Law suggests a perfectly linear gain, actual well results will experience some variance due to mechanical constraints such as pump capacity limits and wellbore friction. However, because AXA100 can dramatically reduce viscosity in laboratory settings, the resulting production increases remain substantial and highly commercial.
Reservoir Stability: The Mobility Ratio
To maximize oil recovery, operators must manage the Mobility Ratio (M), which compares the ease with which water and oil move through the formation.
λw, λo — Mobility of water and oil
krw, kro — Relative permeability of water and oil
μw, μo — Viscosity of water and oil
In heavy oil wells, μo is very high, producing a Mobility Ratio M ≫ 1. This causes "water fingering" — water flows past the thick oil, leaving it trapped in the formation.
By drastically reducing oil viscosity (μo), AXA100 products drive the Mobility Ratio toward a stable value of 1.0. Oil flows as efficiently as water, increasing sweep efficiency and significantly reducing the water-to-oil production ratio.
Mechanism of Action: Nanoparticle / Surfactant Synergy
The efficacy of Axerra's AXA100 product line lies in its proprietary delivery system, which overcomes the limitations of traditional bulk chemical treatments.
The Nanoscopic Bridge
The system utilizes sub-nanometer particles — so small they can navigate pore throats and fracture networks where even the smallest sand proppants cannot reach. Each particle is coated in a specialized surfactant. When these particles encounter the oil-water interface, they act as a "bridge," disrupting surface tension and allowing the surfactant to directly contact and mix with the oil phase.
Brownian Motion & Disjoining Pressure
Once injected, the particles exist in a state of constant Brownian motion — a rapid, random jittering caused by thermal energy. This motion, combined with the particles' electrical charge, creates disjoining pressure. This diffusion-driven mechanical force physically "pries" oil droplets off rock surfaces, mobilizing hydrocarbons previously considered unrecoverable.
Colloidal Dispersion
The particles are delivered in a colloidal dispersion that prevents clumping, ensuring uniform distribution throughout the carrier fluid and deep penetration into the formation matrix.
Operational Performance Targets
Leading products such as those that are part of our AXA100 product line are engineered to match or exceed industry benchmarks for high-efficiency chemical EOR.
| Reservoir Profile | Targeted Oil Increase* | Targeted Viscosity Reduction** |
|---|---|---|
| Heavy Oil (11° – 15° API) | 200% – 500% | From >100,000 to <50 cSt |
| Medium Oil (20° – 30° API) | 150% – 400% | Stabilization of Mobility Ratio |
| Light / Tight Oil (35°+ API) | 100% – 300% | Penetration of micro-fractures |
* Results vary by reservoir. **Lab tests produce different results than field applications.
Candidate Selection & Process
Treatment success depends on identifying the correct well problem and matching AXA100 to the right reservoir conditions.
Ideal Candidates
High-deliverability wells experiencing accelerated or dramatic decline curves.
Initial or "refrac" stimulation programs targeting reduced first-year decline rates.
Best results are expected in formations with temperature <190°F and water cuts >20%.