The chemistry that doubles a field.

Benefits

• —Enhances injectivity and displacement efficiency for significant incremental recovery.
• —Resists thermal and chemical degradation at high temperatures and salinities.
• —Minimal adsorption in the formation; winterized versions for cold climates.

Economics

• —Lower operational energy and injection-pressure costs.
• —High ROI — minimal chemical loss combined with increased oil yield.

Benefits

• —Minimises the Steam-to-Oil Ratio (SOR), increasing total oil output.
• —Thermal-stable; designed to resist degradation in steam systems.
• —Minimal impact on boilers and topside equipment; winterizable.

Economics

• —Reduced SOR translates to lower fuel and water-treatment costs.
• —Minimal topside impact prevents costly repairs and downtime.

Benefits

• —Increases residual oil recovery by keeping oil flowing rather than emulsifying.
• —Lower slug viscosity prevents high-pressure gradients.
• —Enhanced phase stability deep in the reservoir; low surfactant retention.

Economics

• —Lower retention and improved stability cut cost per incremental barrel.
• —Reduced slug viscosity lowers pumping energy expenditure.

Benefits

• —Diverts gas into bypassed pay-zones, maximizing oil recovery.
• —Low surfactant adsorption on reservoir rock — deep penetration.
• —No impact on topside facilities; no reservoir damage from emulsification.

Economics

• —More economical than mechanical interventions; optimises gas utilisation.
• —Reduces gas-recycling OPEX by restricting breakthrough.

Benefits

• —Smart EASEOR™ IIoT sensors and analytics optimise efficiency and safety in real-time.
• —Decreases water cut and lowers CO₂ per barrel by 2–6× through energy-efficient sweep.
• —Extensive polymer range tailored to permeability, temperature, salinity and viscosity.

Economics

• —Energy-efficient sweep reduces lifting and water-handling costs.

Benefits

• —Methodologies: MULTIFLO · TIPPS / AUTOFLOAT · POWER CLEAN.
• —Prevents well damage across multi-year EOR campaigns.

Economics

• —Industry benchmark: 5–20% OOIP for tertiary EOR.

Benefits

• —Methodologies: OPUS II · HPD Evaporation · SHALEFLOW.
• —Recycles produced water for SAGD steam — lifts steam rates.

Economics

• —Eliminates freshwater sourcing and disposal bottlenecks.

Benefits

• —Unlocks residual oil water-flooding cannot recover.
• —5–20% incremental OOIP recovery depending on reservoir conditions.
• —Wettability alteration improves displacement efficiency.

Economics

• —Reduces oil-water IFT to ultra-low levels — trapped droplets move.

Benefits

• —Typical incremental recovery: ~10–20%+ of OOIP in suitable reservoirs.
• —Mobilises oil trapped after water-flooding via ultra-low IFT.
• —Alkali synergy lowers surfactant adsorption — lower dosage and cost per barrel.

Economics

• —Alkali reduces surfactant adsorption onto rock; lower chemical cost per recovered barrel.

Benefits

• —SP: higher recovery than polymer alone, no alkali-related risks, faster to design and implement than ASP.
• —AP: lower chemical cost than SP/ASP, in-situ surfactant generation, particularly effective in acidic crude reservoirs.
• —Simpler chemistry and faster field implementation.

Economics

• —AP delivers in-situ surfactant generation at materially lower chemical cost.