Enhanced Oil Recovery in Northern Delaware Basin

Background

A water midstream company in the Northern Delaware Basin managed 25,000 barrels/day of produced water, with high water-to-oil ratios (up to 10:1). The operation involved gathering water, recovering residual “skim oil” for sale, and reinjecting water for disposal or Enhanced Oil Recovery (EOR) via waterflood. Efficient oil recovery and water injectivity were critical for profitability and EOR success.

Challenge

The operation faced:

• Poor Water-Oil Separation: Emulsified oil in water (200 mg/L, above the 100 mg/L target) reduced skim oil recovery and risked injection well fouling.
• Paraffin/Asphaltene Buildup: Wax and asphaltene deposits clogged pipelines and wells, requiring frequent maintenance (weekly pigging, monthly solvent flushes).
• Poor Injectivity: Injection pressure rose from 1,00 to 1,850 psi, nearing regulatory limits, forcing reduced rates or costly water storage/transport.

These issues cut skim oil recovery (~50 barrels/day), increased costs, and threatened EOR performance.

Recommendation

Chemical Injection Partners (CIP) proposed:

• Custom Emulsion Breaker: To reduce oil-in-water to <50 mg/L.
• Paraffin/Asphaltene Dispersant: To prevent deposition in pipelines and wells.
• Optimized Injection and Monitoring: Relocated injection points, real-time oil-in-water analyzers, and continuous performance tracking.

Implementation

• Trial: Tested chemicals on one processing train, reducing oil-in-water and increasing oil recovery.
• Full Rollout: Applied across all trains with elevated initial dosages to clear deposits, then optimized. CIP monitored water quality and injection performance, adjusting dosages as needed.
• Training: Operator staff trained for ongoing management, with CIP providing long-term support.

Results

• Water Quality: Oil-in-water dropped to 40 mg/L (80% reduction), producing clear brine.
• Oil Recovery: Skim oil increased to 70–75 barrels/day (+40%), adding ~$0.5M/year at $70/barrel.
• Injectivity: Injection pressure fell to 1,300 psi, enabling 15% higher rates without shutdowns.
• Cost Savings: Chemical costs dropped 33% ($165,000/year); maintenance (pigging, filter changes, well cleanings) reduced significantly.
• EOR Impact: Stabilized reservoir pressure boosted offset well production by 3–5%, enhancing recovery.

Conclusion

CIP’s tailored chemical program transformed the operation, improving water quality, oil recovery, and injectivity while cutting costs. This case demonstrates the value of customized chemical solutions and proactive monitoring for water midstream and EOR in high water-cut fields like the Delaware Basin.