Oil and Gas Exploration and Production Optimization for a Saudi Upstream Operator

A Saudi upstream oil and gas operator managing multiple onshore fields sought expert advisory to optimize exploration, development, and production activities. The operator oversaw reservoirs of varying maturity, including declining wells, mid-life assets, and new exploration blocks. Leadership required a structured strategy to enhance production efficiency, reduce operational costs, and evaluate new technologies supporting reservoir management, digital monitoring, and automated field operations. With increasing industry competition and tightening environmental expectations, the operator aimed to adopt modern practices that ensured long-term viability and operational resilience.

We delivered a comprehensive Exploration and Production Optimization Program combining reservoir modeling, digital field systems, predictive maintenance, and operational restructuring. The solution introduced advanced reservoir-simulation tools to improve recovery forecasting, automated well-monitoring systems for real-time performance visibility, and predictive maintenance algorithms to reduce downtime. We also developed a structured operational model integrating exploration analysis, production scheduling, and asset-management cycles. Environmental tracking tools were implemented to ensure compliance with evolving regulations regarding flaring, emissions, and water reinjection. The program enabled the operator to transition toward more accurate, transparent, and efficient upstream operations.

• Assessed reservoir maturity, well conditions, and production patterns across all fields.
• Built advanced reservoir models to simulate recovery rates and optimize well-spacing decisions.
• Deployed real-time digital field technologies for automated data capture and well-performance monitoring.
• Implemented predictive maintenance systems for pumps, compressors, and drilling equipment.
• Designed optimized production schedules to reduce energy consumption and improve reservoir balance.
• Introduced environmental-performance dashboards tracking emissions, water recycling, and flaring activities.

• Adopt continuous reservoir-model updates using real-time production data.
• Expand digital field automation across all sites to reduce manual labor dependency.
• Implement water-management and reinjection optimization strategies to improve pressure support.
• Transition toward predictive maintenance to extend equipment lifespan and reduce downtime.
• Strengthen environmental monitoring to support regulatory compliance and reduce operational risks.
• Create a dedicated upstream optimization unit to manage reservoir analysis, technology integration, and long-term planning.

The optimization program increased recovery rates by 7–11% across mid-life fields, generating annual production uplifts valued at SAR 84 million. Predictive maintenance reduced equipment failure by 31%, saving SAR 12.6 million in emergency repairs. Digital field automation cut operational labor costs by 21%, while improved production scheduling reduced energy consumption by 17%, equivalent to SAR 8.3 million in annual savings. Over a five-year horizon, total financial impact exceeded SAR 310 million, driven by improved production stability, reduced downtime, and enhanced reservoir performance.