H2S Process Mapping

The presence of hydrogen sulfide (H₂S) in production streams poses substantial operational challenges and financial burdens for oil and gas operators. H₂S can lead to production losses stemming from health, safety, and environmental (HSE) concerns, as well as threats to asset integrity. Additionally, the presence of H₂S often reduces process efficiencies and impacts production rates.

Globally, the number of sour fields is increasing, and the degree of souring typically intensifies as fields mature. Reservoir souring is often attributed to microbiological activity within the formation. Understanding the multiphase concentration trends of H₂S is crucial to addressing several key concerns:

• Partial Pressure and Fugacity: Calculating these factors helps assess H₂S behavior under specific temperature and pressure conditions.
• Integrity Threats: H₂S poses significant risks to downhole completions and surface facilities, including corrosion and embrittlement.
• H₂S Production Allocation: Accurate identification of H₂S sources across wells and formations is essential for targeted mitigation.

Reservoir, well, and process souring present complex HSE, asset integrity, and export compliance challenges. Beyond the immediate risks to personnel, H₂S induces corrosion in wet systems and can cause metal embrittlement, jeopardizing the durability of production infrastructure. Despite these risks, many operators lack detailed insight into H₂S concentrations across wells and processes.

To gain an accurate understanding of H₂S distribution, operators often perform mapping exercises across their assets. These efforts target H₂S levels in individual wells and throughout the production process. However, traditional methods present limitations:

• Stain Tubes: While widely used, these are often insufficiently accurate for comprehensive H₂S analysis.
• Offsite GC-SCD or FPD Analysis: Although more precise, this approach involves time-consuming sampling and logistics, often leading to underestimation of H₂S levels due to delays.

To address these challenges, ScanWell provides a cutting-edge solution through its Portable Laser Analyser (PLA), a key component of the OPRA suite of services. The PLA offers real-time, on-site H₂S monitoring with exceptional accuracy and convenience. This advanced ATEX-certified technology combines the precision of laboratory-based gas chromatography (GC) measurements with the portability and ease of use associated with stain tubes.

The PLA enables operators to conduct effective H₂S mapping exercises or implement long-term monitoring strategies. Real-time trending and accurate data empower production teams to:

• Enhance H₂S mitigation efforts by identifying high-concentration areas promptly.
• Develop targeted strategies to reduce H₂S levels and safeguard equipment integrity.
• Improve compliance with HSE and export standards through precise monitoring.

By integrating ScanWell’s PLA technology, operators can gain actionable insights into H₂S distribution across their assets, reducing risks and optimizing production performance. This innovative approach bridges the gap between convenience and accuracy, supporting a proactive stance in managing H₂S in oil and gas production.