Challenge

During a South Texas completion, a frac consultant observed challenging treating conditions, including higher-than-expected treating pressures and complex wellbore dynamics. As this was their first U-shaped well with a new perforation design, the consultant aimed to evaluate a range of variables contributing to the increased pressures, including chemical performance. Razorback Direct’s team was engaged to leverage its chemical expertise to rule out the friction reducer (FR) as a potential factor, enabling the operator to make informed, data-driven decisions.

Razorback Direct's Approach

With extensive experience in completions chemistry, Razorback Direct implemented a thorough, systematic plan to isolate potential factors and clarify the role of the FR in overall performance:

• Onsite Testing and Equipment Adjustment: Initial testing confirmed that the FR was meeting both viscosity and friction reduction specifications. Upon inspecting the chemical setup, Razorback’s team observed that the biocide and FR streams were colliding before reaching the water in the blender tank, affecting the FR’s performance. Repositioning the FR hose effectively resolved this issue, ensuring optimal mixing and confirming the FR’s full functionality in the field.

• Head-to-Head FR Trial: To conclusively rule out the FR as a contributing factor, Razorback conducted a head-to-head trial between a previously proven alternative FR and the incumbent FR under controlled conditions. The incumbent FR consistently treated 200 psi below the alternative, confirming that the FR was not causing the treating pressure variations.

• Comprehensive Diagnostic Support: Razorback collaborated closely with the operator and onsite frac consultant, identifying that the well’s unique 180-degree turn, and the perforation design likely contributed to increased pipe friction. While the well’s structure could not be altered, adjustments to the perforation design resulted in:

1. • Reduced time to achieve maximum rate,
   • Lower chemical usage, and
   • Treating pressures consistent with pre-job expectations.

Conclusion

Through systematic testing, equipment adjustments, and collaborative diagnostics, Razorback Direct ruled out FR as a contributing factor to the treating conditions. Razorback worked closely with the operator to identify additional potential variables, including the effects of pH fluctuations, sand quality, turbidity, and perforation design. Lab analysis ultimately ruled out these factors, guiding everyone to conclude that well design and formation characteristics were the primary contributors to the performance issues.

Razorback’s transparent, expertise-driven approach provided the operator with a comprehensive view of factors impacting the well. As a trusted advisor, Razorback empowered the operator with data-backed insights to address design challenges and make informed adjustments, optimizing completion strategies for future wells.