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In the current challenging global oil and gas market, operators strive to minimize cost-per-foot (CPF) through drilling optimization and the introduction of next-generation tools to maximize return-on-investment. In response, service companies seek game-changing solutions to enhance operators' drilling operations. A cross-functional optimization team was chartered to enhance rate of penetration (ROP) in development drilling Kuwait's prolific Burgan field. The team developed a polycrystalline diamond compact (PDC) drill bit design with 25mm (1 in.) PDC cutters –presently the largest diameter commercial cutter in the industry. This paper presents the outstanding field results that were achieved with the 25mm cutter bit design. The analytical and experimental processes used in the development of the bit design will be described, and the operational results and resulting savings will be presented and compared to the established field benchmark. The geology of the 12¼ in. intermediate sections of Burgan wells is comprised of layered carbonates, shales and sandstones. The section is known to induce moderate-to-severe torsional vibrations with conventional rotary bottomhole assemblies through the heterogeneous formations. Operational practices to mitigate these vibrations effectively limit the section ROP. To address this challenge, an optimization process was initiated to manage the problematic vibrations and maximize drilling efficiency through bit design and cutter technology. In an application that was long dominated by conventional PDC bit designs with 19mm cutters, an upgraded 25mm cutter with the latest HP/HT pressing technologies incorporated in a tailored bit design to strike a balance between drilling aggressiveness and vibration control. The large cutter's unique depth-of-cut potential and increased cutter exposure were combined with reduced bit imbalance and degree of rubbing via numerous computerized simulations as part of the analysis for the Burgan application. The 25mm cutters were lab-tested and video-recorded on a dedicated laboratory rock mill to evaluate the ROP potential and apply these concepts to the 25mm cutter bit design. After the experimental bit was manufactured and performance tested in a controlled laboratory environment, the engineering team focused closely on the successful execution of the preliminary field trials, and then evaluated the results. Deployment of the engineered 25mm cutter bit design led to multiple breakthrough performances in consecutive bit runs, achieving 300%+ increased ROP on each deployment compared to the established 12¼ in. field average. Analysis of the drilling logs indicates the engineered bit design provided the highest drilling efficiency to date in comparison to all conventional PDC bits previously run in this application. Torsional variations were limited through the interbedded formations, which allowed drilling parameters to be optimized throughout the runs. As a result, the operator reduced rotating hours by 70% vs. the field benchmark, with a corresponding 30%+ reduction in CPF.
In the current challenging global oil and gas market, operators strive to minimize cost-per-foot (CPF) through drilling optimization and the introduction of next-generation tools to maximize return-on-investment. In response, service companies seek game-changing solutions to enhance operators' drilling operations. A cross-functional optimization team was chartered to enhance rate of penetration (ROP) in development drilling Kuwait's prolific Burgan field. The team developed a polycrystalline diamond compact (PDC) drill bit design with 25mm (1 in.) PDC cutters –presently the largest diameter commercial cutter in the industry. This paper presents the outstanding field results that were achieved with the 25mm cutter bit design. The analytical and experimental processes used in the development of the bit design will be described, and the operational results and resulting savings will be presented and compared to the established field benchmark. The geology of the 12¼ in. intermediate sections of Burgan wells is comprised of layered carbonates, shales and sandstones. The section is known to induce moderate-to-severe torsional vibrations with conventional rotary bottomhole assemblies through the heterogeneous formations. Operational practices to mitigate these vibrations effectively limit the section ROP. To address this challenge, an optimization process was initiated to manage the problematic vibrations and maximize drilling efficiency through bit design and cutter technology. In an application that was long dominated by conventional PDC bit designs with 19mm cutters, an upgraded 25mm cutter with the latest HP/HT pressing technologies incorporated in a tailored bit design to strike a balance between drilling aggressiveness and vibration control. The large cutter's unique depth-of-cut potential and increased cutter exposure were combined with reduced bit imbalance and degree of rubbing via numerous computerized simulations as part of the analysis for the Burgan application. The 25mm cutters were lab-tested and video-recorded on a dedicated laboratory rock mill to evaluate the ROP potential and apply these concepts to the 25mm cutter bit design. After the experimental bit was manufactured and performance tested in a controlled laboratory environment, the engineering team focused closely on the successful execution of the preliminary field trials, and then evaluated the results. Deployment of the engineered 25mm cutter bit design led to multiple breakthrough performances in consecutive bit runs, achieving 300%+ increased ROP on each deployment compared to the established 12¼ in. field average. Analysis of the drilling logs indicates the engineered bit design provided the highest drilling efficiency to date in comparison to all conventional PDC bits previously run in this application. Torsional variations were limited through the interbedded formations, which allowed drilling parameters to be optimized throughout the runs. As a result, the operator reduced rotating hours by 70% vs. the field benchmark, with a corresponding 30%+ reduction in CPF.
This paper details the improvements to drilling performance and torsional response of fixed cutter bits when changing from a conventional 19-mm cutter diameter configuration to 25-mm cutter diameters for similar blade counts in two different hole sizes. Key performance metrics include rate of penetration (ROP), rerun-ability, torsional response, and ability to maintain tool-face control during directional drilling. A high-performance drilling application was selected with several existing offset wells using a 12¼-in., five-bladed, 19-mm (519) drill bit design, and a concept bit developed using 25-mm diameter cutters while maintaining comparable ancillary features. This was tested in the same field on both vertical and S-shape sections using the same bent-housing motor assembly and drilling performance compared to the existing offsets. A 17½-in. hole size application that experiences high drillstring vibration was also selected, and a 25-mm cutter diameter drill bit was designed with comparable ancillary features to replace a six-bladed, 19-mm (619) drill bit. This was tested in the same field with the drilling performance, and vibration propensity was assessed. Initial testing in the 12¼-in. section showed extremely promising initial results, breaking the field ROP record in a well-established field of more than 3,000 wells. The rerun of the same bit without repair placed fourth in the field in terms of ROP records. Additional testing in the vertical and s-shape sections showed the new 25-mm cutter diameter design consistently exceeding the ROP performance of the 519 drill bit design while achieving directional targets without any reported drilling concerns. Subsequent trials with other operators saw similar performance improvement with multiple instances of breaking field ROP records. The first trial of the new 17½-in. hole size design with 25-mm diameter cutters had 34% average higher ROP than the offset average ROP, achieving the field ROP record. An overall 70% improvement during trials was seen in ROP versus the existing 619 drill bit design. The daily drilling reports and client feedback reported a significantly reduced level of drillstring vibration versus offset wells. This paper demonstrates the potential for a paradigm shift in drilling response and overall ROP by using 25-mm diameter cutters on fixed cutter bits. When correctly modeled, designed, and selected for specific applications, they benefit operators by reducing the time it takes to drill the section, improving repairability, reducing the time that an openhole is left exposed, and reducing drilling costs.
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