The Halliburton MegaForceTM bit features advanced SelectCutterTM PDC technology, ultra-efficient cutter layout force balancing, improved erosion resistant material and enhanced hydraulics. Designed for an operator’s specific application by one of our Application Design Evaluation (ADESM) service specialists using our industry-unique Design at the Customer Interface (DatCISM) Process, the result is a matrix bit with a combination of higher ROP and longer intervals drilled than any other bit.
Case Study1
A customer looked to Halliburton’s Drill Bits and Services for a solution to drilling through a hard and abrasive formation in Kuwait. Halliburton recommended the MegaForce Drill Bit with SelectCutter PDC tech?nology to provide a faster rate of penetration (ROP) with longer drilling intervals. This solution enabled the customer to drill almost double the planned footage.
The customer needed a robust drill bit for a vertical 16-in. hole section through sandstone and limestone. The customized bit needed to endure high abrasiveness and repel the high torque at the bottom.
The matrix body of MegaForce drill bit is designed to stay sharper longer, thereby providing more footage at higher ROPs. The bit’s Advanced Tungsten Carbide Matrix material reduces erosion and wear while the multi-level force balance increases bit stability during drilling. The Micro nozzles of MegaForce drill bit enhance hydraulics to improve fluid flow across the cutting structure. The reduced drill bit length of MegaForce drill bit increases directional control.
The MegaForce drill bit has an aggressive cutting structure due to the SelectCutter technology keeping the elements sharper for longer periods. This capability enabled more footage to be drilled at higher ROPs. The bit’s multi-level force-balancing technology, along with the optimized dual-row cutting structure, enabled an over 1,000-ft section to be drilled at a faster ROP than the field best of 20 ft/hr.
The MegaForce bit drilled 1,197 ft at an average ROP of 32.4 ft/hr and delivered the longest interval with the fastest ROP in the field. This perfor?mance provided an 11% improvement in footage drilled with a 62% increase in the ROP. The results provided the customer with a 31% time savings.
Case Study2
Hard-to-drill applications across the United States have long challenged the limits of drill bit performance, demanding impact and abrasion resistance, which typically means sacrificing penetration rate for durability. Difficult formations such as the Bakken shale are laden with transition zones and conglomerates and serve as the “proving grounds” for advancing bit technology, where the objective is always the same: drill an entire hole interval in a single run at optimal rate of penetration (ROP). Halliburton’s MegaForce bits incorporate new cutter, materials, and design technologies that generate a significantly higher standard of performance than is typically accepted for hard/ abrasive drilling. Featuring the SelectCutter PDC cutters, the industry’s most advanced PDC technology, the erosion-resistant MegaForce bit design integrates the key factors that contribute to longevity and faster ROP. When paired with Halliburton’s Design at the Customer Interface (DatCISM) process, the MegaForce bits deliver longer runs at faster penetration rates than ever before.
Hard/abrasive drilling accelerates cutter wear and reduces ROP, while transition drilling increases susceptibility to cutter impact damage due to the dynamic forces applied to the brittle diamond material.
- MegaForce bits incorporate SelectCutter PDC cutters, which remove significantly more rock with substantially less wear, exhibiting 40% greater abrasion resistance.
Erosion of the matrix material shortens bit life and alters hydraulic efficiency. An abrasive slurry at the bit face with the high flow rate typically needed for hole cleaning can initiate erosion in conventional matrix material, limiting bit performance.
- A proprietary tungsten carbide mix in the matrix drill bit material provides greater erosion resistance and strength, accommodating increased flow rates and pressures that otherwise would compromise material integrity and limit performance in hard/abrasive formations.
Transition drilling through different formations generates unbalanced force loading on bits, making cutters more susceptible to breakage and compromising drilling efficiency.
- Multi-level force balancing modifies the cutter placement, stabilizing the drill bit and providing even distribution of the durable cutting force during transitional drilling. The interface optimizes the depth of the cut on adjacent cutters, improving overall drilling efficiency.
Extreme horizontal well profiles and long lateral sections through hard/abrasive rock test the directional responsiveness of bit designs already exposed to the harshest formations.
- The bit-to-bend distance in a MegaForce bit has been reduced by 14% to extend fatigue life in the connection while “micro” nozzles optimize hydraulics to clear cuttings and minimize erosion.
Case Study3
Williston Basin：In three Bakken shale wells in Wyoming, MegaForce bits continue to improve ROP on subsequent installations. In the first well, an 8 3/4-inch MegaForcebit drilled the entire 8,617-foot vertical section in only 68.5 hours, producing an excellent ROP of 125.8 ft/hr, an operator record for the county. The bit drilled 5,536 feet in 24 hours and averaged 2,913 feet per day, providing the fastest ROP and lowest cost per foot among the offsets. A second well, also drilled with an 8 3/4-inch MegaForce bit, surpassed the results in the first well, drilling an 8,389-foot section to TD after only 66.5 hours. The bit drilled 5,600 feet in 24 hours with a ROP of 126.2 ft/hr, another operator record for the county. Finally, in a long lateral interval of a third well, a 6-inch MegaForce bit drilled 4,133 feet of the Three Forks formation at the fastest ROP and lowest cost per foot, including drilling 2,654 feet in 24 hours to establish a Williston Basin 24-hour Three Forks footage record.
US Rocky Mountains：A mountain well in Utah, the field benchmark performance of 7 7/8-in. bits, shown in red, was well-established, using what was then considered to be latest-generation technology. The introduction of MegaForce bit technology produced immediate performance improvements, with the MegaForce bit drilling 31% more footage at a 20% increase in ROP over the same section, and delivering a better dull grade than all previous designs.
East Texas: In Leon County, Texas, an 8 3/4-inch bit performance had topped out with a maximum footage of 827 feet at an average ROP of 20.6 ft/hr. MegaForce bits immediately exceeded that performance to establish new field benchmarks (shown in red), drilling 918 feet at 22.1 ft/hr for 18% greater footage and 25% faster ROP than the best offset.
Permian Basin：In the Permian Basin, where data from multiple wells is available for comparison, the MegaForce results(shown in red) exceed past field performance records in terms of average ROP and footage drilled in a single run. Over multiple runs, the enhanced MegaForce bits delivered as much as 12% greater footage and up to 24% faster ROP.
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