Application Specific Steel Body PDC Bit Technology Reduces Drilling Costs in Unconventional North America Shale Plays

Hanna, Chase; Douglas, Charles; Asr, Hany; Durairajan, Bala; Gerlero, Martin; Mueller, Levi; Pendse, Bhushan; Travers, Chris

doi:10.2118/144456-ms

Cited by 8 publications

(1 citation statement)

References 10 publications

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“…Waterway, or bit-body, profile plays an important role in bit hydraulics and cuttings evacuation. There are a few studies that suggest that the use of parabolic rather than flat profiles can improve the cuttings removal and mitigate balling (Hanna et al 2011). To study the effects of waterway profile on cuttings removal, two flat and parabolic profiles were selected (Fig.…”

Section: Resultsmentioning

confidence: 99%

Study of the Hydraulic Performance of Drill Bits Using a Computational Particle-Tracking Method

Moslemi

Ahmadi

2014

SPE Drilling &Amp; Completion

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The hydraulic performance of fixed-cutter drill bits was studied with the ANSYS-FLUENT code (ANSYS 2012). Cuttings were modeled as spherical particles that were injected from the bottom of the hole, and discrete particle modeling (DPM) was used to track the cuttings in which particle/particle interaction is ignored. The ratio of average particle velocity to average annulus fluid velocity, referred to as the cuttings-transport ratio (C t ), was then evaluated to study the hydraulic performance of drill bits under different conditions.The simulation results show that C t increases as nozzle-jet velocity and HSI (hydraulic horsepower per square inch of bit) increase. Comparing C t with rate-of-penetration (ROP) data available in the literature revealed that the rate of C t change is less than that of ROP as HSI changes. C t decreased slightly in a bit with seven nozzles when compared with the same bit with five nozzles with the same total flow area (TFA) of nozzles and inlet flow rate. Also, C t was found to be insensitive to the nozzle-size arrangement and bit-waterway profile in the studied bit size. Overall, the current method (with the assumption of negligible particle/ particle interaction) is more appropriate for predicting drill-bit hydraulic performance when drilling hard and nonreactive formations.

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Section: Resultsmentioning

confidence: 99%

Study of the Hydraulic Performance of Drill Bits Using a Computational Particle-Tracking Method

Moslemi

Ahmadi

2014

SPE Drilling &Amp; Completion

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Integrated BHA System Drills Curve/Lateral in One Run at Record ROP Saving Seven Days Rig Time

Meli¹,

Salas

Martin

et al. 2014

IADC/SPE Drilling Conference and Exhibition

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Rodrigo MartinApache Energia Argentina recently commenced horizontal drilling activity to develop shale gas reserves in Neuquén basin, Argentina. On the first well, the curve was drilled with a 12¼-in PDC bit on a positive displacement motor (PDM) bottom hole assembly. The lateral was drilled with an 8½" PDC on a point-the-bit rotary steerable system. A motor BHA was used in the curve because a standard RSS could not deliver the required dogleg severity (DLS). To optimize operations, the operator wanted to complete the curve and lateral with a single 8½" PDC bit. However, the lack of a high-build rate RSS tool required the curve to be drilled with a motor building to 50° of inclination then tripping for a point-the-bit RSS to TD the lateral. The single diameter strategy was successfully executed but further NPT reduction was still possible.The challenge was to drill the curve and lateral with a high build-rate RSS and a single 8½" PDC in one run to eliminate a trip to change the directional drilling system. The introduction of an inclination hold and azimuth software system would enable the hybrid RSS tool, created to build the aggressive curve angle, to continue efficiently drilling in the lateral saving an additional trip. An engineering analysis was then launched to design an application specific PDC bit for the hybrid RSS. An FEA-based system was employed to analyze offset BHAs, directional profiles, bit technologies and mud properties. The study revealed that the baseline PDC was delivering excellent ROP in both the curve and lateral sections, but t modifications would be required to improve the bit's dynamic stability. A modified 8½-in SDi513bit was proposed that featured a customized cutting structure and gauge for improved stability.Next, a rock strength analysis system was used to determine characteristics of lithologies encountered in the field. The study determined that Quintuco (curve) and Vaca Muerta (lateral) formations have relatively low unconfined compressive strengths (3-15 kpsi) but vibration potential in Quintuco formation is moderate. Computer simulations were run to map lateral/axial acceleration and bit torque on the hybrid RSS. The results showed that the new PDC design displayed a significant increase in dynamic stability compared to the baseline bit with similar high rate of penetration (ROP) potential.The shale optimized BHA was run and it drilled 1289m of curve and lateral in one run at a record ROP of 9.64 m/hr, 35% faster than the offset average. The high build-rate hybrid RSS landed the wellbore at 96° inclination with a maximum turning radius of 11.8°/30m increasing reservoir exposure within the allotted acreage unit. The increased ROP enabled Apache to reach total depth (TD) seven days ahead of plan with savings of $595,000USD.

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Aligned Materials and Design Development of High ROP Drill Bits

Deen¹,

Kitagawa²,

Schneider

et al. 2014

All Days

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At their advent, PDC bits were aimed at soft formation, fast drilling applications. However, as PDCs have come to dominate market share over roller cones, PDC bit development has shifted focus toward other goals such as durability and longevity which is often in conflict with high ROP. Returning focus to aggressive, high ROP drilling applications has required development of materials, design and manufacturing processes in alignment with that goal set. A cross-functional team was assembled to understand and focus on the high ROP concerns of the end customer and was tasked to develop a PDC bit platform aligned with these goals. This paper discusses general and application specific challenges posed by high ROP drilling applications and how they have been addressed by the aligned development of a new system of materials, design, and manufacturing processes used in PDC drill bits. Formation to bit interaction simulations and computational fluid dynamic modeling analysis are presented in support of the development hypotheses. Field results from case studies and broad field data analysis summarizing the results of extensive testing are presented as well. Driving ROP beyond the ceilings observed in many extreme ROP applications requires that energy be efficiently transferred not just to the bit, but focused on the cutters. To achieve this, an essential change to the base material of the bit body was made, exposing drastically new avenuesand hurdlesfor design and manufacturing. However, the simulation and field results presented confirm that the new system is able to consistently achieve the goal set in high ROP applications.

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Application Specific Steel Body PDC Bit Technology Reduces Drilling Costs in Unconventional North America Shale Plays

Cited by 8 publications

References 10 publications

Study of the Hydraulic Performance of Drill Bits Using a Computational Particle-Tracking Method

Study of the Hydraulic Performance of Drill Bits Using a Computational Particle-Tracking Method

Integrated BHA System Drills Curve/Lateral in One Run at Record ROP Saving Seven Days Rig Time

Aligned Materials and Design Development of High ROP Drill Bits

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