Faster, Longer, and More-Reliable Bit Runs With New-Generation PDC
Cutter

Clegg, John Martin

doi:10.2523/102067-ms

Cited by 16 publications

(4 citation statements)

References 0 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…The process of diamond leaching to improve the thermal resistance of PDC cutters was first patented around 2000 (Griffin et al 2003), and has remained one of the most important innovations for PDC cutter technology over the last decade (Clegg, J. 2006).…”

Section: Ultra Deep Thermal (Udt) Cutter Technologymentioning

confidence: 99%

Innovative PDC Bit Designs With Improved Cutter Technology Deliver Significant Performance Improvements in Arabian Deep Gas Applications

Teasdale

Markandeya

Djaoui

et al. 2013

SPE Asia Pacific Oil and Gas Conference and Exhibition

View full text Add to dashboard Cite

show abstract

Section: Ultra Deep Thermal (Udt) Cutter Technologymentioning

confidence: 99%

Innovative PDC Bit Designs With Improved Cutter Technology Deliver Significant Performance Improvements in Arabian Deep Gas Applications

Teasdale

Markandeya

Djaoui

et al. 2013

SPE Asia Pacific Oil and Gas Conference and Exhibition

View full text Add to dashboard Cite

show abstract

“…There are several key factors that are attributed to their continuing success including recent major step changes in both cutter technology 13 and stabilization 14 . There are several key factors that are attributed to their continuing success including recent major step changes in both cutter technology 13 and stabilization 14 .…”

Section: Novel Drill Bit Design: Optimized Hydraulics and Gauge Geomementioning

confidence: 99%

Delivering Steering Success in Problematic Soft Formation Directional Wells

Barton¹,

Card²,

Graham³

2008

Proceedings of IADC/SPE Asia Pacific Drilling Technology Conference and Exhibition

View full text Add to dashboard Cite

Development and diversification of directional drilling tools continues, as do the applications in which they operate. As a result, there is continual demand for development and refinement of drill bits and string tools to meet the latest challenges and issues faced. One such challenge is the ability to reliably deliver consistent directional performance in very soft formation applications. Issues such as hole washout, inappropriate drilling parameters, stabilization, and hole quality can all contribute to poor directional drilling performance.Several commercial projects are reviewed where technical merit has justified use of Rotary Steerable Systems (RSS), but due to the very soft lithologies, these systems have been unable to deliver the required directional control. In each example, a separate engineered solution is introduced. These include;• An innovative concentric string reamer, featuring a mid-reamer section that enables effective stabilization of the reamer even if the pilot borehole is of poor quality or is over gauge • A soft formation fixed cutter drill bit design with an engineered hydraulic configuration to avoid hole washout and extended circumferential gauge geometry • A near-bit stabilizer incorporating a full ring gauge that delivers 360 degree circumferential coverage, thus providing greater contact with the wellbore and higher potential for deviation • A specific Bi-center design that utilizes a secondary component configuration on the face of the pilot to enable appropriate drilling parameters to be utilized for efficient directional control. The gauge geometry and profile is also tailored to suit soft formation drilling.Global case studies document where these solutions, in combination with both Push and Point RSS, have proven extremely successful. These have provided greater flexibility with regard to tool selection, well planning options, and delivering lower cost per foot in RS projects.

show abstract

“…Aside from a directionally matched gauge configuration, the bit also featured PDC cutter technology, featuring a cutter wrapped with an ultra abrasive resistant, thermostable diamond layer 11 . This was complemented by full secondary PDC cutter coverage for enhanced durability.…”

Section: Well #8mentioning

confidence: 99%

Extreme Drilling Environment Forces Evolution of Rotary Steerable Systems and Rotary Steerable Bit Technology

Cox¹,

Romo²,

Champion³

et al. 2007

Proceedings of SPE/IADC Drilling Conference

View full text Add to dashboard Cite

TX 75083-3836 U.S.A., fax 1.972.952.9435. AbstractWells drilled in the Tuscaloosa Trend located near Baton Rouge have long been recognized for the extreme nature of the High-Pressure / High-Temperature (HP/HT) operating environment and potential for well control problems 1 . The current focal point, however concerns drilling the highly abrasive formations contained within the intermediate and drilling liner sections to depths of ± 20,000-ft. These sections have been a major cause of bit, directional tool and drill string failures. The directional complexity of the wells has increased exponentially in recent years due to surface location constraints and reservoir compartmentalization. New drills are therefore primarily directional in order to penetrate multiple stacked targets, fault-out depletion; which would otherwise result in drilling differentials in excess of 13,000 pounds per square inch (psi) and adhere to regulatory constraints imposed upon building surface locations in certain areas.Directional control in the intermediate hole section is challenging as it requires drilling through the abrasive and damaging Wilcox formation and still risks the wellbore drifting out of the target. However, below the intermediate section we encounter significant directional tool constraints as in situ temperatures range from 300-ºF to 400-ºF. Poor directional response, low penetration rates as well as increased motor failures due to stator deterioration have traditionally resulted in long and costly sections. The impact of conducting directional operations in the intermediate or drilling liner hole sections has resulted in an incremental spend of up to $3.0-MM on some wells and a 30-day to 45-day delay in first production.This paper focuses on the improvements which have been achieved over a 5-year period due to the implementation of Powered Rotary Steerable Systems (PRSS) coupled with Rotary Steerable Bit Technology. The step-change in performance has been evidenced by reduction in days per 10,000-ft (D/10K) drilled from 86-D/10K to 55-D/10K. The improved time to first production has been attributed to the systematic learning and the successes of several office based, well site and third party teams.

show abstract

Faster, Longer, and More-Reliable Bit Runs With New-Generation PDC Cutter

Abstract: TX 75083-3836, U.S.A., fax 01-972-952-9435.

Cited by 16 publications

References 0 publications

Innovative PDC Bit Designs With Improved Cutter Technology Deliver Significant Performance Improvements in Arabian Deep Gas Applications

Innovative PDC Bit Designs With Improved Cutter Technology Deliver Significant Performance Improvements in Arabian Deep Gas Applications

Delivering Steering Success in Problematic Soft Formation Directional Wells

Extreme Drilling Environment Forces Evolution of Rotary Steerable Systems and Rotary Steerable Bit Technology

Contact Info

Product

Resources

About