Expert Real-Time Drilling Performance Prevents Twist-offs and Reduces Bit Damage in the Permian Basin

Hood, J. A. A.; Taylor, Richard; Morris, P. I.; Riley, Brian J.; Plouzek, Damian; Wilson, John; Metz, Mike; Rashid, Asif

doi:10.2118/173170-ms

Cited by 3 publications

References 3 publications

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Pilot Bit and Reamer Matching: Real-Time Downhole Data Differentiates Hybrid Drill Bit’s Suitability with Concentric Reamer in Deepwater, Gulf of Mexico Application

Chowdhury

Serrano

Rodrigue

2019

SPE/IADC International Drilling Conference and Exhibition

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Deepwater wells routinely use concentric reaming devices in the bottomhole assembly (BHA) to lower the equivalent circulating density (ECD). In Gulf of Mexico (GOM) applications, concentric reamers are frequently used and are positioned approximately 100 to 150 feet behind the pilot bit to address formation evaluation and other operational constraints. This distance between a drill bit and the concentric reamer poses bit–reamer synchronization challenges, especially while drilling interbedded formations, where the bit could drill a softer formation while the reamer is placed in a harder formation or vice versa. This situation causes fluctuations in the compressive load at the bit and reamer. Cutting element damage often results from overloading, leading to a premature and costly trip. In many cases, the pilot bit or reamer could be deprived of the optimal compressive load to cut the formation, resulting in lower-than-expected penetration rates. Inadequate and fluctuating compressive loads at the bit or reamer often trigger unsustainable vibrations. Efforts to address the bit-reamer matching issue are ongoing in the industry, and managing the aggressiveness of pilot bit and reamer is frequently used as a potential solution. Although modelling programs are extensively used during the well planning process, a lack of specific guidelines continues to exist in the industry. Hybrid bits, which combine polycrystalline diamond compact (PDC) and tungsten carbide insert (TCI) rolling cutter elements, have been widely and successfully used in GOM. These bits offer higher drilling efficiency because of their dual cutting elements and balanced aggressiveness. The results of 18⅛-in. hybrid drill bit usage with a concentric reamer provided encouraging results and offered a potential solution to the bit-reamer synchronization issue. Using real-time downhole data, this paper evaluates and compares bit and reamer load distribution, drilling mechanics of PDC and hybrid bits, and provides valuable analytical insights on successful application of hybrid bits to address the issue of bit-reamer synchronization.

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Pilot Bit and Reamer Matching: Real-Time Downhole Data Differentiates Hybrid Drill Bit’s Suitability with Concentric Reamer in Deepwater, Gulf of Mexico Application

Chowdhury

Serrano

Rodrigue

2019

SPE/IADC International Drilling Conference and Exhibition

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High-Frequency at-Bit Measurements Provide New Insights into Torsional Dynamics When Drilling with Steerable Mud Motors in Unconventional Horizontal Wells

Wilson¹,

Whitacre²,

Heisig³

2019

SPE/IADC International Drilling Conference and Exhibition

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New insights into torsional BHA dynamics have been gained from high-frequency at-bit measurements when drilling with steerable mud motors in horizontal wells. Steerable mud motors are traditionally thought to decouple the bit from "sticking" as the BHA and drillstring are subject to torsional fluctuations. However, newly gathered data shows that the bit can actually come to a complete stop while the motor is forced into backwards rotation. Motor twist-offs and back-offs while drilling can be the costly consequence of such behavior. Using high-frequency, at-bit, measurements, dynamic and environmental characteristics of the bit were recorded in a dedicated bit sub at 200 Hz while drilling a horizontal well in the Granite Wash formation in the Texas Panhandle. The recorded variables include azimuthal-gamma, tri-axial accelerations, inclination, RPM, and temperature. Recorded data was examined, after each interval drilled, and correlated with standard MWD data (measured and recorded above the motor) as well as surface-recorded variables. Examination of the data revealed that the bit experienced full stick-slip behavior and, instead of being decoupled from the BHA as is traditionally thought, drove the BHA into backwards rotation via the action of the mud motor's power section. It is believed that, due to the tortuosity of the wellbore and the relative hardness of the formation being drilled, the lower end of the motor periodically "caught" and hung up while rotating, such that the negative driving torque generated in the power section (during the "bit-stick" intervals) loosened the connections below the motor's power section and ultimately led to back-offs of the connections downhole. This new high-frequency at-bit measurement tool has led to clear insights of the stick-slip behavior while drilling horizontal wells with steerable mud motors. As this new understanding contradicts traditional thinking of torsional oscillations in motor BHAs, the authors believe it is worth sharing with the industry as it can help prevent NPT related to this mechanism in the future.

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High-Frequency At-Bit Measurements Provide New Insights Into Torsional Dynamics When Drilling With Steerable Mud Motors in Unconventional Horizontal Wells

Wilson¹,

Whitacre²,

Heisig³

2019

SPE Drilling &Amp; Completion

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Summary New insights into torsional bottomhole-assembly (BHA) dynamics have been gained from high–frequency at–bit measurements when drilling with steerable mud motors in horizontal wells. Steerable mud motors are traditionally thought to decouple the bit from “sticking” as the BHA and drillstring are subject to torsional fluctuations. However, newly gathered data show that the bit can actually come to a complete stop while the motor is forced into the backward rotation. Motor twistoffs and back–offs while drilling can be the costly consequence of such behavior. Using high–frequency, at–bit measurements, dynamic and environmental characteristics of the bit were recorded in a dedicated bit sub at 200 Hz while drilling a horizontal well in the Granite Wash Formation in the Texas Panhandle. The recorded variables include azimuthal gamma, triaxial accelerations, inclination, revolutions per minute (RPM), and temperature. Recorded data were examined after each interval drilled, and correlated with standard measurement–while–drilling (MWD) data (measured and recorded above the motor), as well as surface–recorded variables. Examination of the data revealed that the bit experienced full stick/slip behavior and, instead of being decoupled from the BHA as is traditionally thought, drove the BHA into backward rotation by means of the action of the mud motor's power section. It is believed that, owing to the tortuosity of the wellbore and the relative hardness of the formation being drilled, the lower end of the motor periodically “caught” and was hung up while rotating such that the negative–driving torque generated in the power section (during the “bit–stick” intervals) loosened the connections below the motor's power section and ultimately led to back–offs of the connections downhole. This new high–frequency at–bit measurement tool has led to clear insights into the stick/slip behavior while drilling horizontal wells with steerable mud motors. Because this new understanding contradicts the traditional thinking of torsional oscillations in motor BHAs, the authors believe it is worth sharing with the industry because it can help prevent nonproductive time related to this mechanism in the future.

show abstract

Expert Real-Time Drilling Performance Prevents Twist-offs and Reduces Bit Damage in the Permian Basin

Cited by 3 publications

References 3 publications

Pilot Bit and Reamer Matching: Real-Time Downhole Data Differentiates Hybrid Drill Bit’s Suitability with Concentric Reamer in Deepwater, Gulf of Mexico Application

Pilot Bit and Reamer Matching: Real-Time Downhole Data Differentiates Hybrid Drill Bit’s Suitability with Concentric Reamer in Deepwater, Gulf of Mexico Application

High-Frequency at-Bit Measurements Provide New Insights into Torsional Dynamics When Drilling with Steerable Mud Motors in Unconventional Horizontal Wells

High-Frequency At-Bit Measurements Provide New Insights Into Torsional Dynamics When Drilling With Steerable Mud Motors in Unconventional Horizontal Wells

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