New PDC Technologies Increase Durability and Enable Faster Drilling in Hard/Abrasive Formation

Henry, Todd W.; Sherif, M.; Ragheb, Ahmed M.

doi:10.2118/148398-ms

Cited by 4 publications

(1 citation statement)

References 5 publications

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“…PDC bits possess high rock-breaking efficiency and long service life in soft to medium-hard formations. With the innovation of PDC cutter sintering technology and the in-depth research on the rock-breaking mechanism and impact toughness of shaped cutters, PDC bits also show advantages in hard formation [1,2]. According to the statistical results in 2015, PDC bits account for over 90% of global drilling footage [3].…”

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Forensic Analysis of PDC Bits at the Sinopec Shengli Oilfield

Li,

Han,

et al. 2023

J. Phys.: Conf. Ser.

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Polycrystalline diamond compact (PDC) bit has occupied more than 90% of the total drilling footage in the world. Forensic analysis of dull PDC bits is an important research field that can investigate multiple factors and then find the main failure cause. The findings of the forensic analysis not only guide the selection and placement of the next bit but also promote the advancement of PDC bits. In this study, the PDC bit pulled out of the hole was photographed, and then a forensic analysis was carried out. Based on the analysis of 45 dull PDC bits, the failure causes of PDC bits were divided into three categories: impact, wear, and erosion, which were further divided into ten sub-categories. The correlation between the failure forms and the position of the cutters on the bit tip profile was also investigated. The result shows that the front impact is the dominant failure cause of PDC bits at the Sinopec Shengli Oilfield, which often occurs at the nose and shoulder of the tip profile, while the failure caused by the tip impact is concentrated at the cutters near the OD (outside diameter) position. The results would assist the selection and deployment of the PDC bit.

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confidence: 99%

Forensic Analysis of PDC Bits at the Sinopec Shengli Oilfield

Li,

Han,

et al. 2023

J. Phys.: Conf. Ser.

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Effect of back rake angle and shape on wear rate of PDC cutter in hard formation

Adzis

Abdul-Rani

et al. 2018

AIP Conference Proceedings

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Solving Hard/Abrasive Sedimentary and Igneous Formation Challenge: New PDC Bit Design Reduces 6-in Section Drilling Time By 47%

Peytchev

Malik

Varghese

et al. 2013

SPE Asia Pacific Oil and Gas Conference and Exhibition

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The 6"hole section in Raageshwari Field NW India (onshore) is typically between 600-800m long and highly challenging in terms of formation strength and abrasiveness. Lithology in the upper part is composed of sandstone, claystone and weathered basalt with unconfined compressive strength (UCS) between 3-5kpsi. The lower section contains basalt, felsic and sub-felsic igneous formations with UCS range of 15-30kpsi. Historically, a two bit strategy was employed. First, a PDC bit on a positive displacement motor (PDM) bottom hole assembly was used to drill the soft 6" section until ROP dropped to an unacceptable level. The BHA was then pulled and followed by a diamond impregnated bit on a turbine BHA to drill the very hard volcanics. Typical average on-bottom ROP for the entire section was 4.5m/hr and took approximately 170 hours to reach total depth (TD). To reduce costs, new technology was proposed to improve bit durability in the hard/abrasive volcanics and drill the entire 6" section in one run at a higher ROP. Recent bit and drilling data from offset wells was analyzed to assist in developing a new, cost effective PDC design to replace the expensive diamond-impregnated bits and drill the 6" hole section in one run. The study resulted in a new six-bladed PDC bit with 13mm cutters that incorporates superior cutter technology to improve durability and resist physical and thermal degradation. The design includes a row of backup cutters in the shoulder area to increase radial diamond volume for maximum durability. The new PDC bits have been run on a motor and rotary steerable bottom hole assemblies and drilled the 6" section on three consecutive wells in Raageshwari field totaling 2328meters with an average ROP of 10.7m/hr. This represents approx. 47% decrease in drilling time compared to that previously achieved by Impreg/TCI bit runs. Typically, the new bits are pulled in re-runable condition. This improved performance has saved the operator approximately six-days of rig time and approximately USD 480,000/well.

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New PDC Technologies Increase Durability and Enable Faster Drilling in Hard/Abrasive Formation

Cited by 4 publications

References 5 publications

Forensic Analysis of PDC Bits at the Sinopec Shengli Oilfield

Forensic Analysis of PDC Bits at the Sinopec Shengli Oilfield

Effect of back rake angle and shape on wear rate of PDC cutter in hard formation

Solving Hard/Abrasive Sedimentary and Igneous Formation Challenge: New PDC Bit Design Reduces 6-in Section Drilling Time By 47%

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