New PDC Technology Solves Challenging Directional Application in Saudi Arabia

Al-Hajji, Ali; Klink, Zeinoun; Khan, Salahuddin; Isbell, Matthew

doi:10.2118/85325-ms

Cited by 11 publications

(2 citation statements)

References 4 publications

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“…6 By adjusting the cutter exposure above the blade height, a bearing surface engages the formation and creates a rubbing surface at a specific ROP. As the ROP increases beyond this value, the bearing surface area enlarges rapidly, but the reactive torque continues to increase slowly and linearly.…”

Section: Docc Technologymentioning

confidence: 99%

Combined High-End Technologies Deliver Increased Efficiency in Low-Cost Drilling Environment: Case History in a Western Siberian Field

Lischuk¹,

Brown

Bakici

2005

All Days

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fax 01-972-952-9435. AbstractIn recent years, new technology has significantly improved the economics in high-cost drilling environments worldwide. In a western Siberian case, two service providers recently combined their technologies and operating procedures to yield reduced drilling costs and overall improved project economics. The service companies cooperated to produce the best results for the project and the customer. This paper describes a project in western Siberia, a welldeveloped, low-cost environment. Drilling performance had to be measurable and repeatable. The major challenge was to design a polycrystalline diamond compact (PDC) drillbit/mud-motor combination for use on Russian-made rigs to achieve performance improvement. Issues included tool face control, initial cost of PDC drill bits, and in-country rigs incapable of delivering adequate torque and hydraulic horsepower to the PDC bit.Applied technology included a new PDC bit designed for steerable motors in projects in which tool face control was a primary concern. The PDC bit was optimized for formation characteristics and motor capabilities by use of depth-of-cut control (DOCC) technology. This optimization reduced torque fluctuations that, in turn, increased tool face control while sliding and increased the rate of penetration (ROP) in rotary mode. Maximizing the benefit of the bit, a special motor was used that was capable of delivering high torque to allow consistently high ROP while maintaining trajectory control. This combination resulted in successful high-performance drilling.The objective was to complete intervals normally requiring several bits with a single bit run at higher average ROP. The results were indeed rewarding. There were 66% fewer trips per 8½-in. section, on average, compared to offset wells, in conjunction with a 37% reduction in drilling hours, equating to an ROP improvement of 27%. In spite of the additional cost of the PDC and high-torque motor, the system delivered the lowest cost per foot vs. the best offsets from three drilling pads examined. An important feature of the application was that the bit/motor combination was run on a risk/reward incentive program.

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Section: Docc Technologymentioning

confidence: 99%

Combined High-End Technologies Deliver Increased Efficiency in Low-Cost Drilling Environment: Case History in a Western Siberian Field

Lischuk¹,

Brown

Bakici

2005

All Days

View full text Add to dashboard Cite

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“…Specifically, the recent papers on reducing torque fluctuations with PDC bits have had a significant impact on utilization of these bits on rotary steerable systems. [2][3][4][5][6][7] Further progress has been made in recent years to mitigate/eliminate vibrations both at the bit and within the BHA. This work has made great strides to maintain stability while drilling even the most challenging formations.…”

Section: Introductionmentioning

confidence: 99%

A Fundamental Model for Prediction of Hole Curvature and Build Rates with Steerable Bottomhole Assemblies

Pastusek

Brackin

Lutes

2005

SPE Annual Technical Conference and Exhibition

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There are four key technical issues to be addressed when drilling directional wells with steerable bits and bottom hole assemblies: maximizing hole quality, addressing tool face control, eliminating bit and assembly vibration, and predicting hole curvature or build rates. Hole quality 1 and tool face control 2-7 have been covered in several previous SPE papers, as has bit and assembly vibration elimination 8-9 . This paper covers the recent development of a fundamental model for the prediction of hole curvature based on measured bit response and modeled bottom hole assembly behavior.

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Successful PDC/RSS Vibration Management Using Innovative Depth-of-Cut Control Technology: Panna Field, Offshore India

Jaggi¹,

Upadhaya²,

Chowdhury

2007

SPE/IADC Drilling Conference

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The operator has been active in Panna field for several years drilling a main horizontal and two laterals through a window milled in pre-existing 9–5/8″ casing. The laterals vary in length between 800m to 1600m, depending on the carbonate reservoir's constraints. However, interbedded formations with contrasting hardness had the potential to cause stick-slip and lateral vibration. Initially, the operator utilized RSS/MWD to geosteer the BHA within the target formation. However, previously chosen PDC bits caused severe lateral vibrations, stick slip and BHA whirl that resulted in multiple downhole tool failures. It appeared new PDC technology was required. An in-depth study revealed the BHA was exposed to severe stick-slip and lateral vibrations. There were also regular instances of BHA whirl and severe acceleration and deceleration caused by stick-slip. To enhance overall bit/BHA stability, a new-style 8–1/2″ PDC was implemented with innovative depth-of-cut control (DOCC) technology and enhanced stability features. BHA design was also reviewed and minor changes were implemented. The result was a significant reduction in stickslip, lateral vibration and BHA whirl. The new PDC/RSS set a new national Indian record for the longest 8–1/2" offshore section making 3956m of hole in a single run. The bit has since successfully drilled several multilateral drainholes in a single run proving the reliability of the new PDC design and enabling technology. The authors will present the vibration signature of a standard PDC versus the new one with DOCC. The authors will discuss proper RSS/PDC bit selection and demonstrate the benefit of DOCC/PDC on RSS when applied in high angle/horizontal wells. Introduction The Panna field1–3 is located in Arabian Sea about 95 km west of Mumbai, India (Figure 1). It is surrounded by other fields including Mukta, Neelam, Tapti and Bombay High. Together they constitute an important oil producing area of India. The Panna field is jointly owned by BG Exploration & Production India Limited (BGEPIL), who have a 30% holding, the Indian Government's Oil and Natural Gas Corporation Limited (ONGC) who maintain a 40% holding and Reliance Industries Limited (RIL) are partners with a 30% share. The field was discovered in 1977 and is estimated to have approximately one billion bbls of oil and 1.9 trillion cubic feet (tcf) of gas in place. Panna field produces from predominantly two carbonate reservoirs, including the upper A-zone (Oligocene) and lower B-zone (Middle Eocene). Overburden consists of argillaceous sediments of Chinchini, Tapti, Mahim and Bombay limestone followed by Alternations that lies directly on the A-zone reservoir (Figure 2). The Alternations horizon is between 70–100m thick and consists of thin interbedded shale and limestone formations of varying hardness. BGEPIL's current drilling campaign involves re-entering wells through a window milled in pre-existing 9–5/8″ casing to drill multiple fishbone laterals (Figure 3) through the reservoir section utilizing a rotary closed loop (RCLS) drilling system integrated with a resistivity, density and neutron porosity formation evaluation (FE) package (Figure 4). Application Challenges The initial horizontal wells in the Panna drilling campaign utilized steerable motors with LWD tools. However, this BHA experienced sliding difficulties that limited the extent of the horizontal reach. There were also drilling dynamics issues that caused severe tool damage on several occasions. Directional requirements/formation mineralogy while drilling the open-hole sidetrack in the 8–1/2″ horizontal section required the bit to deliver optimum dogleg severity without having an aggressive gauge as this may initiate hole spiraling and compromise wellbore quality and operational efficiency.

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New PDC Technology Solves Challenging Directional Application in Saudi Arabia

Cited by 11 publications

References 4 publications

Combined High-End Technologies Deliver Increased Efficiency in Low-Cost Drilling Environment: Case History in a Western Siberian Field

Combined High-End Technologies Deliver Increased Efficiency in Low-Cost Drilling Environment: Case History in a Western Siberian Field

A Fundamental Model for Prediction of Hole Curvature and Build Rates with Steerable Bottomhole Assemblies

Successful PDC/RSS Vibration Management Using Innovative Depth-of-Cut Control Technology: Panna Field, Offshore India

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