Specialized PDC Bit Improves Efficiency of Rotary Steering Drilling Tools in Demanding Directional Drilling Programs

2000 ◽  
Author(s):  
Graham Mensa-Wilmot ◽  
Krepp Tony ◽  
Richard Hill
Keyword(s):  
Directional Drilling ◽  
Drilling Tools ◽  
Pdc Bit

scholarly journals Rotary steerable systems: mathematical modeling and their case study

2021 ◽  
Vol 11 (6) ◽  
pp. 2743-2761
Author(s):  
Caetano P. S. Andrade ◽  
J. Luis Saavedra ◽  
Andrzej Tunkiel ◽  
Dan Sui
Keyword(s):  
Directional Drilling ◽  
Steering Control ◽  
Fundamental Physics ◽  
Drilling Tools ◽  
Drilling Operations ◽  
Beam Bending ◽  
Extended Reach Drilling ◽  
And Control ◽  
2D And 3D

AbstractDirectional drilling is a common and essential procedure of major extended reach drilling operations. With the development of directional drilling technologies, the percentage of recoverable oil production has increased. However, its challenges, like real-time bit steering, directional drilling tools selection and control, are main barriers leading to low drilling efficiency and high nonproductive time. The fact inspires this study. Our work aims to contribute to the better understanding of directional drilling, more specifically regarding rotary steerable system (RSS) technology. For instance, finding the solutions of the technological challenges involved in RSSs, such as bit steering control, bit position calculation and bit speed estimation, is the main considerations of our study. Classical definitions from fundamental physics including Newton’s third law, beam bending analysis, bit force analysis, rate of penetration (ROP) modeling are employed to estimate bit position and then conduct RSS control to steer the bit accordingly. The results are illustrated in case study with the consideration of the 2D and 3D wellbore scenarios.

Drill Bit Contact Dynamics Including Side Cutting: Simulation and Validation

2017 ◽  
Vol 139 (2) ◽  
Author(s):  
Alfonso Callejo ◽  
Siamak Arbatani ◽  
József Kövecses ◽  
Masoud Kalantari ◽  
Nick R. Marchand
Keyword(s):  
Experimental Validation ◽  
Contact Forces ◽  
Contact Dynamics ◽  
Specific Method ◽  
Directional Drilling ◽  
Simulation Framework ◽  
Finite Segment ◽  
Oil Drilling ◽  
Simulation Techniques ◽  
Drilling Tools

Simulation techniques are increasingly becoming popular in recent years as a way of simulating oil drilling processes. Among them, directional drilling is a specific method that benefits enormously from such numerical techniques, inasmuch as the estimation of the wellbore curvature is crucial and cannot be properly estimated through approximate geometry methods. We present here some of the latest advances in bit contact dynamics, wellbore update algorithms, and experimental validation of side cutting, in the context of a finite element (FE) and finite segment simulation framework. The framework is based on the high-fidelity dynamic simulation of the mechanical system, including detailed geometry, large displacements, and accurate contact forces. The theoretical aspects, along with the experimental results, are thoroughly presented. Overall, this paper constitutes a step toward a more deterministic way of calculating build rates and designing downhole drilling tools.

First Application of Hybrid Bit Technology to Optimize Drilling Through S Shape Directional Section with High Chert Content in UAE Land Operations

2021 ◽  
Author(s):  
Ygnacio Jesus Nunez ◽  
Munir Bashir ◽  
Fernando Ruiz ◽  
Rakesh Kumar ◽  
Mohamed Sameer ◽  
...  
Keyword(s):  
Good Condition ◽  
Polycrystalline Diamond ◽  
Steering System ◽  
Directional Drilling ◽  
Main Challenge ◽  
Drilling Parameters ◽  
Pdc Bit ◽  
Heterogeneous Formation ◽  
Polycrystalline Diamond Compact ◽  
Cutting Mechanisms

Abstract This paper highlights the solution, execution, and evaluation of the first 12.25″ application of hybrid bit on rotary steerable system in S-Shape directional application to drill interbedded formations with up to 25 % chert content in UAE land operations. The main challenge that the solution overcame is to drill through the hard chert layers while avoiding trips due to PDC bit damage nor drilling hour's limitation of TCI bit while improving the overall ROP and achieving the directional requirement. The solution package has demonstrated a superior ROP over rollercone bits, as well as improved PDC cutter durability and lower reactive torque leading to better steerability and stability which will be detailed in this paper. A significant contributor to such success was utilizing a new hybrid bit technology which incorporates the dual cutting mechanisms of both polycrystalline Diamond Compact (PDC) and rollercone bits. This allows a more efficient drilling by bringing the durability of the crushing action of rollercone to drill through hard interbedded lithology and the effectiveness of the shearing action of PDC cutters to improve ROP without sacrificing the toughness of the cutting structure edge. The proposed solution in combined with continues proportional rotary steering system managed to drill 4,670 ft through heterogeneous formation with chert nodules, with an average ROP of 38.29 ft\hr improving ROP by 15% and eliminating extra trips of utilizing roller cone bits to be able to drill though the chert nodules and avoid the PDC bit damage. Leading reduction in cost per foot by 35 %. Additionally, the hybrid bit exceed the expectation achieving 878 thousand of revolutions, with effective bearing and with the drilling cutting structure in a very good condition. Furthermore, the directional objectives were met with high quality directional drilling avoiding wellbore tortuosity. Such success was established through application analysis, specific formations drilling roadmaps and optimized drilling parameters in order to improve the overall run efficiency. The combination of roller cone and PDC elements in a hybrid bit designed to deliver better efficiency and torque stability significantly increased performance drilling the section in one single run, proven that heterogeneous formations can be drill.

Application of the Advanced Methods to Investigate Incidents and Drilling Engineering Principles to Prevent Critical Wear-Out of Downhole Equipment When Drilling Wells in Chayandinskoye Field

2021 ◽  
Author(s):  
Nikolay Valerevich Abaltusov ◽  
Anton Sergeevich Ryabov ◽  
Artem Evgenevich Perunov ◽  
Sergey Sergeevich Rublev ◽  
Sergey Aleksandrovich Mitrokhin ◽  
...  
Keyword(s):  
The Other ◽  
Problem Analysis ◽  
Directional Drilling ◽  
Expert Review ◽  
Incident Investigation ◽  
Risk Increase ◽  
Drilling Tools ◽  
Investigation Methods ◽  
Drilling Engineering ◽  
Equipment Wear

Abstract The pressing challenge is the abnormally rapid wear of well logging equipment and drilling tools when drilling wells in pay zone of Chayandinskoye field. Wear-out of BHA stabilizers within one run makes directional drilling inefficient and results in additional trips to replace equipment. Wear-out of drill pipes results in emergencies risk increase. To prevent such incidents the necessity arises to conduct an unscheduled inspection, reject and replace drilling tools. All these conditions entail increase in drilling time and decline in profitability. Problem analysis and expert review was made by drilling optimization specialists from DD Contractor jointly with the experts from R&D Center and Operator Company. This paper discusses how cooperation of the engineers from three companies as well as a particular approach to incident investigation and drilling engineering made it possible to identify the most critical factors, which contribute to a standard BHA wear, to work out measures to prevent similar situations in future and select an alternative BHA. The gained experience has been successfully disseminated to the other wells in Chayandinskoye field and other fields in Eastern Siberia; and the incident investigation methods and drilling engineering procedures are effectively applied under the other projects.

Simulation study of new directional drilling PDC bit used in coal mine

2016 ◽  
Vol 20 (3) ◽  
pp. 142-148 ◽  
Author(s):  
Rongjun Sun ◽  
Pei Ju ◽  
Zhijun Shi
Keyword(s):  
Simulation Study ◽  
Coal Mine ◽  
Directional Drilling ◽  
Pdc Bit

Field Tests on the Application of Oscillation Tool with a Fluidic Amplifier to Directional Well Drilling

2015 ◽  
Vol 741 ◽  
pp. 599-602
Author(s):  
Jiang Fu He ◽  
He Liu ◽  
Kun Yin ◽  
Xin Gan
Keyword(s):  
Flow Rate ◽  
Pressure Pulse ◽  
Field Tests ◽  
Test Results ◽  
Directional Drilling ◽  
Drilling Tool ◽  
Well Drilling ◽  
Operation Process ◽  
Drilling Tools ◽  
Drilling Technology

The directional well drilling technology is extensively utilized and developed throughout the world. However, series of drilling problems occurred in the operation process of directional drilling. In order to reduce the friction of drilling tools, an oscillation tool with a fluidic amplifier has been field tested, and the pressure pulse of oscillation tool has been obtained. Field test results have shown that the oscillation tool has an extensive flexibility to directional well drilling, and the oscillation tool could stably actuate the drilling tool to have reciprocating vibration, which contributes to the friction and drag reduction of drilling tools. Furthermore, it can be concluded that the pressure pulse value generated by pumped fluid varies with input flow rate, and the pressure of oscillation tool increases while the flow rate is increasing. In addition, the motion frequency of the oscillation tool is exponentially increasing with the raise of pumped flow rate.

Study of the Influence of Shale Anisotropy Orientation on Directional Drilling Performance in Shale

2017 ◽  
Author(s):  
Abdelsalam N. Abugharara ◽  
Charles A. Hurich ◽  
John Molgaard ◽  
Stephen D. Butt
Keyword(s):  
Depth Of Cut ◽  
Directional Drilling ◽  
Laboratory Procedure ◽  
Drilling Rig ◽  
Drilling Performance ◽  
Mechanical Measurements ◽  
Different Types ◽  
Pdc Bit ◽  
Weight On Bit ◽  
Shale Anisotropy

The influence of shale anisotropy orientation on shale drilling performance has been studied using a new laboratory procedure. This procedure includes drilling and testing three sets of shale samples in different orientations from a single rock sample. Shale samples of different types were collected from outcrops located at Conception Bay South (CBS) in Newfoundland, Canada. For predrilling tests, oriented physical and mechanical measurements on each type of shale were conducted on the same rocks that will be drilled later. For drilling tests, three sets of tests were conducted. Each set was in a different orientation, corresponding to those in the physical and mechanical measurements. Each set was conducted under the same drilling parameters of pressure, flow rate (FR), and weight on bit (WOB) using a fully instrumented laboratory scale drilling rig. Two different types of drill bits were used, including a 35 mm dual cutter PDC bit and a 25.4 mm diamond coring bit. The drilling data was analyzed by constructing relationships between drilling rate of penetration (ROP) versus orientation (i.e. 0°, 45°, or 90°). The analysis also included relationships between WOB and bit cutter Depth of Cut (DOC), Revolution Per Minute (RPM), and Torque (TRQ). All the above relations were evaluated as a function of shale bedding orientation. This evaluation can assist in understanding the influence of shale anisotropy on oriented drilling. Details of the conducted tests and results are reported.

First Non-Directional Casing While Drilling CWD Run in ADNOC Onshore Saves Five Days Rig Time and Improves the Well Construction Process Minimizing Associated Risks with Circulation Losses and Wellbore Instability

2021 ◽  
Author(s):  
Roswall Enrique Bethancourt ◽  
Mohammed Sarhan ◽  
Felix Leonardo Castillo ◽  
Imad Al Hamlawi ◽  
Luis Ramon Baptista ◽  
...  
Keyword(s):  
High Water ◽  
Drill String ◽  
Wellbore Stability ◽  
Abu Dhabi ◽  
Strengthening Effect ◽  
Directional Drilling ◽  
Rate Of Penetration ◽  
Well Integrity ◽  
Main Challenge ◽  
Pdc Bit

Abstract Loss of circulation while drilling the surface holes has become the main challenge in the Abu Dhabi Onshore developed fields. Typical consequences of losses are blind drilling and high instability of the wellbore that eventually led to hole collapse, drill string pack-offs and other associated well-integrity risks. Expensive operations including implementing aerated drilling technique, high water consumption and logistical constraints lead to difficulties reaching planned depth and running casing with added complexities of well integrity due to poor cement quality and bonding in the required isolation zones. Casing while drilling (CWD) is becoming a powerful method in mitigating both lost circulation as well as wellbore stability issues. This paper details the first 13 3/8″ × 16″ successful non-directional CWD trial accomplished in Abu Dhabi and the various advantages of the process. The Non-Directional CWD technology is used to drill vertical or tangent profiles with no directional drilling or logging (formation evaluation) requirements. The casing string is run with drillable body polycrystalline diamond cutters (PDC) bit and solid body centralizers are installed into the casing to achieve the required stand-off for cementing purpose. Some of the best practices applied to conventional drilling operations are not valid for CWD. The paper presents the methodology followed by the drilling engineers during the planning and preparation phases and presents a detailed description of the execution at the rig and the results of the evaluation including time savings, cement quality, rate of penetration, bottomhole assembly (BHA) directional tendency and losses comparison among others.The implementation of CWD saved the operator five days. The bit selection and fit-for-purpose bit design were critical factors for the success of the application. The interval was drilled (as planned) in one run through interbedded formations with a competitive rate of penetration (ROP). In this trial the interval consisted of 2,470ft with an average on-bottom ROP of 63.7 ft/hr, zero quality, health, safety and environmental (QHSE) incidents with enhanced safety for the rig crew.The technology eliminated the non-productive time (NPT) associated with tight spots, BHA pack-off, vibrations or stalls which it is an indication of good hole cleaning and optimum drilling parameters.Medium losses (10-15 BBL/hr) were cured due to the plastering and wellbore strengthening effect of CWD allowing drilling to resume with full returns.Well Verticality maintained with 0.3 degrees Inclination at section final depth.The drillable CWD bit was drilled out with a standard 12.25-in PDC bit in 1 hour as per the plan.

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