Setting a New Standard: PDC Bits Equipped with Compact Vibration Recorders Monitor Entire Run and Reveal Stick-Slip Mitigation System Dysfunction and Downhole Motor Under Performance

2021 ◽  
Author(s):  
Gilles Pelfrene ◽  
Bruno Cuilier ◽  
Dhaker Ezzeddine ◽  
Alfazazi Dourfaye ◽  
Dimo Dimov ◽  
...  
Keyword(s):  
Real Time ◽  
Cost Effective ◽  
Fine Tuning ◽  
Drill Bit ◽  
Stick Slip ◽  
Drilling Performance ◽  
Horizontal Drain ◽  
Monitoring Tools ◽  
Bottom Hole Assembly ◽  
Sensor Package

AbstractDownhole vibration measurements are used real-time and post-run to monitor drilling dynamics. Real-time monitoring tools are applied to facilitate immediate corrective actions but their deployment adds operational constraints and costs. This paper describes a new high-capability vibration recorder embedded in the drill bit as a standard component. The analysis of two case studies in the Middle East shows how memory devices available at a reduced cost and on every run are a valuable option for many appraisal or development wells.Developing a fleet of reliable downhole recording tools typically takes years and involves teams of experts in various fields. The paper describes the strategy followed by a drill bit manufacturer to develop and deploy a compact, high capability and cost-effective vibration recorder to provide continuous readings of accelerations, rotation speed (RPM) and temperature at 100Hz and over 250 hours. Sensors and batteries have been packaged to fit into the drill bit shank or elsewhere in the bottom hole assembly (BHA). The recording starts automatically and thus removes the need for onsite personnel. The paper also presents proprietary data analytics software used to retrieve, process and synchronize the recorded data with other available data (mud logs, Measurement/Logging While Drilling logs) and to present critical drilling events.In the first application, the 8 ½-in. bit drilled a 20,000 ft horizontal drain. More than 250 hr of data were recorded showing intense levels of stick-slip. During the entire run, the drilling team deployed several strategies to mitigate stick-slip, including the use of two surface-based stick-slip mitigation systems. The analysis shows that these systems are sometimes unsuccessful in mitigating stick-slip and are difficult to calibrate. It is demonstrated how the vibration recorder may contribute to fine tuning these mitigation efforts through optimization of their settings. In the second application, the vibration recorder was mounted on a 12 1/4-in. bit used to drill 5,000 ft through cement and formation. The analysis shows the motor was subjected to erratic RPM cycles, leading to frequent stalls and acceleration peaks during the run. It is shown how motor performance then decreased consistently during the last hundreds of feet of the section and how this affected rate of penetration (ROP).Deployment of a vibration recorder over the entire drill bit manufacturer's fleet allows continuous monitoring of critical drilling issues and malfunctions related to a variety of drilling equipment that enables the operator to improve drilling performance. The bit-sensor package makes high frequency data systematically available at a reduced cost for every drilling application.

Model Development of Torsional Drillstring and Investigating Parametrically the Stick-Slips Influencing Factors

2012 ◽  
Vol 135 (1) ◽  
Author(s):  
Parimal Arjun Patil ◽  
Catalin Teodoriu
Keyword(s):  
Nonlinear Differential Equations ◽  
Torsional Oscillation ◽  
Stick Slip ◽  
Friction Forces ◽  
Rock Interaction ◽  
Torsional Oscillations ◽  
Drilling Performance ◽  
Bottom Hole ◽  
Drilling Parameters ◽  
Bottom Hole Assembly

Drillstring vibration is one of the limiting factors maximizing drilling performance. Torsional vibrations/oscillations while drilling is one of the sever types of drillstring vibration which deteriorates the overall drilling performance, causing damaged bit, failure of bottom-hole assembly, overtorqued tool joints, torsional fatigue of drillstring, etc. It has been identified that the wellbore-drillstring interaction and well face-drill bit interaction are the sources of excitation of torsional oscillations. Predrilling analysis and real time analysis of drillstring dynamics is becoming a necessity for drilling oil/gas or geothermal wells in order to optimize surface drilling parameters and to reduce vibration related problems. It is very challenging to derive the drillstring model considering all modes of vibrations together due to the complexity of the phenomenon. This paper presents the mathematical model of a torsional drillstring based on nonlinear differential equations which are formulated considering drillpipes and bottom-hole assembly separately. The bit–rock interaction is represented by a nonlinear friction forces. Parametric study has been carried out analyzing the influence of drilling parameters such as surface rotations per minute (RPM) and weight-on-bit (WOB) on torsional oscillations. Influences of properties of drillstring like stiffness and inertia, which are most of the times either unknown or insufficiently studied during modeling, on torsional oscillation/stick-slip is also studied. The influences of different rock strength on rate of penetration (ROP) considering the drilling parameters have also been studied. The results show the same trend as observed in fields.

Hybrid Drill Bit Technology on Performance Motor Bottom Hole Assembly Yields Breakthrough Drilling Performance in Kuwait

2019 ◽  
Author(s):  
Waleed Al-Baghli ◽  
Mohammad Al-Salamin ◽  
Sulaiman Sulaiman ◽  
Atef Abdelhamid ◽  
Ali Alnemer ◽  
...  
Keyword(s):  
Drill Bit ◽  
Drilling Performance ◽  
Bottom Hole ◽  
Bottom Hole Assembly

Real-Time Lookahead Imaging Using the Drill Bit as Seismic Source

2021 ◽  
Author(s):  
Alexander Valentin Goertz ◽  
Tatiana Thiem ◽  
Endre Vange Bergfjord ◽  
Audun Libak ◽  
Brian Atkinson ◽  
...  
Keyword(s):  
Real Time ◽  
Seismic Source ◽  
Seismic Signal ◽  
Drill Bit ◽  
The North ◽  
Look Ahead ◽  
Imaging Results ◽  
Pdc Bit ◽  
Well Trajectory ◽  
Bottom Hole Assembly

Abstract We monitor the seismic signal emitted from a rotating drill bit in real time with an array of seismic sensors at the seafloor. Drill-bit seismic signals provide information to locate the drill-bit position itself and to image geological objects ahead and around the drill bit for geosteering purposes during drilling operations. The data can be obtained in real time without the need to stop drilling for logging and without any additional downhole instrumentation in the bottom hole assembly. Drill-bit positioning accuracy is independent of measured depth and with meter level lateral precision. This is significantly better than conventional downhole gyro-based methods, especially for long horizontal wells. With sources along the drilled well path approaching a target reservoir we obtain a 3D reverse VSP (RVSP) image around the well for prediction ahead of the drill bit. This paper presents a case study from the Grane reservoir in the North Sea, where we utilize a permanent reservoir monitoring (PRM) array for listening to signals emitted from drilling with a PDC bit. We present imaging results from a highly deviated well and compare them to 3D seismic. The field example shows the ability to look ahead several hundreds of meters below the drilled well trajectory.

Stick-slip investigation of dual drilling and reaming bottom hole assembly

2021 ◽  
pp. 095440622110184
Author(s):  
Mohammed F Al Dushaishi ◽  
Mortadha T Alsaba ◽  
Ahmed K Abbas ◽  
Tariq Tashtoush
Keyword(s):  
Field Studies ◽  
Drill Bit ◽  
Coupled Vibration ◽  
Stick Slip ◽  
Premature Failure ◽  
Bottom Hole ◽  
Vibration Model ◽  
Dual Action ◽  
Bottom Hole Assembly ◽  
Element Approach

Drillstring vibration is known to cause failures of drilling equipment, including the drill bit. In particular, stick-slip vibration has been known for causing premature failure of the drill bit, hence resulting in reducing the rate of penetration. With dual reaming while drilling, cutting forces are acting on the drillstring due to the simultaneous contact of the reamer and the drill bit. Field studies have shown dramatic changes in the dynamics of the bottom hole assembly due to the dual cutting actions. This paper investigates the dynamics of bottom hole assembly for dual reaming and drilling operation, with emphasis on stick-slip vibrations due to the reamer and the bit contact with the formation. A coupled vibration model representing the drillstring was created to simulate the stick-slip vibrations caused by the bit and reamer interactions using the finite element approach. The numerical analysis showed an elevated stick-slip vibration due to the dual-action of the reamer and the bit. Sensitivity analysis indicated that the cutter aggressiveness for the bit and the reamer are the most significant parameters affecting stick-slip behavior.

scholarly journals Real-time monitoring of driver drowsiness on mobile platforms using 3D neural networks

2019 ◽  
Vol 32 (13) ◽  
pp. 9731-9743 ◽  
Author(s):  
Jasper S. Wijnands ◽  
Jason Thompson ◽  
Kerry A. Nice ◽  
Gideon D. P. A. Aschwanden ◽  
Mark Stevenson
Keyword(s):  
Real Time ◽  
Three Dimensional ◽  
Cost Effective ◽  
Smartphone Application ◽  
Fine Tuning ◽  
Detection Methods ◽  
Crash Risk ◽  
Real Time Monitoring ◽  
Drowsiness Detection ◽  
Driver Drowsiness

Abstract Driver drowsiness increases crash risk, leading to substantial road trauma each year. Drowsiness detection methods have received considerable attention, but few studies have investigated the implementation of a detection approach on a mobile phone. Phone applications reduce the need for specialised hardware and hence, enable a cost-effective roll-out of the technology across the driving population. While it has been shown that three-dimensional (3D) operations are more suitable for spatiotemporal feature learning, current methods for drowsiness detection commonly use frame-based, multi-step approaches. However, computationally expensive techniques that achieve superior results on action recognition benchmarks (e.g. 3D convolutions, optical flow extraction) create bottlenecks for real-time, safety-critical applications on mobile devices. Here, we show how depthwise separable 3D convolutions, combined with an early fusion of spatial and temporal information, can achieve a balance between high prediction accuracy and real-time inference requirements. In particular, increased accuracy is achieved when assessment requires motion information, for example, when sunglasses conceal the eyes. Further, a custom TensorFlow-based smartphone application shows the true impact of various approaches on inference times and demonstrates the effectiveness of real-time monitoring based on out-of-sample data to alert a drowsy driver. Our model is pre-trained on ImageNet and Kinetics and fine-tuned on a publicly available Driver Drowsiness Detection dataset. Fine-tuning on large naturalistic driving datasets could further improve accuracy to obtain robust in-vehicle performance. Overall, our research is a step towards practical deep learning applications, potentially preventing micro-sleeps and reducing road trauma.

Offset Data Analysis and Seam Less Execution Through Real Time Monitoring Results in Step Change in Drilling Performance

2021 ◽  
Author(s):  
Singh Anurag Yadav ◽  
Imran Muhammad Chohan
Keyword(s):  
Real Time ◽  
Step Change ◽  
Management Tool ◽  
Oil Well ◽  
Optimization Approach ◽  
Real Time Monitoring ◽  
Stick Slip ◽  
Gas Drilling ◽  
Drilling Performance ◽  
Bottom Hole

Abstract In oil and gas drilling, consistency of performance delivery heavily depends upon rig capability and its ability to maintain performance assurance through its execution cycle. It's not an uncommon occurrence that a rig is found with an underperforming top drive, one such scenario was observed in an in-fill oil well drilling project. This project was essentially drilling horizontal wells with bottom hole assemblies which had primary drive mechanism as a top drive. The rig in question was struggling to provide not only the requisite RPM but also not been able to deliver consistent torque needed to drill the well. This study analyzes how severe rig limitations were overcome through an optimization plan in which most optimal BHA was designed and drilling practices were customized for safe and successful execution of wells. In order to understand root cause of the challenge, an offset well analysis was conducted, it identified that high torque was mostly generated while drilling through inter-bedded formations which typically caused top drive to stall. In addition, multiple tool failures were encountered due to the high stick slip which rig couldn't mitigate due to the low RPM yield of the top drive. To manage the rpm and torque limitations, a motorized RSS BHA was designed as a solution. Further, based on micro-stall events of motor only BHA's across the inter-bedded formations in the field, a stick slip management tool was placed below the motor so that a potential twist-off and/or motor damages can be avoided. Also, different bottom hole assembly's drilling dynamics response were analyzed to come up with optimal stabilization and connection practices to avoid back reaming while trip outs. This paper would showcase actual results which highlight improvements achieved in stagnant drilling performance of the project. The analysis would demonstrate how multiple wells were drilled in one run following the risk assessment developed from the optimization study and subsequent real time monitoring of mitigating actions while execution. The comprehensive bottoms-up drilling optimization approach helped save 4 planned days for each well, this really paves way to pursue applied-engineering solutions to achieve step change in drilling performances, especially on rigs which are severely limited either due to capacity or malperformance issues. The bottoms up approach taken to understand the drilling challenges followed by a methodical approach to address each of the challenges demonstrate importance of effective pre-job planning. Learnings from this study can be adopted as a template to mitigate similar drilling challenges.

Deployment of Downhole Mechanics Measurement System and Drilling Dynamics Modelling to Enhance Overall Drilling Performance Under Complete Mud Losses Environment

2021 ◽  
Author(s):  
Edgar Echevarria Garnica ◽  
Gustavo Alves Moreira ◽  
Alexey Ruzhnikov
Keyword(s):  
Real Time ◽  
Drilling Performance ◽  
Real Time Measurement ◽  
Local Practices ◽  
Expected Performance ◽  
Weight On Bit ◽  
Bottom Hole Assembly ◽  
Low Levels ◽  
Performance Results ◽  
Drilling Time

Abstract Drilling surface 16-in. and 12.25-in. sections in Middle East often accomplished by complete mud losses where downhole dynamic changed completely. To increase the performance and reduce drilling time the Positive Displace Motors (PDM) are used, however drilling under complete mud losses scenario may lead to a failure of the PDM, Measure While Drilling (MWD) tool, jar and any other components of the Bottom Hole Assembly (BHA). This manuscript describes the study of BHA dynamic in total loss scenario aiming to increase Rate of penetration (ROP) and decrease mechanical failures. The changing in drilling dynamics under complete mud losses increases the severity of shock and vibrations (S&V), BHA whirl and, consequently, leads to downhole failures. Local practices have been used to control this risk by taking an over conservative approach, limiting Weight on Bit (WOB) and Revolution per Minute (RPM) to very low levels, affecting overall performance. To comprehensively understand the level of shock and vibrations under complete mud losses based on the modeled data, a Downhole Mechanics Measurement (DMM) system was used in the BHA to acquire the required data in real time to confirm and further improve the modeling of drilling dynamics. A drilling schedule with several combinations of WOB and RPM was developed to cover the full drilling envelop. This study provided valuable understanding on the drilling dynamics while drilling under complete mud losses and allowed to clearly define the limiting boundaries to optimize ROP without jeopardizing the mechanical integrity of the BHA, particularly the PDM and drilling jar. On each formation drilled, RPM, WOB were changed to cover all possible combinations and, using the continuous real time measurement, ROP was optimized based on the level of shocks and vibrations experienced. Furthermore, the recorded mode Low and High-frequency data enabled to model the drilling dynamics and to quantify the effects of shocks and vibrations on the BHA. As a result, the wells have been drilled with significant ROP improvement (saving one day per run) and without downhole failures, achieving higher than expected performance results.

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