A Business Case for Drilling Automation: Well Cost Compression by Suppressing Downhole Tool Failure in Low Oil Market

2021 ◽  
Author(s):  
Danaparamita Kusumawardhani
Keyword(s):  
Comparative Method ◽  
Business Case ◽  
Stick Slip ◽  
Difficult Situation ◽  
Oil Market ◽  
Pdc Bit ◽  
Downhole Tool ◽  
Bottom Hole Assembly ◽  
Drilling Cost ◽  
Rock Interface

Abstract In a difficult situation where the oil market is down, reducing drilling cost is always an interesting outlook to be pursued. To do so, one should consider looking at the highest component on the drilling cost. Down-hole equipment failure and stuck pipe is avoidable during the engineering planning. It is well-known that billions of dollars have been lost and numerous Bottom-Hole Assembly (BHA) are left in the well due to such problems, related to stick-slip phenomenon. Thus, despite the low oil price, it is a new normal that some asset owners opt to invest on high-end tools to prevent stick-slip, meanwhile others are still reluctant because of its high initial costs and chose to solely focus on the technical skills to drill faster. The objective of this paper is to determine whether, and which, utilization of these automations will be an effective method to lower overall cost, between using Anti-Stick Slip Technology (AST), Surface soft-torque, Self-Adjusting PDC Bit or all three combined together. The analysis of this project is conducted by providing conjecture in comparative method to visualize the configuration. In each case, estimated Rate of Penetration (ROP) is observed based on the recent literature of its application in similar lithology which is carbonate and interbedded shale. As the ROP increases, the overall drilling cost along with percentage of potential net saving for each case is evaluated in this study and select the most effective strategy. The outturn suggests that despite the high initial investment, combining all technologies are economically advantaged. With the DOCC by the self-adjusting PDC bit and torque alleviation by AST to handle the rock interface in addition to BHA torque wave mitigation from surface by surface soft torque, the ROP is quantified as summation of all cases’ ROP gained as the tool complements each other. The estimated ROP of the case significantly gives high decrement of the overall cost and boosted the potential net saving. Moreover, prevention from NPT due to downhole failure and stuck pipe problem is also a contributing factor to increasing cost efficiency. Therefore, combining all the tool together is proven to be the most favorable option aside from, respectively from preferable to the less, utilizing Surface Soft Torque, Self-Adjusting PDC Bit, and AST. Although it requires high initial investment, it is worthwhile to explore the usage of automation technologies for the overall cost reduction contributes to make the case financially attractive.

Application Research on TorkBuster in Well Yashen 1 of Yumen Oilfield

2012 ◽  
Vol 591-593 ◽  
pp. 484-487
Author(s):  
Yi Gen Zeng ◽  
Zhong Liang Wei ◽  
Da Hong Liu
Keyword(s):  
Test Results ◽  
Application Research ◽  
Test Program ◽  
Stick Slip ◽  
Pdc Bit ◽  
Drilling Cost ◽  
Drilling Time ◽  
Slip Phenomenon

To the technical difficulties of slow ROP and low drilling efficiency in Silurian formation of Yumen Oilfield. After investigating on the ROP improvement technologies of domestic and abroad similar formation's characteristics, proposing a drilling test program of torsion and percussion in Silurian formation of Well Yashen 1. The test well section is 3753.00~4108.05m, the accumulative footage of TorkBuster is 355.05m, the actually drilling time is 208.35h, the average ROP is 1.70m/h. Compared with the offset well, the average ROP is up to 110%.The test results are shown that: TorkBuster eliminates the "stick-slip" phenomenon effectively when the bit cutting the formation, ensures the PDC bit continue to cut the formation effectively, cuts down the drilling cycle and saves the drilling cost. It provides a new guiding ideology to increase ROP in Cretaceous formation of Yumen Oilfield.

scholarly journals Kinematics and dynamics analysis of new rotary-percussive PDM drilling tool

2021 ◽  
pp. 146134842198915
Author(s):  
Jialin Tian ◽  
Xuehua Hu ◽  
Liming Dai ◽  
Lin Yang ◽  
Yi Yang ◽  
...  
Keyword(s):  
Drill String ◽  
Structure Design ◽  
Drilling Process ◽  
Analysis Model ◽  
Drilling Tool ◽  
Stick Slip ◽  
Rate Of Penetration ◽  
Bottom Hole ◽  
Bottom Hole Assembly ◽  
The Impact

This paper presents a new drilling tool with multidirectional and controllable vibrations for enhancing the drilling rate of penetration and reducing the wellbore friction in complex well structure. Based on the structure design, the working mechanism is analyzed in downhole conditions. Then, combined with the impact theory and the drilling process, the theoretical models including the various impact forces are established. Also, to study the downhole performance, the bottom hole assembly dynamics characteristics in new condition are discussed. Moreover, to study the influence of key parameters on the impact force, the parabolic effect of the tool and the rebound of the drill string were considered, and the kinematics and mechanical properties of the new tool under working conditions were calculated. For the importance of the roller as a vibration generator, the displacement trajectory of the roller under different rotating speed and weight on bit was compared and analyzed. The reliable and accuracy of the theoretical model were verified by comparing the calculation results and experimental test results. The results show that the new design can produce a continuous and stable periodic impact. By adjusting the design parameter matching to the working condition, the bottom hole assembly with the new tool can improve the rate of penetration and reduce the wellbore friction or drilling stick-slip with benign vibration. The analysis model can also be used for a similar method or design just by changing the relative parameters. The research and results can provide references for enhancing drilling efficiency and safe production.

scholarly journals Experimental Study on Axial Impact Mitigating Stick-Slip Vibration with a PDC Bit

2021 ◽  
Vol 2021 ◽  
pp. 1-8
Author(s):  
Yong Wang ◽  
Hongjian Ni ◽  
Yiliu (Paul) Tu ◽  
Ruihe Wang ◽  
Xueying Wang ◽  
...  
Keyword(s):  
Impact Force ◽  
Impact Load ◽  
Similarity Theory ◽  
Impact Frequency ◽  
Stick Slip ◽  
Axial Impact ◽  
Pdc Bit ◽  
Fluctuation Amplitude ◽  
Rotary Speed ◽  
The Impact

Stick-slip vibration reduces the drilling rate of penetration, causes early wear of bits, and threatens the safety of downhole tools. Therefore, it is necessary to study suppression methods of stick-slip vibration to achieve efficient and safe drilling. Field tests show that the use of downhole axial impactors is helpful to mitigate stick-slip vibration and improve rock-breaking efficiency. However, there are many deficiencies in the study of how axial impact load affects stick-slip vibration of a PDC bit. In this paper, based on the two-degrees-of-freedom spring-mass-damper model and similarity theory, a laboratory experiment device for suppressing stick-slip vibration of a PDC bit under axial impact load has been developed, and systematic experimental research has been carried out. The results show that the axial impact force can suppress the stick-slip vibration by reducing the amplitude of weight on bit and torque fluctuations and by increasing the main frequency of torque. The amplitude of impact force affects the choice of the optimal back-rake angle. The impact frequency is negatively correlated with the fluctuation amplitude of the rotary speed. When the impact frequency is greater than 100 Hz, the fluctuation amplitude of the rotary speed will not decrease.

Investigation of PDC bit failure base on stick-slip vibration analysis of drilling string system plus drill bit

2018 ◽  
Vol 417 ◽  
pp. 97-109 ◽  
Author(s):  
Zhiqiang Huang ◽  
Dou Xie ◽  
Bing Xie ◽  
Wenlin Zhang ◽  
Fuxiao Zhang ◽  
...  
Keyword(s):  
Vibration Analysis ◽  
Drill Bit ◽  
Stick Slip ◽  
Drilling String ◽  
Pdc Bit

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.

scholarly journals An Optimum Bits Selection for a Southern Iraqi Oil Field Located in Basra Region by Depending a New Algorithm

2013 ◽  
Vol 4 (3) ◽  
pp. 16-44
Author(s):  
Manar Ahmed Naser
Keyword(s):  
Oil Field ◽  
Oil Fields ◽  
Advantages And Disadvantages ◽  
Drilling Performance ◽  
Drill Bits ◽  
Optimum Selection ◽  
Surface Intermediate ◽  
Pdc Bit ◽  
Drilling Cost ◽  
Selection For

     Even drill bits cost are about 3-5% of the total drilling budget, but bits performance affects as much as 60% of the drilling cost[1] that would explain the necessity of continuous studying and developing this tool to improve drilling performance. Unfortunately, most of Iraqi oil fields managed by states companies does not give the proper attention for bits optimization issues, that would cause insufficient bits used to drill a certain formation due to the absence of a serious dealing with formation hardness and other bit selection criteria while designing, or making bits purchases contracts, or they would satisfy by a minimum rates of penetration. Unfortunately, the bit selection issue is matched the optimum selection for the drilling parameters issue, it is a matter of tri and error [2]. In this study, a southern Iraqi oil field located in Basra region have been selected to optimize the bits used to drill its wells. Summarizations of bits selection methods have been reviewed, advantages and disadvantages of possibility to applicant those methods in Basra regions have been introduced. A proper algorithm for selecting bits in Iraq was also presented. An economic evaluation for a different bit type's strategies used to drill holes of Mishrif wells in Basra oil fields region also discussed. This study improve that using bits holding the IADC code 425, M322 PDC bit with 6th blades and 16mm cutter size and M323 PDC bit with 5th blades and 6mm cutter size are the optimum selection to drill the surface, intermediate, and production holes consequently. This study is applicable to all Iraqi oil fields and especially for Basra region oil fields due to its large analogous on the lithology column and the drilling problems may combined the drilling operations among the different oil fields in this area.

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.

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.

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.

The Shaped PDC Cutter and Special Bit Element Utilization to Improve Overall Drilling Performance in Hard Massive Carbonate: A Case Study of ERD Horizontal Well In Offshore East Java, Indonesia

2021 ◽  
Author(s):  
I. Fajar
Keyword(s):  
Torsional Vibration ◽  
Slip Rate ◽  
Offshore Area ◽  
Drilling Performance ◽  
Carbonate Formation ◽  
Pdc Bit ◽  
Shape Selection ◽  
Medium Level ◽  
Downhole Tool ◽  
Strength Material

Drilling through hard massive carbonate formation combined with naturally induced torsional vibration due to bit-formation interaction is often resulting in unnecessary down time caused by downhole tool failures, sub-optimal drilling performance and extra trip to change out worn out bit. The torsional vibration is also well known as as stick and slip. To address the challenge, special PDC bit with advanced cutter technology were utilized in ERD well in Offshore East Java. The key focus when selecting the bit was on PDC cutter shape selection to improve drilling efficiency and utilization of higher strength material elements to improve stability and impact durability of the cutting structure critical in drilling hard and harsh rocks. The bit record, bit type configuration, QA/QC process, hydraulic & stability analysis and secondary cutter materials consideration were also specifically analysed when selecting this bit to improve bit performance further and ensure the bit could be repairable & reusable after being used. The first field run of the bit incorporating all this technology mentioned above was performed on last two (2) ERD well drilled in East Java Offshore area, at the 8.5in hole section with 7 bladed, 16mm cutter. The bit successfully drilled total of 3,029 ft interval through massive carbonate formation for both wells. The bit reached target depth without bit change. The bit had proven to reduce drilling torsional vibration stick & slip from severe to medium level. Both bit run also had set considerably remarkable slip-to-slip Rate of Penetration (ROP) for ERD wells category, which had significantly improved by 69.35% compared to previous ERD well drilled in same carbonate formation with ERD profile. When on surface, the bit was observed still in excellent condition for this application. The enhanced PDC bit selection had proven to enable drilling into more challenging torsional vibration induced formation in massive Carbonate formation and challenging ERD trajectory thus improving overall drilling performance and achieve actual rig time & cost saving compared to plan.

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