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.

Intelligent Rotary Steerable System, Coupled with an Instrumented Bit, Delivers Section Plan in Deepwater GOM Project

2021 ◽  
Author(s):  
John Snyder ◽  
Graeme Salmon
Keyword(s):  
Intelligent Systems ◽  
Systems Approach ◽  
Polycrystalline Diamond ◽  
Cost Effective ◽  
Structure Design ◽  
Directional Drilling ◽  
Steering Control ◽  
Efficient System ◽  
Drilling Performance ◽  
Downhole Tool

Abstract The challenging offshore drilling environment has increased the need for cost-effective operations to deliver accurate well placement, high borehole quality, and shoe-to-shoe drilling performance. As well construction complexity continues to develop, the need for an improved systems approach to delivering integrated performance is critical. Complex bottom hole assemblies (BHA) used in deepwater operations will include additional sensors and capabilities than in the past. These BHAs consist of multiple cutting structures (bit/reamer), gamma, resistivity, density, porosity, sonic, formation pressure testing/sampling capabilities, as well as drilling dynamics systems and onboard diagnostic sensors. Rock cutting structure design primarily relied on data capture at the surface. An instrumented sensor package within the drill bit provides dynamic measurements allowing for better understanding of BHA performance, creating a more efficient system for all drilling conditions. The addition of intelligent systems that monitor and control these complex BHAs, makes it possible to implement autonomous steering of directional drilling assemblies in the offshore environment. In the Deepwater Gulf of Mexico (GOM), this case study documents the introduction of a new automated drilling service and Intelligent Rotary Steerable System (iRSS) with an instrumented bit. Utilizing these complex BHAs, the system can provide real-time (RT) steering decisions automatically given the downhole tool configuration, planned well path, and RT sensor information received. The 6-3/4-inch nominal diameter system, coupled with the instrumented bit, successfully completed the first 5,400-foot (1,650m) section while enlarging the 8-1/2-inch (216mm) borehole to 9-7/8 inches (250mm). The system delivered a high-quality wellbore with low tortuosity and minimal vibration, while keeping to the planned well path. The system achieved all performance objectives and captured dynamic drilling responses for use in an additional applications. This fast sampling iRSS maintains continuous and faster steering control at high rates of penetration (ROP) providing accurate well path directional control. The system-matched polycrystalline diamond (PDC) bit is engineered to deliver greater side cutting efficiency with enhanced cutting structure improving the iRSS performance. Included within the bit is an instrumentation package that tracks drilling dynamics at the bit. The bit dynamics data is then used to improve bit designs and optimize drilling parameters.

Casing While Drilling Application: Changing Mitigation to a Performance

2021 ◽  
Author(s):  
Alexey Ruzhnikov ◽  
Fahad AlHosni ◽  
Edgar Garnica Echevarria ◽  
Rodrigo Varela
Keyword(s):  
Extensive Study ◽  
Drilling Process ◽  
Wellbore Instability ◽  
Existing Problems ◽  
Drilling Performance ◽  
Geological Conditions ◽  
Pdc Bit ◽  
Low Torque ◽  
The Cost ◽  
A Performance

Abstract Well construction process through the unstable formations prone to total losses, pack-off and water influx is challenging. The manuscript describes the casing while drilling (CwD) combined with stage-cementing tool as introduced solution, when the challenge was to ensure that torque limit is not reached while drilling and estimate the effect of CwD on curing total losses and bring the casing while drilling performance to the level of conventional drilling. Introduction of CwD required extensive study of the potential torque while drilling as existing stage-cementing tools have low torque rating. Additionally, the casing fatigue may be a factor affecting the operations what lead to an introduction of magnetic particle casing inspection. The CwD bit design was adopted to the geological conditions based on best performance of the PDC bit, and originally selected drilling parameters were further optimized based on the result of the first runs. As the drilling of the well required utilization of mud cap for well control purposes, the mud recipes were adjusted to optimize the drilling performance and minimize the cost implication. The proposed solutions allowed to eliminate the problem with wellbore instability and related stuck pipe events. Further the proper engineering of the drilling process allowed significantly increase the rate of penetration since the beginning of the implementation, when the drilling torque never reached the limit even at 7,000 ft depth. The manuscript describes in detail the approach to make a proper design of CwD process focusing on prevention of existing problems and aiming to convert mitigation tool to a performance tool. Additionally, in details described the studied effect of CwD on curing total losses in highly fractured environment.

Integrated approach to drilling dynamics challenges in the Browse Basin

2012 ◽  
Vol 52 (2) ◽  
pp. 666
Author(s):  
Yezid Arevalo ◽  
Cathal O'Sullivan ◽  
Ashley Fernandes
Keyword(s):  
Real Time ◽  
Technology Implementation ◽  
Integrated Approach ◽  
Planning Stage ◽  
Time Dynamics ◽  
Drilling Performance ◽  
Planning Cycle ◽  
Downhole Tool ◽  
Using Data ◽  
Effective Use

The use of drilling dynamics measurements has traditionally focused on improving downhole tool reliability. This, however, is a limited scope and in recognition of this, drilling dynamics is approached as a process that starts early in the planning stage of a project and targets the performance of the complete drillstring. Failures or inefficiencies associated with drillstring dynamics continue to occur in spite of the sophistication of today's measurements, particularly in exploratory projects that extend the present drilling envelope. Several methodologies were integrated to address the challenges of drilling dynamics and overcome frequent failures observed on the initial exploratory work on the Browse Basin. A steep learning curve was achieved by accelerating the improvement cycle using advanced modelling techniques and obtaining optimum designs without the need of multiple trial and error cycles. This extended abstract also describes the use of real-time dynamics measurements to quantify the risks related to drillstring vibration, a critical need for the drilling environment observed in the basin that ties planning work into the execution stage. Finally, the project cycle is closed with the evaluation of drilling performance using data-handling tools that allow the effective use of large amounts of drilling data generated during the execution and feedback into a new planning cycle. The extended abstract describes the implementation of drilling dynamics modelling to assist performance improvement, but more importantly, the methodology to incorporate it into a real-time decision-making process that maximises the value of technology implementation.

Bit Dysfunction Characterization Using a Sensor System at the Bit

2007 ◽  
Author(s):  
Sorin G. Teodorescu ◽  
Eric C. Sullivan ◽  
Paul E. Pastusek
Keyword(s):  
Structural Integrity ◽  
Sensor System ◽  
Sensor Data ◽  
Drilling Performance ◽  
Rock Formations ◽  
Drill Bits ◽  
Pdc Bit ◽  
Recent Developments ◽  
Drilling Operations ◽  
Rock Bit

Drilling operations represent a major cost in discovering and exploring new petroleum reserves. Poor drilling performance, for example low ROP, can lead to high cost per foot. In order to optimize the performance of drill bits, the dynamic behavior of the bit and the drillstring has to be monitored. In recent developments, we have deployed a sensor / data acquisition (DAQ) system that is mounted at the bit, which can monitor the behavior of the drill bit and dynamic dysfunctions associated with the operating parameters, different rock formations and rock/bit interactions. A modified shank accommodates the sensor / DAQ system. Its location was determined based on extensive analysis of the bit’s structural integrity. Initial tests verified the ability of the system to identify PDC bit dysfunctions, such as backward whirl — one of the most bit damaging events in the drilling operation. Placing a sensor system in the bit allows for accurate pattern recognition and severity determination in terms of dynamic dysfunctions of the bit and can aid in optimizing drilling parameters in pursuit of increased ROP and reduced drilling costs.

Torsional Vibration Analysis of Drillstrings in Blasthole Drilling

2008 ◽  
Author(s):  
Omid Aminfar ◽  
Amir Khajepour
Keyword(s):  
Torsional Vibration ◽  
Natural Frequencies ◽  
Element Model ◽  
Drilling Process ◽  
Torsional Vibrations ◽  
Rotary Drilling ◽  
Well Drilling ◽  
State Response ◽  
Drilling Performance ◽  
Overall Performance

Reducing vibrations in well drilling has a significant effect on improving the overall performance of the drilling process. Vibrations may affect the drilling process in different ways, i.e., reducing durability of the drillstring’s elements, reducing the rate of penetration, and deviating the drilling direction. In rotary drilling, which is used to open mine and oil wells, torsional vibration of the drillstring is an important component of the overall system’s vibration that has received less attention in the literature. In this paper, we propose a finite element model for a sample blasthole drillstring used to open mine wells to investigate its torsional vibrations. Boundary conditions and elements’ specifications are applied to this model. In the model, the interaction between the insert and the rock is represented by a set of repetitive impulses according to the insert pattern. The steady-state response of the system to the repetitive impulses is found and natural frequencies, kinetic energy, and potential energy of the drillstring are calculated. The root mean square (RMS) of the total energy can be used as the measure for reducing the torsional vibration of the system. Finally, an optimum combination of inserts on the cone’s rows was found based on minimizing the total vibratory energy of the drillstring. The optimum design can reduce the torsional vibrations of the drillstring and improve the drilling performance.

scholarly journals Comparative analysis of drilling performance of kymera and PDC bits in salt formation

2020 ◽  
Vol 1 (2) ◽  
pp. 25-28
Author(s):  
Alaba O Clement
Keyword(s):  
Penetration Rate ◽  
Pearson Correlation ◽  
Salt Formation ◽  
Well Drilling ◽  
Drilling Performance ◽  
A Value ◽  
Pdc Bit ◽  
Measurement While Drilling ◽  
Logging While Drilling

The study compares the drilling performance of Kymera and PDC bits in salt formation using River and Delta State Continental Shelf of Nigeria as a case study. The measurement while drilling (MWD) and the logging while drilling (LWD) methods were used to measure the real time well drilling operation. well formation and drilling statistics. The data obtained from the Ogbaimbiri. Ossiomo. Utorogu and Okporhuftu wells have the penetration rate of 6.2 m/hr. 5.9 m/hr. 12.2 m/hr. 6.3 m/hr for Kymera bit and 4.2 m/hr. 3.4 m/hr. 6.8 m/hr. 3.9 m/hr for PDC bit respectively. The pearson correlation coefficient has a value of r = 0.897. n = 4. p<0.05 and r = 0.784. n = 4. p<0.05 for both kymera and PDC bits. The results established a strong and positive correlation between the penetration rate and distance drilled in each bit. It also shows that the higher the penetration rate the more the distance drilled by each bit. The study concluded that the Kymera bit was more efficient as it was able to penetrate the different formations with a lesser time and at a greater penetration rate.

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.

Hybrid Physics-Field Data Approach Improves Prediction of ROP / Drilling Performance of Sharp and Worn PDC Bits

2021 ◽  
Author(s):  
Guodong David Zhan ◽  
Arturo Magana-Mora ◽  
Eric Moellendick ◽  
John Bomidi ◽  
Xu Huang ◽  
...  
Keyword(s):  
Prediction Models ◽  
Collaborative Study ◽  
Hybrid Approach ◽  
Polycrystalline Diamond ◽  
Rock Properties ◽  
Quantitative Prediction ◽  
Model Learning ◽  
Drilling Performance ◽  
Pdc Bit ◽  
Polycrystalline Diamond Compact

Abstract This study presents a hybrid approach that combines data-driven and physics models for worn and sharp drilling simulation of polycrystalline diamond compact (PDC) bit designs and field learning from limited downhole drilling data, worn state measurements, formation properties, and operating environment. The physics models include a drilling response model for cutting forces, worn or rubbing elements in the bit design. Decades of pressurized drilling and cutting experiments validated these models and constrained the physical behaviour while some coefficients are open for field model learning. This hybrid approach of drilling physics with data learning extends the laboratory results to application in the field. The field learning process included selecting runs in a well for which rock properties model was built. Downhole drilling measurements, known sharp bit design, and measured wear geometry were used for verification. The models derived from this collaborative study resulted in improved worn bit drilling response understanding, and quantitative prediction models, which are foundational frameworks for drilling and economics optimization.

Quantifying PDC Bit Wear in Real-Time and Establishing an Effective Bit Pull Criterion Using Surface Sensors

2021 ◽  
Author(s):  
Ysabel Witt-Doerring ◽  
Paul Pastusek Pastusek ◽  
Pradeepkumar Ashok ◽  
Eric van Oort
Keyword(s):  
Real Time ◽  
Initial Point ◽  
Sensor Data ◽  
Data Set ◽  
Unit Distance ◽  
Drilling Performance ◽  
Pull Out ◽  
Bit Wear ◽  
Pdc Bit ◽  
Wear Indicator

Abstract It is useful during drilling operations to know when bit failure has occurred because this knowledge can be used to improve drilling performance and provides guidance on when to pull out of hole. This paper presents a simple polycrystalline diamond compact (PDC) bit wear indicator and an associated methodology to help quantify wear and failure using real-time surface sensor data and PDC dull images. The wear indicator is used to identify the point of failure, after which corresponding surface data and dull images can be used to infer the cause of failure. It links rotary speed (RPM) with rate of penetration (ROP) and weight-on-bit (WOB). The term incorporating RPM and ROP represents a "sliding distance", i.e. the number of revolutions required to drill a unit distance of formation, while the WOB represents the formation hardness or contact pressure applied by the formation. This PDC bit wear metric was applied and validated on a data set comprised of 51 lateral production hole bit runs on 9 wells. Surface electric drilling recorder (EDR) data alongside bit dull photos were used to interpret the relationship between the wear metric and observed PDC wear. All runs were in the same extremely hard (estimated 35 – 50 kpsi unconfined compressive strength) and abrasive shale formation. Sliding drilling time and off-bottom time were filtered from the data, and the median wear metric value for each stand was calculated versus measured hole depth while in rotary mode. The initial point in time when the bit fails was found to be most often a singular event, after which ROP never recovered. Once damaged, subsequent catastrophic bit failure generally occurred within drilling 1-2 stands. The rapid bit failure observed was attributed to the increased thermal loads seen at the wear flat of the PDC cutter, which accelerate diamond degradation. The wear metric more accurately identifies the point in time (stand being drilled) of failure than the ROP value by itself. Review of post-run PDC photos show that the final recorded wear metric value can be related to the observed severity of the PDC damage. This information was used to determine a pull criterion to reduce pulling bits that are damaged beyond repair (DBR) and reduce time spent beyond the effective end of life. Pulling bits before DBR status is reached and replacing them increases overall drilling performance. The presented wear metric is simple and cost-effective to implement, which is important to lower-cost land wells, and requires only real-time surface sensor data. It enables a targeted approach to analyzing PDC bit wear, optimizing drilling performance and establishing effective bit pull criteria.

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.

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