Drilling Automation – Benefits of the New Drilling Model

2021 ◽  
Author(s):  
Jorge Heredia ◽  
Jan Egil Tengesdal ◽  
Rune Hobberstad ◽  
Julien Marck ◽  
Harald Kleivenes ◽  
...  
Keyword(s):  
Conventional Method ◽  
Three Dimensional ◽  
Cost Savings ◽  
Work Force ◽  
Directional Drilling ◽  
Well Performance ◽  
Human Errors ◽  
Drilling Performance ◽  
Friction Factors ◽  
Remote Operations

Abstract A pilot program for automated directional drilling was implemented as a part of the roll out plan in Norway to drill three dimensional wells in an automated mode, where steering commands were carried out automatically by the automation platform. The rollout plan also targeted the use of remote operations to allow personnel to be relocated from the rig location into remote drilling centers. The goal of the program was to optimize the directional drilling performance by assessing the benefits of automation using the latest rotary steerable system technologies and machine learning smart algorithms to predict and manipulated the BHA performance, as well as the ability to predict the best drilling parameters for hole cleaning. The automation was implemented on three different rigs and the data was compared with the drilling performance from the last two years, with three dimensional wells drilled in the conventional method. The main benefits between drilling wells in the conventional method versus drilling wells with the new drilling automation model include the following. Reduce the overall cost per meter –  Improve the rate of penetration –  Improve running casings Consistence process adherence –  Reduce human errors –  Reduce POB without sacrificing lost of technical experience Optimize workforce resources –  Allows continuity of service (COVID-19 restrictions) Drilling automation can drill smoother wells by reducing the friction factors and tortuosity. This is translated in direct cost savings per meter and reduction in the overall well delivery time, with the advantage of performing the execution and monitoring of the well performance remotely. This new drilling model open the door of new opportunities, especially for the challenges where the work force resources, and drilling performance is a priority for the operations.

New Intelligent Push-the-Bit Rotary Steerable System Helped Reducing Well Time and Maximized Directional Drilling Performance, Abu Dhabi, UAE

2021 ◽  
Author(s):  
Saif Al Arfi ◽  
Fatima AlSowaidi ◽  
Fernando Ruiz ◽  
Ibrahim Hamdy ◽  
Yousef Tobji ◽  
...  
Keyword(s):  
Real Time ◽  
Oil And Gas ◽  
Service Providers ◽  
Directional Drilling ◽  
Cruise Control ◽  
Time Data ◽  
Human Errors ◽  
Drilling Performance ◽  
Oil And Gas Fields ◽  
Gas Market

Abstract To meet the current oil and gas market challenges, there is an industry need to optimize cost by safely drilling longer horizontal wells to maximize well productivity. Drilling challenges include the highly deviated trajectory that starts from the surface sections and wellhead, the high DogLeg Sevirity (DLS) profile with collision risks, and the thin complex geological structures, especially in new unconventional fields where numerous geological and geomechanical uncertainties are present. To mitigate for those challenges, reviewing the existing drilling techniques and technologies is necessary. To compete in the current Hi-Tech and Automation era, the main challenges for directional drilling service providers are to reduce well time, place wells accurately, and improve reliability, reducing repair and maintenance costs and helping the customer reduce time and costs for the overall project. Offset wells analysis and risk assessments allowed identifying the main challenges and problems during directional drilling phases, which were highlighted and summarized. As a proposed solution, the new generation of intelligent fully rotating high dogleg push-the-bit rotary steerable system has been implemented in the UAE onshore oil and gas fields to improve the directional drilling control and the performance. This implementation reduced the Non-Productive time (NPT) related to the human errors as the fully automation capabilities were being utilized. The new rotary steerable system has the highest mechanical specs in the market including self-diagnosis and self-prognosis through digital electronics and sophisticated algorithms that monitor equipment health in real-time and allow for managing the tool remotely. As a result, the new intelligent RSS was implemented in all possible complex wellbore conditions, such as wells with high DLS profile, drilling vertical, curve, and lateral sections in a single trip with high mud weight and high solid contents. Automation cruise control gave the opportunity to eliminate any well profile issues and maintain the aggressive drilling parameters. Using the Precise Near-bit Inclination and Azimuth and the At-Bit Gamma real-time data and high-frequency tool face measurements in the landing intervals where required for precise positional control to enable entering the reservoir in the correct location and with the correct attitude helping the customer's Geology and Geophysics department to place wells accurately while maintaining a high on bottom ROP.

Autonomous Directional Drilling Planning and Execution Using an Industry 4.0 Platform

2021 ◽  
Author(s):  
Samba BA ◽  
Maja Ignova ◽  
Kate Mantle ◽  
Adrien Chassard ◽  
Tao Yu ◽  
...  
Keyword(s):  
Industry 4.0 ◽  
System Level ◽  
Directional Drilling ◽  
Drilling Performance ◽  
Automated Evaluation ◽  
Drilling Operations ◽  
Working Plan ◽  
Rich Data ◽  
Remote Operations ◽  
Intelligent Planning

Abstract Today, directional drilling is considered a mix between art and science only performed by experts in the field. In this paper, we present an autonomous directional drilling framework using an industry 4.0 platform that is built on intelligent planning and execution capabilities and is supported by surface and downhole automation technologies to achieve consistently performing directional drilling operations accessible for easy remote operations. Intelligent planning builds on standard planning activities that are needed for directional drilling applications and advances them with rich data pipelines that feed predictive and prescriptive machine-learning (ML) models; this enables more accurate BHA tendencies, operating parameters, and trajectory plans that ultimately reduce executional risk and uncertainty. Intelligent execution provides technologies that facilitate decision-making activities, whether they be from the wellsite or town, by leveraging the digital-drilling program that is generated from the intelligent planning activities. The program connects planning expectations, real-time execution data from the surface and downhole equipment, and generates insights from data analytics, physics-based simulations, and offset analysis to achieve consistent directional drilling performance that is transparent to all stakeholders. This new framework enables a self-steering BHA for directional drilling operations. The workflow involves an automated evaluation of the current bit position with respect to the initial plan, automated evaluation of the maximum dogleg capability of the BHA, and the capability to examine the health of the BHA tools and, if needed, an automated re-planning of an optimized working plan. This is accomplished on a system level with interdependencies on the different elements that make up the complete workflow. This new autonomous directional drilling framework will minimize operational risk and cost-per-foot drilled; maximize performance, procedural adherence, and establish consistent results across fields, rigs, and trajectories while enabling modern remote operations.

Block 61 Drilling Fluids Optimization Journey

2021 ◽  
Author(s):  
Majda Jan Mohammad ◽  
Muneer Al Noumani ◽  
Iain Cameron ◽  
Younis Al Masoudi
Keyword(s):  
Cost Saving ◽  
Continuous Improvement ◽  
Cost Savings ◽  
Cost Benefit ◽  
Drilling Fluids ◽  
Well Performance ◽  
Drilling Performance ◽  
Delivery Times ◽  
Wellbore Strengthening ◽  
The Cost

Abstract BP operates Khazzan & Ghazeer fields in the Sultanate of Oman with the aim to deliver safe, reliable and efficient wells. Efficiencies within drilling fluids design form part of a greater continuous improvement cycle to well delivery cost. With fluids spend contributing to a significant portion of the executed well cost (typically 15 % in Oman), fluids design changes hold the potential to yield positive cost savings (where well performance is maintained). This paper presents the areas of fluids design which were explored to reduce fluids spend as part of the continuous improvement cycle. Combined, the changes to fluids design evolved to reduce the fluids cost of Barik vertical wells to 6% of total well cost. All avenues of fluids design and the costs associated with the fluids operation in Oman were viewed as being in scope for change to maintain overbalance hydrostatic pressure on fluids spend. The methodology employed to reduce fluids spend can be described in four steps as per continuous improvement roadmaps; identify the cost saving project, the key enablers which allow the cost saving to be realized, risk/reward analysis where low risk/high reward projects were accelerated as priority and placed to the front of the queue for field trial and where a trial outcome is positive, the change is introduced permanently to the operation. This process worked well in continuously pushing fluid performance and reducing the fluids spend in Oman. The scope of change to fluids design was wide, with each ‘value adding project’ providing its own cumulative cost benefit. The projects which contributed to significantly reducing the overall fluids spend in Oman focused on personnel, fluid type selection, fluids formulation optimization, wellbore strengthening, fluid consumption and recycling, drilling fluids practice and brine selection. Reductions in fluids spend were accompanied with an improved well performance. Well delivery times being continuously observed to improve throughout the campaign (63 days vs 42 days). Whilst the fluids design is not directly responsible for this outcome, it does highlight that the changes made to fluids design positively influenced the improved well delivery performance. The drilling fluids optimization initiatives resulted in significant time and cost saving thus reduction in overall Barik vertical well drilling cost. Drilling fluids cost is reduced by over 55% without impact on safety and drilling performance.

Bottom Hole Assembly Design Enhancement Successfully Eliminate Hole Problems and Reduce Significant Drilling Time : South S Field Case Study

2020 ◽  
Author(s):  
Y. D. Mulia
Keyword(s):  
Contact Area ◽  
Cost Savings ◽  
Assembly Design ◽  
Drilling Performance ◽  
Bottom Hole ◽  
Unconsolidated Sand ◽  
Bottom Hole Assembly ◽  
Drilling Parameter ◽  
Drilling Time

For S-15 and S-14 wells at South S Field, drilling of the 12-1/4” hole section became the longest tangent hole section interval of both wells. There were several challenges identified where hole problems can occur. The hole problems often occur in the unconsolidated sand layers and porous limestone formation sections of the hole during tripping in/out operations. Most of the hole problems are closely related to the design of the Bottom Hole Assembly (BHA). In many instances, hole problems resulted in significant additional drilling time. As an effort to resolve this issue, a new BHA setup was then designed to enhance the BHA drilling performance and eventually eliminate hole problems while drilling. The basic idea of the enhanced BHA is to provide more annulus clearance and limber BHA. The purpose is to reduce the Equivalent Circulating Density (ECD,) less contact area with formation, and reduce packoff risk while drilling through an unconsolidated section of the rocks. Engineering simulations were conducted to ensure that the enhanced BHA were able to deliver a good drilling performance. As a results, improved drilling performance can be seen on S-14 well which applied the enhanced BHA design. The enhanced BHA was able to drill the 12-1/4” tangent hole section to total depth (TD) with certain drilling parameter. Hole problems were no longer an issue during tripping out/in operation. This improvement led to significant rig time and cost savings of intermediate hole section drilling compared to S-15 well. The new enhanced BHA design has become one of the company’s benchmarks for drilling directional wells in South S Field.

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.

Three-Dimensional Microfabrication System for Biodegradable Microdevices With High-Resolution and Bio-Applicability

2005 ◽  
Author(s):  
Akira Yamada ◽  
Fuminori Niikura ◽  
Koji Ikuta
Keyword(s):  
Tensile Strength ◽  
Biodegradable Polymers ◽  
Conventional Method ◽  
Three Dimensional ◽  
Single Layer ◽  
Batch Process ◽  
Potential Applications ◽  
A Cell ◽  
The One ◽  
Almost All

Biodegradable polymers are employed in medicine and its further application is expected with eagerness. But the lack of an appropriate processing method retards the progress. To overcome this problem, we have developped a novel three-dimensional microfabrication system. The system design allows us the processing of the free three-dimensional micro-level forms by stacking up melted polymers from the nozzle. Different from the conventional method, we adopted a batch process to supply materials in order to eliminate the prior process that required toxic solvents. In addition, it is possible to handle almost all biodegradable thermoplastic resins by adopting this system. A single layer from the piled-up layers of extruded lines was observed to evaluate the resolution. The lateral and depth resolutions attained are 40 μm and 45 μm, respectively. Biodegradable polymers enable three-dimensional microstructures such as micro-pipes, micro-bends, and micro-coil springs to be manufactured in less than 15 min. The biocompatibility of the newly fabricated structure was evaluated using a cell line (PC12). For this purpose, a small vessel, with a transparent base, was fabricated using PLA and cells were cultivated in it. The results were then compared with the results obtained using the standard method. The mechanical strength of our microstructures was evaluated using a tensile strength test. The tensile strength of the microstructure was lower than the one obtained from the conventional method, but has enough strength for fabrication of medical devices. Our system renders it possible to produce toxic-free, as well as transparent and leakage-free devices. Our system is expected to have potential applications in optimum design and fabrication of implantable devices, especially in tissue engineering.

scholarly journals Identification of RBC and WBC Count in Human Blood Using ARM Based Instrumentation

2015 ◽  
Vol 11 (1) ◽  
pp. 145-150
Author(s):  
B. Basavanagoud ◽  
K. Priya
Keyword(s):  
Conventional Method ◽  
High Speed ◽  
Low Cost ◽  
Blood Analysis ◽  
Medical Sciences ◽  
Accurate Analysis ◽  
Human Errors ◽  
Arm Processor ◽  
Wbc Count ◽  
Human Fluids

The rapid growth in microelectronics and crunching RISC in the field of bio-medical sciences incorporated of soft tools to diagnose various parameters of human fluids. Conventional method of blood sample analysis makes use of laboratory technique of titration, which is operator-dependent and results in lot of errors depending on the skill of the technician. In order to eliminate the human errors involved in the conventional method, in this paper an attempt has been made to present a capillary centrifuge technique driven by high speed DC motor fed by Morgan chopper and controlled by powerful ARM processor. It results in accurate analysis of the blood samples. The various techniques involved in accurate sensing of speed using timer and generation of firing pulses to thyristor in the Morgan chopper is judiciously achieved. This paper clearly brings out the advantages of the proposed blood measurement technique which effectively gives blood analysis faster and at a low cost.

Pushing the Limits in Offshore Mexico

2021 ◽  
Author(s):  
Hector Hugo Vizcarra Marin ◽  
Alex Ngan ◽  
Roberto Pineda ◽  
Juan Carlos Gomez ◽  
Jose Antonio Becerra
Keyword(s):  
Gulf Of Mexico ◽  
Real Time ◽  
Lessons Learned ◽  
Clear Understanding ◽  
Directional Drilling ◽  
Case Histories ◽  
Control Plan ◽  
Drilling Performance ◽  
Drilling Parameters ◽  
Drilling Engineering

Abstract Given the increased demands on the production of hydrocarbons and cost-effectiveness for the Operator's development wells, the industry is challenged to continually explore new technology and methodology to improve drilling performance and operational efficiency. In this paper, two recent case histories showcase the technology, drilling engineering, and real-time optimization that resulted in record drilling times. The wells are located on shallow water in the Gulf of Mexico, with numerous drilling challenges, which typically resulted in significant Non-Productive Time (NPT). Through close collaboration with the Operator, early planning with a clear understanding of offset wells challenges, well plan that minimize drilling in the Upper Cretaceous "Brecha" Formation were formulated. The well plan was also designed to reduce the risk of stuck pipe while meeting the requirements to penetrate the geological targets laterally to increase the area of contact in the reservoir section. This project encapsulates the successful application of the latest Push-the-Bit Rotary Steerable System (RSS) with borehole enlargement technology through a proven drilling engineering process to optimize the drilling bottomhole assembly, bit selection, drilling parameters, and real-time monitoring & optimization The records drilling times in the two case histories can be replicated and further improved. A list of lessons learned and recommendations for the future wells are discussed. These include the well trajectory planning, directional drilling BHA optimization, directional control plan, drilling parameters to optimize hole cleaning, and downhole shocks & vibrations management during drilling and underreaming operation to increase the drilling performance ultimately. Also, it includes a proposed drilling blueprint to continually push the limit of incremental drilling performance through the use of RSS with hydraulics drilling reamers through the Jurassic-age formations in shallow waters, Gulf of Mexico.

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