Sekal (Norway)

Abstract Rig automation is becoming common practice, due to increased instrumentation on the drill-floor and the possibility to communicate and control the drilling machines via an Automated Drilling Control System. Active control of the drilling process itself (i.e. hole creation) is an active field of innovation, with several solutions being currently developed. We consider here the testing and validation of such a drilling optimization system. This system continuously computes set-points for the three main rig machines (hoisting, rotation, and circulation systems) so that the performances are optimized (highest Rate of Penetration (ROP) as possible) while ensuring that the process as a whole is still conducted in a safe manner. This involves limiting the possible range of setpoints to avoid cuttings transport issues, buckling or high downhole pressures. In this context, one of the key features is the ability to react quickly to changes in downhole conditions: abrupt formation changes and founder point excess are the two main scenarios that are considered. When such changes occur, it is important to react in a timely fashion to avoid unwanted situations (for example high Weight on Bit (WOB) when entering a hard formation while in ROP mode). This feature requires a continuously updated response model of the drill-bit: this relies on constant calibration of a bit-response model, that relates the surface parameters (Block velocity, top drive RPM and pump rates) to the well’s response, WOB, bit torque and estimated ROP. The system involved in this study performs this calibration using particle filter algorithms, providing constant estimates of the current formation properties and bit characteristics. The calibrated model is thereafter used to generate optimum set-points to the machines. Testing such a system can be challenging because of the inter-dependency between the bit-response calibration and the set-points computation. Offline or passive testing provides little value because the calibration relies on sufficient excitation of the system: standard drilling data sets usually use constant set-points while on-bottom, and the calibration becomes suboptimal. In turn, the set-point generation process cannot determine optimum values due to the lack of properly calibrated models. A solution is to base the testing and validation on a simulated environment. This requires a high-fidelity drilling simulator that can be integrated with the automation system. We present in this paper how such a simulator was used to test the drilling optimization system under a variety of possible scenarios, which would have been impossible in a passive mode on a drilling rig. Along with the requirements on the simulation environment, the testing methodology will be presented, together with the different metrics used to validate the system.

ABSTRACTAir pollution constitutes a major threat to public health. To meet increasingly strict air quality regulations, efficient air purification solutions are necessary. Non‐thermal plasma (NTP) offers an economic alternative to traditional methods such as incineration and filter adsorption as it can treat large emissions with minimal pressure drop and without the need to heat the emission. NTP is suitable for particle, VOC, and odour abatement in a variety of industries. The exact processes in an NTP discharge are only partially understood, and effective air purification requires tailoring the solution to the emission in question. This paper gives an introduction to the industrial implementation of NTP as either a standalone solution or as the basis for a multi‐step cleaning solution.

Abstract Automation has progressively taken over various manual drilling subprocesses on selected rigs for one Norwegian operator. In the past year, notable advancements in automation have been achieved, which orchestrate automation procedures across disparate surface and subsurface systems into a unified platform for control. This paper presents the tangible benefits these initiatives have yielded, notably enhanced operational efficiency and safety as well as improved efficiency of workflows for the drilling crews. This paper will detail the technological innovations employed in this project, the verification and validation steps that preceded full-scale implementation, and the practical impact the automation solution is having on operations. The paper will elaborate on how the solution enables orchestration across multiple engineering solutions in conjunction with the rig control system to ensure a state-managed set of critical drilling parameters is utilized to deliver precise actuation aligned with the current rig process. It will also discuss the process of establishing connectivity between the parties involved in both a technical and operational capacity. This project represents a revolutionary step in offshore drilling, showcasing the successful collaboration, integration, and orchestration of automated technologies in a complex operational environment involving multiple actors. We will provide a detailed review of the project’s objectives, which centered on demonstrating the feasibility of autonomous drilling operations to function over an extended period. The project demonstrated successful interoperability of processes aligned with best practices between downhole and surface controls across multiple partners, on a robust system for exchange platform. In addition to reviewing what worked well, the paper highlights several learnings on the relevance of integrated process boundaries for lower-bounds management in system control. The paper will explore the implications of these results for future offshore drilling operations, emphasizing the potential for widespread adoption of autonomous drilling technologies. It will reflect on the project’s contribution to the field of automated drilling and its alignment with industry goals of safer, more efficient, and consistent practices.

This contribution is an introduction to the thematic collection ‘Digitally enabled geoscience workflows: Unlocking the power of our data’. The goal of the collection is to show how advances in data-science are transforming the process of scientific research and fueling a new generation of energy geoscience workflows. These workflows are providing game-changing advances in terms of time saving on complex tasks, improved consistency and repeatability of interpretation, and utilization of scarce experienced geoscientists. Eight articles have been accepted for publication as part of this thematic collection, five in Petroleum Geoscience and three in Geoenergy . We provide a short summary of each of these contributions and hope that this collection will provide inspiration and examples of the breadth of workflows that can be transformed by embracing the coming wave of digital technologies. This thematic collection resulted from an open call for papers on the theme of ‘Digitally enabled geoscience workflows: Unlocking the power of our data’. Eight contributions have been accepted for publication, five in Petroleum Geoscience and three in Geoenergy . Although the energy geoscience industry typically employs statistical workflows that are highly data intensive, it has been relatively slow to adopt modern data-science technologies. This is a result of historical reliance on established methods, the cost and complexity of adopting new technologies, and cultural and organizational challenges. However, with improved computing power and growing interest in data sciences, this is now changing rapidly, with the development and application of data-driven workflows an active area of research in energy geoscience. It is expected that the publication of research contributions in this area will continue to accelerate, with this collection providing a useful summary of the current key emerging themes.

Summary The drilling industry is striving to be more efficient, reducing time, costs, and emissions to provide energy solutions for a more climate-conscious world. Reducing nonproductive time (NPT) and invisible lost time (ILT) by utilizing modeling software to optimize tripping operations is one method to combat this. Additional factors such as sea heave have a significant impact on tripping operations on semisubmersible drilling vessels, which do not show a linear response to increased heave. These vessels have compensation systems, but they are often not in use or not completely accurate. Typical heave experienced in the North Sea is between 0.5 and 3-m amplitude and 10–30-second heave period. In this study, transient modeling software is used to create a digital twin of the wellbore to safely predict the tripping speed and define the effect heave has on the tripping operations, from causing additional swab and surge pressures when in or out of slips to reducing tripping speed and improving efficiency by reducing mud gelling at connections. To further understand the effect heave has on tripping operations, experimental simulations of varying heave magnitude were completed in wellbore sections of 0°, 30°, 60°, and 90° inclination. Model validation was completed before running simulations. The results indicate that in horizontal holes, low heave magnitudes result in no bit or pressure response. The same cannot be said for vertical wells, which show smooth bit movement and pressure response throughout the heave magnitude spectrum. However, in a horizontal hole when the wave height is of a larger magnitude, sufficient to break wellbore friction, bit displacement is observed to display jerky axial stick and slip movement, and resultant increased swab and surge pressures are shown even when accounting for the reduced pressure fluctuations due to string eccentricity in an inclined wellbore. It is proposed that much of the related mechanical and pressure response is due to the properties of the drilling mud, string elasticity, and the forced frequency of the waves on the natural frequency of the drilling rig and drillstring. It is clear from definitive and experimental simulations that extra care must be taken when the heave is significant to maintain wellbore stability and reduce wellbore pressure cycling.

Abstract Objective and Scope The purpose of this paper is to document an ongoing project called "Dual - velocity tubular running" which is being used to optimize the drill-string and casing running speeds, with the view to trip as efficiently and quickly as the rig and geo pressure limitations allow but doing so in a safe manner that prevents nonproductive time, both visible and invisible, and always retains the wells integrity and allows safe operations. Dual speed refers to the ability to target an initial speed to safely break the mud gels, and a second tripping speed permissible once those same gels are broken, and this is illustrated in Figure 1. This ‘dual speed’ optimization approach can be achieved by a more advanced use of mud gel-break and rheology data and a new auto sequence for stepwise axial velocity control. This project is a step change in targeting an autonomous and optimized drilling process, and the impressive results that can be achieved can be seen in figure 2 above. As many authors have noted, such as Cayeux E., E. W. Dvergsnes, F. P. Iversen 2009 there are many factors that contribute to nonproductive time, which include Lost circulation, formation influx, pack-offs and other stuck pipe events which cause delays, problems, lost time, and generally increase risk, and cost of the well, during drilling operations. Each of these has the potential to escalate into serious problems that can result in undesirable technical sidetracks. Couple this with ever more complex wells, (whether they be long horizontal sections, multi-laterals, etc.), and ensuring operations are done safely and efficiently is paramount. Furthermore, the traditional metrics of time and cost, are now further modified by the requirements to reduce the carbon footprint of operations. Anything which allows the well operations to be completed more quickly reduces the carbon footprint of the operation. The solution and concept presented in this paper showcases a modelling approach which allows all these situations to be accurately modelled in a transient setting, to optimize tubular running speeds – be that drill pipe, casing, liners, expandable liners, sand screens or any tubular string run in hole, and then also compared and back modelled using all the available real time high frequency data. This coupled with an automated drilling control system has resulted in safe, record-breaking drilling achievements in the North Sea. The models allow updated safeguards to be applied to the drilling control system to maintain a downhole pressure within the acceptable limits of the open hole formations. It also automatically stops the movement of the drill string in case of abnormal hook loads or surface torques. Since automatic actions can be triggered in case of an unexpected situation, some standard procedures have been fully automated, including friction tests and back-reaming. In prior papers such as Cayeux E., B. Daireaux, E. W. Dvergsnes, 2010," Automation of Mud-Pump Management : Application to Drilling Operations in the North Sea , the peak surge seen when pipe is first moved and gels are ‘broken’ has been used as the limit for safe tripping, however that precluded further optimization that exists once gels are broken, and pipe and fluid is in motion. This optimization process will be discussed in detail in this paper.

Abstract Unexpected situations and system failures during well construction operations are always possible. In the context of drilling automation, or even autonomous drilling, proper automatic management of these situations is of critical importance as the situation awareness of the human operator is very much reduced. The proper management of the transition between automatic and manual modes is necessary to improve the safety of automation solutions.An important characteristic of drilling automation solutions is their ability to cope with unexpected situations. This also encompasses, placing the drilling system in a state that is easy and intuitive for the human operator when manual control is required. Our approach to safe mode management is dependent on a good state estimation of the current conditions of the process. If for any reason, manual control must be regained, then the automated function itself triggers the necessary actions that will ensure a stable current state.In case of a drilling problem or a system failure, the human operator may have to regain control when the context might be totally different from the one left when the automation or autonomous function was enabled. It may even be a different human operator that has to take control, if a crew change has taken place. To make the transition from the automated/autonomous context to manual control, the automation/autonomous system sets the drilling machines in a so-called safe transition state. A safe transition state is one for which leaving the current setpoints of drilling machines untouched for a reasonable amount of time, will not immediately jeopardize the safety of the drilling operation. A safe transition state is contextual as it is not necessarily the same sequence of actions that must be performed to reach the safe transition state every time. The novel safe modes management method is integrated into existing drilling automation solutions.In a drilling automation context, the situation awareness of the human operator is considerably reduced as the automated functions control the process and the human operator is not actively driving the drilling machines. Without active safe mode management, there is a risk that drilling automation solutions may lead to serious situations as the driller may be totally unprepared to regain control in the middle of a critical situation. When it is needed to return to manual mode in the middle of the execution of an automatic procedure, an adequate procedure is executed. The choice of the procedure and its parameters depend on the current state of the process and system.

Abstract The drive for cost efficient solutions in drilling has become stronger the last few years, and one of the approaches to this end is to increase the level of automation. Automation is multi-disciplinary task, and to really succeed, there is a need for collaboration between the different parties in the drilling industry. In this paper we discuss which underlaying technologies within instrumentation, control systems and communication technology that should be in place for a typical model-based automation and well protection software to work optimal. We elaborate on what is needed to take out the full potential of performance-enhancing functionalities in automated drilling control software. We highlight the gaps present today and how this affects the automation efforts as a whole. The discussion shows that there are some low-hanging fruits that can give significant cost reduction and improvements in automation and safety, while there are also some technology gaps that will take some time to fill and that require coordinated efforts between the vendors.

Tujuan penelitian ini adalah untuk mendapatkan data empiris mengenai pembelajaran yang efektif dari sudut pandang peserta didik maupun dari sudut pandang guru. Penelitian ini merupakan penelitian kuantitatif menggunakan metode survei. Populasi dalam penelitian ini seluruh siswa kelas X dan XI IPS tempat dilaksanakannya PKM/PPL. Sampel terdiri dari guru dan siswa yang masing-masing jumlahnya 23 orang dan 521 orang. Instrumen yang digunakan berupa angket skala Likert. Hasil penelitian menunjukkan bahwa antara siswa dan guru punya perspektif yang cenderung sama mengenai pembelajaran sejarah yang efektif. Perbedaan yang terjadi hanya dalam hal penggunaan buku paket. Siswa berpandangan penggunaan buku paket efektif untuk pembelajaran sejarah. Sementara guru berpandangan efektifnya pembelajaran sejarah jika juga menggunakan buku selain buku paket.

Abstract The application of safe-guards, safety triggers and automated procedures to control the mud-pumps, hoisting system and top-drive allows for safer, more consistent and more efficient drilling operations. Attempting to apply drilling automation on a floater needs to manage the impact of the unpredictable movement of the drill-string induced by heave movements. Because of the drill-string elasticity and the continuous movement of the rig, it is challenging to estimate the bit position, the bottom hole depth or the instantaneous rate of penetration. Yet, these estimations are crucial for the evaluation of cuttings production and their transport, or dynamic open hole pressures. Furthermore, the variability of the top of string movement can change abruptly when heave compensation is turned on or off or depending on the efficiency of the heave compensation system. These facts have an impact on the look-ahead strategy to determine safe drilling parameters. An existing drilling automation system, originally designed for fixed platforms, has been modified to meet those new requirements. For this first adaptation, only vertical drilling has been considered. Heave movements with and without compensation are constantly monitored so that sudden or slow changes in amplitudes get accounted for. Induced effects on downhole pressures are estimated via hydraulic simulations for a wide range of drilling and heave scenarios. Consequently, the design of the automation system had to be deeply modified to incorporate this additional dimension. The resulting system has been used for the drilling of three exploration wells, in eleven sections. Offshore drilling operations are characterized by a large variability of the drilling operation conditions. On a floater, the drilling context is even more challenging as it is subject to ever changing weather conditions. Yet, by utilizing model-based drilling automation solutions it is possible to improve drilling efficiency.