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Collaborating Authors
Well Simulator Technology Overview and Results for Onshore, Offshore and Subsea Drilling Operations
Santoro, D. (ENI SpA, San Donato M.Se, Milan - ITALY) | Forno, L. Dal (ENI SpA, San Donato M.Se, Milan - ITALY) | Ferrara, P. (ENI SpA, San Donato M.Se, Milan - ITALY) | Bianchini, L. P. (ENI SpA, San Donato M.Se, Milan - ITALY) | Bartucci, G. (ENI SpA, San Donato M.Se, Milan - ITALY) | Bianchi, L. (ENI SpA, San Donato M.Se, Milan - ITALY) | Lahou, K. (eDrilling, Stavanger - NORWAY) | Nabavi, J. (eDrilling, Stavanger - NORWAY) | Huseynov, P. (eDrilling, Stavanger - NORWAY) | Gocmen, E. B. (eDrilling, Stavanger - NORWAY) | Lye, J. (eDrilling, Stavanger - NORWAY) | Loh, J. (eDrilling, Stavanger - NORWAY)
Abstract Well simulator technologies have become an ever more important part of Well Construction design and Drilling Operations follow-up worldwide. Adopted initially by Company to support personnel training through virtual environment applications, they were then used for planning, real time support and post job analysis for drilling operations, being integrated in all engineering processes. This paper presents an overview of its current use and procedures, highlights current and potential benefits and suggestions for future developments. Selected wells are configured inside the well simulator which is then latched to mud log data streams. Dynamic models calibration is performed by adjusting dedicated coefficients to reach an overlap between simulated and measured drilling parameters. The degree of drift between curves allows to identify well operations-related issues. Outputs are mostly time-based, in mud log and driller-cabin-like layouts fashion. Depth-based plots, such as roadmaps for axial and torsional friction factors are also available and can be used as input for advanced analyses for both planning and post job phases. Systematic application of the well simulator was started early 2021 with real time monitoring for North Sea and Africa offshore/subsea operations. Deployment along 2022 spread out across several other business units in various operated countries, for onshore, offshore and subsea drilling operations. Experience gained in a number of relevant case histories, dedicated to both real time support and what-if post-analyses, allowed to provide earlier feedbacks on drilling operations good practice but also to predict, avoid and mitigate consequences of wellbore problems and equipment malfunctions, boosting interest for further developments. Nowadays, well simulator technologies constitute a fundamental step towards drilling automation, since their dynamic modelling approach allows the definition of drilling parameter envelopes inside which robotic tools can operate and generate alerts if envelopes are overridden. Anomalous behavior of the drilling parameters can be recognized and governed. Automatic configuration and calibration of real time driven models are key enablers of real time optimization of operational drilling parameters and contactless operations, reducing back-office support to minimum. Well simulator solutions that have been tested and deployed in our operations allow adaptability to a variety of existing platforms from both the operators and service companies side. The new upgrades, for data input and results visualization, are prone for user-friendly application, reducing the amount of training required for operative personnel to familiarize themselves with the tool and apply it during drilling operations.
- North America > United States > Texas (0.29)
- Europe > United Kingdom > North Sea (0.25)
- Europe > Norway > North Sea (0.25)
- (2 more...)
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. Figure 1: Objective of the Automated Drill-String Tripping and Casing Running project. This โdual speedโ 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. Figure 2: An example of the tripping speed improvements with the dual speed approach 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 โ 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 โbrokenโ 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.
- Europe > United Kingdom > North Sea (0.45)
- Europe > Norway > North Sea (0.45)
- Europe > Netherlands > North Sea (0.45)
- (2 more...)
IGas Energy was granted planning consent to develop a new oil wellsite in Lincolnshire in the UK close to its existing Glentworth-K site which has been producing oil for 60 years. Lincolnshire county council granted planning permission for an initial appraisal well and up to six horizontal development wells in the second phase of the development. The first phase has the potential to add around 200 BOPD, and the second phase could add a further 500 B/D, IGas said in a statement. The oil produced at the site will be sold to a domestic refinery.
Using Transient Modeling to Define the Effects of Heave on Wellsite Operations
Shipton, Peter (Sekal AS (Corresponding author)) | Amish, Mohamed (School of Engineering, Robert Gordon University) | Gjerstad, Kristian (Faculty of Science and Technology, Department of Energy and Petroleum Engineering, University of Stavanger)
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 10โ30-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 0ยฐ, 30ยฐ, 60ยฐ, and 90ยฐ 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.
- North America > United States (1.00)
- Europe > United Kingdom > North Sea (0.25)
- Europe > Norway > North Sea (0.25)
- (2 more...)
- Research Report > New Finding (0.88)
- Research Report > Experimental Study (0.67)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- (2 more...)
Best Approach From Drilling Perspective Through Concept Select to Pre-FEED for Long Term Development of Offshore Brown Oil Field in Middle East Area
Fujinaga, Ryota (ADNOC Offshore, Abu Dhabi, UAE) | Toki, Takahiro (ADNOC Offshore, Abu Dhabi, UAE) | Toma, Motohiro (ADNOC Offshore, Abu Dhabi, UAE) | Andrews, Kerron Kerman (ADNOC Offshore, Abu Dhabi, UAE) | Alloghani, Khalid Hussain (ADNOC Offshore, Abu Dhabi, UAE)
Abstract Concept Select and Preliminary Front End Engineering and Design (Pre-FEED) were carried out on a long-term development plan (LTDP) for a brown oil field with nearly 200 existing Wellhead Towers (WHTs) and four existing artificial islands in the middle east area. The development objective is ramping up the production to certain rate and sustain it as long as economically feasible. This paper will describe: Critical stuff that needs to be performed or taken into account from drilling perspective during Concept Select/Design and Pre-FEED How the drilling discipline should be proactively engaged through Concept Select and Pre-FEED for development project of offshore brown oil field During the Concept Select, necessary data related to drilling was firstly collected such as well target locations, available slots on existing WHTs etc. In addition to that, several assumptions were set, associated with drilling rig specifications, constraints on drilling feasibility and number of well slots on new WHT. Based on the data and assumptions, multiple concepts were developed with respect to different drill centers including new WHTs, new artificial islands and existing WHTs/islands in coordination with other disciplines. Techno-economical evaluation was conducted on each concept. Subsequently, Pre-FEED was conducted based on the selected concept. During the Pre-FEED, more detailed study on WHT locations, WHT orientations, WHT design, island location, island design, HSE assessment etc. was conducted by Pre-FEED contractor, incorporating basis and requirements from all the concerned disciplines. Through the Concept Select and Pre-FEED for Long Term Development Plan (LTDP), following things were found important: Generic drilling limits like maximum horizontal departure to targets should be defined clearly at early timing of Concept Select for optimization of well allocation to drill centers Rig specifications and its limits like air gap, skidding envelope and allowable drilling load should be identified at early stage for optimization of WHT design/locations and island design Slot-to-slot distance and row-to-row distance are quite important especially for island in terms of rig operability on island and anti-collision between wells Requirements for area and its arrangement on island should be well defined item-by-item to avoid shortage in the area dedicated for drilling during subsequent stage of project Anything that needs to be studied or considered by Front End Engineering and Design (FEED) contractor should be captured in FEED Scope of Work (SoW) with detailed requirements, which will be utilized for tender process. Anything that is not captured in the FEED SoW could result in variation order or be difficult to be added to the scope after contract award. This paper will present not only the experience in this specific project but also a fundamental approach that will be applicable in any other offshore brown oil fields worldwide.
- North America > United States > Texas > Terry County (1.00)
- North America > United States > Texas > Gaines County (1.00)
- Europe > United Kingdom > North Sea > Southern North Sea (1.00)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.16)