bluuebunny/crossref_metadata_2025_split huggingface dataset:
Buoyancy Technology Used to Successfully Install Casing in Argentina's Longest Extended Reach Slim Well Pad
Authors: Bahl C. , Tait W. , Garcia S. , Munawar M. 
Published: October 2023

Abstract
The main objective of this paper is to summarize and present the results of extended reach casing installations in the Vaca Muerta basin in Argentina. The wellbores used as case studies in this paper had lateral lengths up to 4250m and includes the longest lateral cased in the Vaca Muerta region. A discussion of the operational parameters, placement philosophies and a risk assessment will be covered.
A glass disc flotation collar was installed as part of the casing string. This device traps air between it and the float equipment, reducing the frictional forces acting on the casing through the buoyancy effect. At the target depth, a pre-determined pressure is applied to the glass disc, rupturing the disc and allowing circulation in preparation for the cementing operation to follow.
Previous papers such as Rastegar et al. (2018), introduced the concept of placing the flotation collar at an "optimal" location. These previous attempts all assumed that the optimal position was the location that yielded the maximum hookload possible at target depth. While this is often the case, an alternative approach was taken in this case study whereby the flotation collar was placed to maximum the hookload at the build and curve section of the wellbore where frictional forces are often of highest concern.
Operation decisions that impact flotation collar effectiveness are also discussed in this paper. The primary discussion point is centered around the mud filling strategy used and improvements implemented at the rig. A discussion of the early filling strategy used, and the improvements made for the case study will be covered in detail.
The results of the case study project determined that there was a 28% reduction in the run-in-hole time when using the new deployment strategies. These strategies also reduced the need for string rotation, ultimately reducing casing wear and fatigue.
Drilling and Completing of Highly Depleted and Unconsolidated Sand Requiring Overbalance Mud Weight for Shale Layer. A Control Made Possible with Strong Well Planning Optimization and Mechanical Earth Model Iteration
Authors: Ninga M. Chembou , Ponte G. , Rouat T. , Murray P. , Ozioko R. C. , Bois A. , Oredolapo O. 
Published: October 2023

Abstract
Cameroon, Rio del Rey basin has been developed in the late 70's with more than 400 wells drilled & producing from different reservoirs in vertically (stacked reservoir) and horizontally (faulted) compartmentalized fields. The long production history of these fields coupled with the under-compaction state of some deep geological formation tends to raise a real challenge to any operator which would plan to drill infill wells in this context to sustain the production rate.
The addition of any drainage points in currently producing reservoirs must pass through in-depth analysis of the current state of stress in the drilled zone. One must consider the under compaction of shale layers requiring high MW to counteract the collapse pressure, the huge depletion of the targeted reservoir and the need to maintain a minimum overbalance in front of unproduced layers at virgin pore pressure. The resulting narrow margin between pore pressure & collapse pressure on the low end, and the fracture propagation and initiation pressure in the higher end, can drive to non drillability of the wells planned. However, thanks to thorough trajectory optimization - mainly well inclination angle at the entry of reservoir section - and iteration supported by a solid 1D Mechanical Earth Model (MEM), it was possible to drill two sidetracks (ESM-1ST & ESM-2ST) in this challenging environment, with up to 3000psi overbalance in front of severely depleted permeable formations, completed by a cemented 5½″ liner in 6¾″ open hole. It was possible to validate the possibility to enlarge drilling envelope by increasing the fracture pressure thanks to inclination and even being able to operate beyond this limit thanks to strong wellbore strengthening procedure implemented. Improvement process through lessons learnt from the first sidetrack helped to drill and case off the second sidetrack well successfully.
Capability Development of Technician in Oil and Gas Operation: A Story of PETRONAS Upstream Business in Revolutionizing Competency Development in Meeting the Aspiration for the Field of the Future
Authors: Hussain Mohamad Hafez , Idrus Hana Maslinda Md 
Published: October 2023

Abstract
The objective of the paper is to share on PETRONAS Upstream (Upstream) journey in the development of technicians in meeting the business demands in volatile Oil & Gas industry. Being at the "Front Line" their competency & effectiveness in ensuring high uptime and reduction of unplanned production deferment will directly translate to meeting the Production Outputs and Business delivery. The competency of technicians is revolutionized through upskilling of current and future technicians to be Multiskilled.
The development consists of structured capability program, which encompasses the learning of knowledge and skill to ensure technicians are fundamentally equipped with proactive & predictive mindset. This is done through e-Learning process for knowledge and the ‘On-The-Job’ training exposure at the worksites (offshore and terminals) for honing their skills in the multi-disciplinary areas of Production, Instrument, Mechanical and Electrical. To ensure the learning outcomes for knowledge and skill in the multi-disciplinary areas are met, a structured knowledge and ‘On-site’ assessment is carried out. This is to ensure technicians can carry out their role in the multi-disciplinary areas safely and correctly.
PETRONAS Upstream journey in multiskilling of technicians started in 1998, with the introduction of the ‘Second Skill’. In 2018, the organization revolutionized the multiskilling program with the introduction of the ‘Third’ and ‘Fourth’ skill for technicians. We are also utilizing our very own Technical Training Centre, INSTEP to train these technicians.
Further to that, to ensure that the multi-disciplinary role of technicians who have mastered the four skills set and being utilized accordingly, the remodeling of required Production and Maintenance task listed through the introduction of Competency Level Indicators (CLI) for all listed Production and Maintenance task and the merging of task into multi-disciplinary task. With the new multi-disciplinary task, it is shown that there will be a significant increase in Operation Efficiency up to 25%. This can be translated into a manpower efficiency for manning of every Offshore and Terminal facilities and promote the concept of ‘do more with less’.
With the introduction of multiskilling, PETRONAS Upstream ambition of managing operating cost, particular in a low oil price situation, and managing increased cost of aging facilities will be realized and to remain competitive in all eventualities of possible volatility of the Oil & Gas price.
Data Analytics Driven Subsurface Reservoir Sectorization Review of a Giant Abu Dhabi Onshore Field Carbonate Reservoir for Efficient Reservoir Management
Authors: Javid Khalid , Alshkeili Sara , Al-Hammadi Fatema , Benourkhou Noureddine , Al Sayari Saleh Ali , Kenawy Maher , Ryzhov Sergey 
Published: October 2023

Abstract
This paper discusses the approach used to sectorize mature giant carbonate reservoir located onshore Abu Dhabi for the purpose of reservoir management, offtake, and injection balancing. The reservoir is developed under line-drive WAG scheme in combination with peripheral water injection. Future development plan for the reservoir includes massive deployment of Maximum Reservoir Contact (MRC) horizontal wells and a gas-based EOR scheme.
A practical data-driven approach, based on one of the ADNOC's Integrated Reservoir Management (IRM) workflows was selected for the purpose of sectorization. It starts from defining a number of possible sectorization schemes and goes through the review of:
relevant geological data (faults and structural features, rock properties and facies distribution), well performance data (productivity/injectivity indices, WCT and GOR mapping, WOR/GOR vs. cum oil trends, well maturity indicators), reservoir performance indicators (fluid properties and reservoir pressure distribution, water, and gas front movement, streamline analysis and analysis of injection allocation factors). compliance to the future development plans.
Through the review each of the preliminary sectorization schemes are scored for their compliance to IRM requirements and the scheme with the highest score is selected for the future implementation.
Out of eight sectorization schemes proposed at the start, one single scheme compliant with most of the requirements of ADNOC IRM workflow was selected. This scheme honors major faults and lineaments, reflects observed variation in rock properties and pressure distribution and at the same time caters for the requirements of future development schemes.
Selected sectorization scheme features five sectors, each having comparable number of wells, while number of wells "sharing" multiple sectors was reduced to the minimum. Being compliant to the distribution of reservoir pressure and to observed trends in well performance selected sectorization allows improved monitoring and management of voidage replacement, pressure maintenance and will cater for adequate surveillance planning and execution. Moving forward, selected sectorization scheme will be used for regular sector performance reviews aiming at identifying subsurface opportunities and areas of improvement and helping to drive efficient reservoir management decisions.
Plug and Abandonment Excellence Journey in Malaysia from the Perspective of Malaysia Petroleum Management (MPM), Petronas
Authors: Omar M. , Xiong C. C. Yee , Idris F. R. , Zawawi A. 
Published: October 2023

Abstract
This paper demonstrates how to steer excellent well plug and abandonment (P&A) programs in Malaysia from the regulator's perspective through architecting P&A activities in Malaysian water by guiding operators to execute excellent P&A activities and adapting best practices from planning until execution based on a proven technical approach that's fit for purpose to deliver P&A with optimum cost and duration without compromising safety and technical requirements in Malaysia
Decommissioning and Abandonment (D&A) activities have become more prominent in Malaysia as more hydrocarbon fields are reaching their life span. There are more than 500 idle wells that need to be plugged and abandoned by 2030. Therefore, more than 70 wells per year need to be in the P&A commitment funnel for execution until 2030.
Based on PETRONAS Malaysia Petroleum Management's (MPM) observation as a regulator, inconsistency in well P&A approach by various operators resulted divergence in well P&A design, planning, and execution to meet PETRONAS Procedures and Guidelines for Upstream Activities (PPGUA). Among the two (2) main factors identified which led to a huge variance in P&A approaches across operators are lack of experiences in performing well P&A on a larger scale and gaps in communication with regulators, Realizing the communication gap between regulator and operators based on observation from 2016 until 2020, PETRONAS MPM, as shaper and enabler, embarked on an effective communication workflow based on a structured well abandonment activities cycle with the aim to close the gap and align the understanding among operators.
PETRONAS developed the well abandonment workflow cycle as a guide to operators, which covers five (5) distinct stages to ensure successful P&A campaign delivery from the initiation stage until well close-out & lesson learnt stage. Other supporting guidelines from PETRONAS MPM, for instance, are well P&A complexity benchmarking and well P&A campaign execution strategies, which assist operators in Malaysia from planning until execution stages.
It is mandatory to identify key factors to optimize the duration and minimize the cost. PETRONAS MPM emphasizes six (6) potential areas of optimization as key factors for operators to put their focus on when exploring cost and time reduction. Based on historical experiences, these six (6) areas will provide between 30% to 40% cost reduction opportunities in a well P&A campaign.
In summary, PETRONAS MPM, as a regulator, shaper, and enabler, will continue to take proactive measures to collaborate with all operators and business partners in Malaysia to continue promoting a safe, sustainable, and strong P&A ecosystem. PETRONAS believes a strong collaboration culture of sharing experiences will be essential for operators and contractors to work safely, stimulate creativity, and strive towards decommissioning cost compression.
Historical Cement Packer Case Study from Trinidad & Tobago Columbus Basin
Authors: Mammadli R. , Adilov R. , Bassie Y. , Rasmine M. , Hosein N. , Somai J. , Bruce T. 
Published: October 2023

Abstract
Historically, in the Columbus basin offshore Trinidad and Tobago small pool reserves are left behind the casing above the existing production packer. A low-cost alternative to an expensive rig workover was required to develop these trapped reserves. As a solution to this challenge, coiled tubing up-hole cement packer re-completion was developed and advanced during the last 10 years. Several well candidates were chosen to trial this method in the region. This paper will discuss the learnings and challenges faced during the execution and how the team applied these learnings for the next candidate selection.
Extensive data has been gathered from previous cement packer jobs and evaluated to establish the best practices and understand the key failure mechanisms. Based on the learnings, a candidate well was selected for up-hole recompletion. One of the key learnings from this exercise suggested the importance of well deviation to the success of cement packer jobs. Numerous failed well cement packers experienced contamination and channeling on 40 deg and higher deviation. It was identified that extending the top of the cement packer to the vertical section of the well was crucial for the success of the job. Extensive software modeling and lab testing related to the first-time use of a MgO-based expansive agent were performed to conduct the sensitivities around the height of cement in the annulus, and displacement rate to optimize the displacement efficiency. The analysis was performed to evaluate if the use of different cement retainer types and setting depth contributed to the success of the results.
The candidate well delivered planned objectives efficiently and within budget. The cement packer was placed above the zone of interest and logging was performed to confirm the quality of cement bonding. Cement displacement software modeling assisted in designing the pump rates to achieve the best results. Despite the operational challenges which resulted in setting the cement retainer shallower than the intended depth, ~500ft of uncontaminated cement with ~2200 psi compressive strength was attained. Even though the plan of bringing the cement to the vertical section was not achieved during the execution, the required cement packer height was not compromised. Perforations then were made, and ceramic sand screens were installed to prevent sand production.
Cement packers are not new to the industry. However, notable learnings were obtained from the Trinidad & Tobago region that integrates the combination of Gas lift mandrels, control lines, operational challenges and limitations. Incorporating previous learnings, cement lab testing, software simulation models, and the use of expanding agents, were the main contributors to the success of this job.
Wells and Facilities Instrumentation and Automation Towards Achieving Field Intelligence
Authors: Salim M. M. , Traboulay I. , Ahmed G. S. U. , Ibrahim E. , Al Wehaibi S. , Al Hammadi O. , Ballaith N. , Al Houqani M. 
Published: October 2023

Abstract
A well is a conduit that connects the hydrocarbon deposits in the subsurface to the facilities that transfers and processes it. Understanding the flow of oil or gas through the source rock can only be made possible from the wells itself. Aside from the flow conduits, wells are the only point of reference to understand the field wide behavior. This information is critical to manage the reservoir, ensuring sustainable production throughout the field life.
Traditionally, acquiring data from the subsurface to the wellhead relies on intervention, conveying instruments downhole with wireline or coiled tubing. Though effective, this activity incurs costs, logistically challenging and only sporadically available. Surface flow parameters such as rate and pressure are usually measured by analog gauges and Barton chart measurements, which are read manually by personnel to be tabulated later. In most cases, these data can be lost without a proper data management system in place.
With the advent of digital instruments, parameters such as pressure, temperature and flowrates; can now be measured automatically and transmitted to a DCS or SCADA system. Some downhole completions are now equipped with instruments that are robust and accurate to take measurements even in extreme conditions of heat and pressure.
With data at high availability, engineers are now able to conduct analysis faster, applying data analytics, collaboration and decision making. The main value for Digital Oilfield (DOF) is to save time in data retrieval, analysis and decision making and allow domain engineers to perform higher analytical function and decision making, taking them out from repetitive, manual work through automation.
This paper will describe the minimum instrumentations for all well types and major oil and as process facilities for real time data acquisition required to run DOF workflows. This covers subsurface wellbore to production manifold to custody transfer meters.
Managing Shift Workers Fatigue Using Psychomotor Vigilance Test and Biomathematical Modelling
Authors: Qureshi Farrukh , Karyum Hanafi , Al Mazrouei Shayma , Al Hammadi Nooh , Bametraf Rashed , Al Hammadi Saud , Saleh Ahmed 
Published: October 2023

Abstract
Shift work is a crucial aspect of modern industries, enabling round-the-clock operations. However, working outside conventional daylight hours can disturb the body's natural circadian rhythms, leading to increased fatigue, reduced vigilance, and impaired cognitive performance. This technical paper describes the use of the Impairment Detection Technology (IDT) i.e. Psychomotor Vigilance Test (PVT) and software based on the biomathematical modeling as an integrated approach to assess, predict, and manage shift workers' fatigue. By combining objective performance measurements and mathematical algorithms, employers can predict fatigue and proactively address fatigue-related risks, enhance worker safety, and optimize productivity in shift work environments.
High Conversion Refineries: An Approach to Reduce the Carbon Footprint by Hydrogen Network Optimization and Flexibility Enhancement
Authors: Campanelli Veronica , Magliulo Ciro , Albanese Claudio , Arces Ignazio 
Published: October 2023

Abstract
The momentum behind hydrogen as strategic vector to satisfy refining sector needs remains strong over the years. Indeed, hydrogen is a key feedstock in refining operations particularly for a complex conversion configuration such as that of Eni Sannazzaro Refinery, with one of the highest levels of complexity and capacity conversion in Europe, comprising of more than ten hydrogen consuming technologies out of which two hydrocracking, three diesel/kero hydrotreaters, three naphtha hydrotreaters, a FCC naphtha selective hydrogenation and other minor hydrogen consuming processes.
The Sannazzaro Refinery is a hydrogen self-sustaining hub thanks to a robust hydrogen producing system that includes technologies such as steam reforming, catalytic reforming and gasification that feed a hydrogen network structured in three hydrogen grids at different pressures and purities.
Targeting an excellent hydrogen network management and aiming at optimizing as possible the site energy consumption thus minimizing associated GHG emissions, the Sannazzaro Refinery has implemented a Dynamic Matrix Control (DMC) system monitoring the hydrogen network pressure to reduce the steam reforming throughput while maximizing the consumption of hydrogen produced by catalytic reforming units avoiding overpressures and hydrogen discharges towards the fuel gas network.
The project has resulted in an overall increased stability of hydrogen network, achieving a noteworthy hydrogen production saving of 900 ton/year with a reduction of 8500 ton/year of CO2 associated emissions towards an increase of site sustainability, parallel resulting in an enhanced stability of hydrocracker recycle gas purity (always maintained over 85%vol hydrogen content in order to preserve catalyst activity), determining a remarkable reduced standard deviation for controlled variables such as the high purity hydrogen grid pressure, succeeding in minimizing the hydrogen content into the fuel gas network, thus increasing relative fuel gas Wobbe index by 3 MJ/Nm3, hence positively impacting the site energy efficiency and enhancing its flexibility to closer tackle the variations on hydrogen refinery needs. All results have been achieved thanks to a fast controller run time (ca. 30 seconds) and an average service factor &gt; 70%.
In conclusion, the overall project demonstrates how the implementation of a Dynamic Matrix Control system interestingly contributes to reduce a high conversion refinery carbon footprint and its hydrogen production cost via a fast-track and a low-cost project, being the site characterized by a complex hydrogen network with multiple hydrogen grids and steam reforming units to modulate the hydrogen production.
Paving the Road for Wireless Gauge Installation in Onshore Field
Authors: Almadani Amr H. , Eissa Mohammad A. , Winarno Mulad B. , Mutairi Khaled M. 
Published: October 2023

Abstract
Observation wells become very essential to provide an update of reservoir performance. Monitoring reservoir pressure is very crucial in reservoir and production’s enhancement process. Collecting pressure data using slickline method is not favorable in high production’s high demand period. One of the conventional techniques to collect downhole pressure data is by installing Permanent Downhole Pressure System (PDHMS). These PDHMS are powered by electric cable which is subjected to failure in case of rush current or short circuit. Once failed, workover rig is required to replace the failed PDHMS which is considered as non-economical solution.
An innovative approach was developed to continue monitor the reservoir data for wells that have failed PDHMS without the need of workover rig. This approach is by installing wireless gauges. The system is powered by batteries, can be deployed by wireline, and installed inside production tubing.
Pressure and temperature data are transmitted wirelessly through metal from tubular to wellhead. Surface panel system can display, store and provide port to download the data. However, the data transmission of the wireless gauges is interrupted by overhead powerline, cathodic protection, intelligent field equipment and other existing electric devices. Therefore, first of its kind noise filter cancelation was added into the system to ensure the accuracy and continuity of data transmission.
An integrated process for wireless gauges installation was developed starting with the designing process to receiving the data at engineers’ desktop. This process plays a vital role in planning future production optimization, reservoir management and injection strategies.
This paper is sharing the best practice and procedure that should be followed during the surface panel work preparation up to downhole gauge installation