bluuebunny/crossref_metadata_2025_split huggingface dataset:
Empowering Collaboration and Refining Acumen with Rig Acceptance Workflow Digitalization
Authors: Meor Hashim Meor M Hakeem , Norhashimi Lokman , Norazman Nor Ashraf , Arriffin M Faris 
Published: August 2022

Abstract
Current rig acceptance workflow practiced by many operators globally has been inefficient and this gap has been apparent for years. Redundancy, accountability issues and resource wastages can be quite complicated. In a typical workflow, the issues encountered include lack of accountability by inspectors toward item closure, inability to generate snapshots of current status, limited access, and an unfit sharing process. Report formats are not standardized across different disciplines hence the experience is not seamless as there is no one-stop center to view aviation, marine, and HSE inspection items. The digitalization of rig acceptance workflow can help to overcome these pain points by having a single platform to allow multidiscipline parties to keep tabs on rig activation status and updates throughout company-wide operations globally during the rig acceptance process. This initiative introduces a much leaner and more seamless method of conducting rig acceptance. Migrating the manual paper-based workflow to a web-based one-stop center for all things related to rig acceptance (i.e., marine, rig, HSE, and aviation) is the main strategy. It grants the ability for inspectors and designated personnel to insert comments for each finding as well as the ability for inspectors to assign and edit severity levels for each finding. The single platform approach allows the possibility to link up the other checklist and findings on the same system and immediately reduce the redundancy of certain items that is similar to other checklists, which can be streamlined online. Therefore, implementation of this Digital Rig Acceptance Workflow (DRAW) solution can produce a user-friendly online platform to allow inspectors, project teams, management, and rig equipment subject matter experts to access the system anywhere, anytime. DRAW allows status updates and clarifications to be communicated via a single platform. It utilizes data input to produce actionable insights hence generating direct business value via improving process cycle efficiency in a project's well life cycle.
Deploying Dynamic Trend-Based Monitoring System to Deliver Real Time Drilling Decision
Authors: Richard Bobbywadi , Saarani M Sazani , Sulaiman Suhaimi , Meor Hashim Meor M Hakeem , Arriffin M Faris , Ghazali Rohaizat 
Published: August 2022

Abstract
Significant technical challenges are prominent in today's oil and gas drilling operations, especially in remote locations with increasingly difficult geological settings. Stuck pipe incidents have become a major operational challenge, with events typically resulting in substantial amounts of lost time and associated costs. Real-time monitoring has emerged as an important tool to achieve drilling optimization in avoiding downtime, particularly stuck pipe events. With the addition of a predictive monitoring system, this process becomes much more effective and competent. Predictive monitoring is used for advanced real-time monitoring in the remote centre and operational workflows to aid in the drilling execution of complex or critical well sections. The emphasis will be on reducing the complexity of real-time data analysis by exploiting trends and anomalies between modelled and actual data to monitor wellbore conditions. This monitoring system and trend-based predictive capability enable drilling teams to detect borehole changes and take preventive action up to several hours in advance. Predictive monitoring can provide early warning of stuck pipe symptoms, allowing the rig and operations team to take corrective and step-by-step actions. The circumstances that lead to the stuck pipe can be difficult to detect as various factors may indicate potential problems. These are frequently missed until the situation has progressed to the point where the drill string becomes stuck. This system could have provided the rig crew with advance notice of changes in downhole conditions. An example of predictive monitoring adoption in a highly deviated extended reach well (ERD), with a 12,000ft long horizontal section is presented. It is exceptionally challenging in terms of geomechanics perspective as well as the well design. Predictive monitoring was implemented to assist drilling operation for the sidetracked well, and it had been completed successfully with minor hole condition issues. The predictive monitoring system is built around a trio of tightly coupled real-time dynamic models consisting of hydraulic, mechanical, and thermodynamic that simulate the wellbore state and physical processes during drilling operations. These models work simultaneously in a seamless process to assess drilling performance, borehole conditions, and related associated risks. It uses dynamic modelling to accurately model key drilling parameters and variables, allowing better monitoring.
Making Wells Safer; Rectification of High Annulus Pressure via Diagnostic and New Technologies Through Annulus Intervention Method
Authors: Osman Abdul Afif , Azman Aulfah , Sipangkui Rayner Brian , Nazirmuddin M Nazrul Shahril , Aripin Izura , Utta Arie Muchalis , Sujavudin M Ridhuwanuddin , Sy Ahmad Sy M Shahril 
Published: August 2022

Abstract
Sustained annulus pressure is an increasingly common well integrity issue encountered particularly in aging platforms. The issue is normally discovered via periodic wellhead maintenance programs or during monitoring by the production team. Subsequently, the wells integrity team will pursue well diagnostic via annular pressure diagnostic by manipulating and creating specific conditions to acquire information on the potential leak rate, leak path, and source of the leak. The probable culprit of the tubular integrity issues is due to completion or casing leakages, or failed cement conditions.
The generic rectification technique available varies from rig to rigless method. Considering the low economic of the field & remote jacket location with a small footprint and limited crane capacity in Sabah waters, either the rig or workover option can be unfavorable. Therefore, the options available to remediate the sustained annulus pressure are limited considering the platform's design and operational setup. Historically, the team has attempted with a conventional pump and lubricate the annulus to mitigate the symptoms. However, the effectiveness was questionable as the pressure kept creeping up within a short period which urged the team to look into better technology solutions.
With the limitations above, the team warrants a new holistic approach to resolve the sustained annulus issue. Annulus Intervention System (AIS) provides better fluid conveyance and circulation for better fluid displacement at the targeted depth. The AIS system has a smaller footprint as compared to a pumping or workover unit which is a major advantage for a small and remote platform directly applicable to the target Sabah asset. This paper will table out the step-by-step method that has been taken by the team to ensure the AIS system is engineered and tailored to rectify the sustained annulus pressure in a less than 500-meter square deck space.
Storage Development Plan SDP for Abandoning High Risk Development Wells and Drilling Fit-For-Purpose CO2 Injectors Offshore Carbon Capture Storage CCS Project
Authors: Picha Mahesh S , Chuttani Anil 
Published: August 2022

Abstract
Operators are majorly focusing on zero carbon emission to comply environmental rules and regulations. This paper aims to give insights on world's major CCS project Storage Development Plan (SDP), where CO2 injection wells will be drilled to inject, and store produced CO2 from contaminated fields. To safeguard the CO2 storage containment, the integrity of all wells needs to be scrutinized. Ensuring long-term wells integrity of existing Plug and Abandonment (P&A) and active wells that penetrated the selected CO2 storage reservoir is the key to reduce leakage risks along the wellpath for long-term containment sustainability.
Development wells in the identified depleted gas field are more than 30-40 years old and were not designed with any consideration of high CO2 concentration in the reservoir. Possibility of leakage along the wellbores due to accelerated corrosion, channeling, cracks, cannot be ignored and requires careful evaluation. Rigorous process has been adopted in assessing the feasibility for converting existing producers into CO2 injector. Wells disparity between the required defined basis of designs for gas producer and CO2 injection wells governs the re-usability for CO2 injection or needs to be abandoned. New three (3) CO2 injectors with fat to slim design approach, corrosion resistant alloy (CRA) material and CO2 resistant cement are designed in view to achieve lifecycle integrity. Optimum angle of 60deg and maintaining the injection pressure of 50 bar at 90MSCFD rate is required for the injection of supercritical CO2 for 25 years. On top, during well execution, challenges such as anti-collision risk, total loss scenarios while drilling in Carbonate reservoir needs to be mitigated. The completion design is also focusing on having minimal number of completion jewelries to reduce pressure differential & potential leak paths all the way from tubing hangar down to the end of lower completion. Well design optimization from fat to slim has been carried out based on WellCat sensitivity analysis output. Well integrity life cycle monitoring using in country value latest generation fiber optic as well as acquiring seismic for CO2 plume development.
Research and Application of Integrated Technology of Chemical Sand Control and Stratified Water Injection in Offshore Oilfields Injection Well
Authors: Zhao Shunchao , Zhou Yugang , Bai Jianhua , Fang Tao , Shang Baobing 
Published: August 2022

Abstract
This paper proposes an integrated technology of chemical sand control and stratified water injection in water injection well, which enlarge the inner diameter of injection well after sand control and achieve flexible stratification of injection layer. Mechanical sand control is the main method for injection wells in offshore oilfields. After sand control, the inner diameter of injection well is small and the number of injection layers is generally 3-4 layers. For reservoirs with strong longitudinal heterogeneity, it's difficult to get higher longitudinal sweep coefficient of driving and better effect of injection.
The technology realizes completion by chemical sand control, without screens downhole. The ceramsite whose surface has been treated by crosslinking agent is injected into the well and heated. The crosslinking reaction occurs on the surface of the ceramsite, forming a cement layer with a thickness of 3-5cm and a certain compressive strength of 7.2MPa and a permeability of 5000mD on the wellbore. This cement layer not only can be used as a barrier to retain formation, but also can provide flow channels for fluids. Then, the stratified injection pipe string is run. The developed multi-functional packer contacts and seals the cemented layer to realize the stratification of the injection reservoir. The position and quantity of the packer are designed according to the target injection horizon to achieve flexible stratification.
This technology has been successfully applied to 4 wells in the Bohai Oilfield, all of which have the characteristics of large reservoir thickness and strong vertical heterogeneity. The conventional sand control and injection technology makes it difficult for the actual injection volume to reach the target volume, and the water cut of the benefit well continues to rise. After applying the integrated technology, for a directional well with a bore diameter of 9.625 in, the maximum inner diameter can reach 9.625 in, while the inner diameter of traditional sand control methods is only 4.75 in. The number of injection layers exceeds 5, and the actual injection volume meets the designed requirement. The validity period has exceeded 40 months and continues to be effective. The water cut of the benefiting well decreases from 85% to 78%, and the oil production rate increased from 56 m3/d to 72 m3/d.
The successful application of the integrated technology provides a new idea for subdivision water injection in offshore oilfields. The increase in the internal diameter of well can reduce the difficulty of operation and increase the water injection rate. The flexible stratification can improve the vertical production degree of reservoir water flooding and the overall effect of water injection.
Study on Dynamic Variation Characteristics of Reservoir Fluid Phase Behavior During CO2 Injection in CO2 Based Enhanced Oil Recovery Process
Authors: Zuo Mingsheng , Chen Hao , Xu Chenghao , Stephenraj Infant raj , Qi Xinyu , Yu Haizeng , Liu Xiliang Yang 
Published: August 2022

Abstract
CO2 huff and puff is an effective EOR technology for tight reservoirs. However, the mass transfer between CO2 and oil makes the reservoir fluid phase behavior very complex and affects the reservoir recovery. Through the visual injection experiment, phase equilibrium calculation model and thermodynamic parameter entropy, this paper researches the change characteristics of oil phase behavior during CO2 injection. In this paper the oil phase behavior is divided into four stages and reveal the mechanism of oil phase behavior changes. The results show that in the first stage of CO2 injection, CO2 dissolves in the oil and the volume of oil expands. In the second stage, CO2 dissolves, replaces and extracts the components of the oil, forming the third phase oil-gas transition zone, so that the volume of the oil decreases rapidly. In the third stage, the mass transfer of oil-gas components slows down, and CO2 extraction effect becomes the main factor, so the oil-gas transition zone almost disappears, and the volume of the oil decreases slowly. In the fourth stage, the mass transfer of oil and CO2 stops, and due to the compression effect the volume of oil decreases linearly. Because of the effects of extraction and compression, excessive injection of CO2 is not conducive to enhanced EOR. These results can furnish an in-depth understanding of the complicated mechanisms of the CO2 huff and puff in unconventional reservoirs.
Multi-Stage Length Optimization with Integrated Hydraulic Fracture Propagation and Production Simulation Technology for Horizontal Wells in Unconventional Resource
Authors: Yuankai Xiang , Zhou Jianlin , Leiming Cheng , Junxiu Ma , Huang Xingning , Singjaroen Thanapol , Kieduppatum Piyanuch 
Published: August 2022

Abstract
Since the tight sandstone gas reservoir which is widely distributed in China has become increasingly important in oil field with the further development of resource, it is extraordinarily meaningful for the sustainable and healthy development of China’s energy industry to explore its benefit development mode. Though great achievements have made with the wide use of the hydraulic fracturing technology, which serves as an effective process measure to increase the productivity of a single well, in the development of global unconventional oil and gas resources, there have been many technical problems exposed. A critical one is that if the fractured stage length is too long, the oil and gas resources won’t be effectively exploited, and if it is too short, the operation cost and time will be increased apparently. Therefore, it is urgently required to make plans for determining the optimal length of the fractured reservoir based on different geological features of the oil and gas reservoirs. This paper took the tight oil reservoir in Lower Wuerhe formation in study area as the research case, determined 5 fracturing stage length cases combined with the treatment status and pumping injection procedure of M oil field: Case A (40m), Case B(50m), Case C (60m), Case D (70m) and Case E(80m), and realized fully 3D coupled simulation of the hydraulic fractures in H1 well based on the 3D geomechanical modeling and 3D DFN model with considering multiple factors including stress shadow, proppant settlement and migration using the unstructured grid technology to preprocess it to improve the capacity prediction accuracy of numerical simulation. The productivity prediction results showed that the 10-year EUR (Estimated Ultimate Recovery) of a single well ranged from 35,500 tons to 48,200 tons. With the comprehensive production and fracturing operation cost being considered comprehensively, it was recommended that the optimal length of the single fractured reservoir should be 60 meters.
Well Integrity Under Dynamic Stresses Using Flexible Cement Systems
Authors: Mahmood Ahmad Abdullah , Rasheed Hassaan , Jan Usman Ahmed , Khan Anum Yousuf , Salazar Jose 
Published: August 2022

As the field of well construction has advanced over the years, one feature that has remained consistent throughout is the use of Cement as a primary well barrier element. The long-lasting, impermeable nature of the cement matrix means no other material has been considered as an effective, widely-available alternate almost a century from the first cement job. What has changed however, with advancement in the the field of well integrity, is how we approach the cement job design and how certain materials can complement the role of the cement in improving hydraulic isolation. The historical cement job design only targeted a pumpable slurry reaching the desired placement interval, then the design moved to improving liquid slurry properties such as rheologies, fluid-loss and free fluid. Later, the short-term performance as the slurry transitioned through a gel phase to a set state also became an important criterion. More recently, after the renewed global focus on well integrity as learning from disasters such as Macondo, the annular cement’s role as a well barrier has become a major focal area for any well construction program.
This paper presents a systematic approach in designing cement systems that promise long-term well integrity starting with the root-cause identification, simulating the effect on the cement sheath, required modification of the design, and finally the application and associated results.
Cable Deployed ESP System Applied with Conventional ESP Assembly: A New Generation of Rigless ESP Technology
Authors: Zhao Mengpan , Zhang Qiang , Wei Ping , Hong Yuandong , Li Qijun , Zhu Lisha 
Published: August 2022

Abstract
A new generation of Rigless ESP technology, Cable Deployed ESP (CDESP) System uses specialized cable to replace ESP, which saves rig cost and reduces production deferment tremendously. However, most CDESP in the market are applied with inverted ESP assembly, which has high requirements and more uncertainties on customized ESP.
This paper will introduce the design philosophy of a CDESP applied with conventional ESP assembly, which is more compatible. Rounds of multiple factory tests were successful, pressure test of hanger assembly and penetrator system were up to 7,500 psi,cable connector tension tests meet the specialized cable and ESP weight requirement. Also, the electrical tests were qualified. The factory tests and field applications verified the reliability and robustness of this new generation of Rigless ESP technology.
Pilot Deployment and Field Validation of Wellbore Strengthening Design Criteria and Enhanced Fracture Gradient in a Depleted Reservoir
Authors: Tan Chee Phuat , Razak M. Solehuddin , Zakaria Siti Shahara , Abitalhah Abiabhar , Wan Mohd Zainudin Wan Nur Safawati 
Published: August 2022

Abstract
Fracture gradient enhancementtechnology has been developed for drilling mud compounds based on comprehensive large scale laboratory test data which can widen the stable mud weight window for safe and efficient drilling in depleted reservoirs. Based on the laboratory test data, correlations were developed between optimum compound particle size against Young's modulus of the rock and generated fracture width for maximising the wellbore strengthening performance of the compounds. In addition, Enhanced Fracture Gradient (EFG) concept and criteria were developed for the compounds to widen the stable mud weight window. The niche workflow developed for utilisation of the wellbore strengthening design criteria and guidelines was deployedand validated in the pilot deployment of the optimum compound particle size correlations and Enhanced Fracture Gradient criteria in two wellsfor drilling through a depleted reservoir in the Malay Basin.The enhanced fracture gradient was predicted and incorporated into the mud weight programme and mud loss contingency plan of the wells. The wells were drilled with 10 ppb of the optimum mud compounds and the concentration was monitored and maintained throughout the drilling. In the first well, the maximum ECD exceeded the in-situ fracture gradient of the depleted reservoir by 1 ppg without any losses. Following TD of the hole section, an openhole leak-off test was conducted which validated the predicted average EFG of 1.8 ppg above the in-situ fracture gradient. The predicted EFG was within 0.2-0.3 ppg from the openhole leak-off test value. In the second well, the depleted reservoir was exposed to 0.6 ppg above the in-situ fracture gradient and no losses was observed.
Locked up at home : A cross-sectional study into the effects of COVID-19 lockdowns on domestic violence in households with children in Belgium
Authors: Fomenko Elizaveta , De Schrijver Lotte , Vandeviver Christophe , Keygnaert Ines 
Published: August 2022

Abstract
Background
Policymakers worldwide took measures to limit the spread of the COVID-19-virus. While these sanitary measures were necessary to fight the spread of the virus, several experts warned for a significant impact on mental health and a potential increase in domestic violence. To study the impact of the COVID-19 measures in Belgium, and the factors influencing the occurrence of domestic violence, we set up the study on relationships, stress, and aggression. In this study, we evaluate the prevalence of domestic violence victimization during the COVID-19 lockdown in Belgian children aged zero to seventeen years and the associations of the parents’ financial status, relationships, mental health, and previous victimization to the child’s victimization.
Methods
A stepwise forward binary logistic regression was used to analyse the association between multiple risk factors of domestic violence and victimization of the respondent’s child. The respondent being an assailant, the respondent’s age, and the age of the children in the household were added as moderators.
Results
In this model an association with domestic child abuse was found for the age of the respondent, the household’s size, the presence of children between zero and five years in the household, the perceived stress level of the respondent, and victimization of the respondent during the first wave of the sanitary measures, as well as victimization before the COVID-19 pandemic. None of the interacting effects were found to be significant.
Conclusion
It is advisable to make extra efforts to improve well-being when maintaining sanitary measures by providing appropriate assistance and helping households struggling with increased or acute stress to install positive coping strategies - especially in larger households with children between six and 17 years. Besides, our findings draw attention to the clustering of risk of child and adult violence exposure in lockdown situations as well as to the potential cumulative impact of exposure to violence across the lifespan and across generations. It is key to invest in training healthcare workers and staff at schools to screen for and assess risks of domestic violence development and ongoing or past occurrence in order to detect, refer and follow-up on families at risk.