bluuebunny/crossref_metadata_2025_split huggingface dataset:
Getting Practical About the Future of Work a Framework for Upskilling and Reskilling Based on Trends Impacting the Oil and Gas Industry
Authors: Saad Amal , Zohair Alifiya 
Published: October 2023

Abstract
The FoW is a forecast of how work, workers, and workplaces will evolve in the upcoming years (SHRM, 2022). According to McKinsey, by 2030, up to 30 to 40 percent of all workers in developed countries may need to move to new occupations or upgrade their skills significantly with the impact of Digitalization and Artificial Intelligence AI (Hancock, B., et. Al. 2020). For some organizations, the future of work is exciting. For most, it creates anxiety. Studies indicate variation in readiness for the future based on country, gender (LHH, 2022), and even generation (Chambers, N., 2019). While many organizations know that re-skilling and up-skilling will be required; most are not preparing for this yet (Hancock, B., et Al. 2020).
This research theorizes that the lack of action toward upskilling and reskilling may contribute to a lack of a usable framework. The study set out to identify the skills required for the future of work in the oil and gas industry. The study started with a comprehensive literature review to identify the key trends that would impact the global oil and gas industry in the short, long, and mid-term. Qualitative research was then conducted through focus groups with managers and executives from the industry to match each trend to skill requirements.
The results were compiled into a framework for organizations in Oil and Gas to plan for workforce upskilling and reskilling. The framework allows organization leadership to review their current workforce skills with the expected skills based on this future of work analysis and to create and implement programs that support upskilling and reskilling towards the future of work. This article makes recommendations for the implementation of such programs.
While the future of work is recognized as important by executives, there is a gap in practical frameworks like the one created by this research.
PDO Flare Management Transformation Towards NZE Journey
Authors: Al Waily N. A. , Al Riyami B. A. , Al Mahrooqi M. A. 
Published: October 2023

Abstract
The objective of this paper is to share insights of the best practices of Petroleum Development Oman (PDO's) in the energy sector as the leading organization in the country in the domain of flare management and transformation towards NZE journey. The scope of this paper shall entail both; soft initiatives and projects initiatives with examples of applications and post implementation with demonstrated results yielding tremendous step change improvements within the organization. Flare management is a key pillar in PDO's Decarbonization strategy, amounting to approximately 17% of its total GHG emissions (2nd largest contributor after power generation). Significant efforts were placed to reduce company's flaring emissions through an integrated manner approach and active emissions abatement programs consisting of cross-organizational projects, quick wins leveraging via process optimization and cultural change through awareness and training, strict waiver compliance and adherence to flaring limits. Management's role in driving changes was also vital to organizational and performance cultural change through monthly huddles and flaring accounting assurance via flare meters health checks reviews, proactive flare containment via Exception Based Surveillance and Gap to Potential Reliability Program for gas system reliability enhancement. Company's performance scorecard includes flaring as a key KPI and proportionally linked to total HSE performance. In 2022, PDO has reduced its gas flaring volumes by more than 46% compared to its 2019 levels. PDO also endorsed the Zero Routine Flaring (ZRF) initiative by the World Bank and hence flare recovery projects have been commissioned in addition to implementing new technology trials for small-scale volumes; an Energy Management System was developed which includes projects maturation funnel to ensure their timely and effective commissioning. A campaign was launched for passing valves to flare and repair plans and verification of sufficient combustion efficiency and flare measurements in accordance to Oil and Gas Methane Partnership (OGMP 2.0) pledge with the aim of achieving gold standard.
First Successful Hydraulic Fracture Treatment in Deep Pre-Khuff Clastics: Lessons Learned from the Implementation of Cutting-Edge Technology Offshore Abu Dhabi
Authors: Buijs H. , Ibrahim M. , Basioni Mahmoud , Alloghani J. A. , Elmahdi A. , Sayed S. , Swedan T. , Azoug Y. , Al Kaabi A. , Bulekbay A. , Efnik M. , Al Hammadi A. E. , Al Kindi R. K. , Al Aryani F. M. , Bregar U. B. , Nuriakhmetov R. 
Published: October 2023

Abstract
This paper describes the development and implementation of a multi-frac completion strategy that improved the well performance by more than 500% in the first successful hydraulic fracture treatment pumped in deep Pre-Khuff targets. The primary target reservoir is a deep tight gas sandstone that can be found at depths exciding 16,000 ft with temperatures above 350°F. Given the reservoir characteristics, primarily its low permeability, hydraulic fracturing is required to achieve commercial production rates. The design of the fracture stimulation treatment presented several challenging conditions including high formation temperature, closure stress, and fracture pressure with the potential for post treatment proppant flowback in an offshore environment.
The learning curve was collapsed by interdisciplinary evaluation of diverse data sets from legacy and newly drilled wells. Mechanistic models were employed in a grid-oriented planar 3D hydraulic fracture simulator to optimize treatments and to understand changes in production performance related to specific multi-fractured completion strategies, guiding the optimization process. This work led to the successful implementation nano-proppants, pseudo-stable fracturing fluids and, among other technologies, specialized perforation guns designed for low stress anisotropy conditions. This paper will provide insights on the results and lessons learned from the implementation of cutting-edge hydraulic fracturing technology that provided the means to overcome challenges to unlock hard to recover reserves.
Auto-Detecting Drilling Vibrations Through Intelligent 4IR Solution
Authors: Gowida Ahmed , Saadeldin Ramy , Gamal Hany , Elkatatny Salaheldin 
Published: October 2023

Abstract
Downhole vibrations have a significant impact on downhole equipment performance, wellbore stability, and drilling efficiency. High levels of drillstring vibration often led to equipment failure, hole problems, energy loss, and reduced drilling performance. Detecting these vibrations through downhole sensors is costly and time-consuming. However, advancements in new technologies and machine learning present opportunities for intelligent data analysis and addressing complex technical problems. In this study, a successful application of a machine learning technique was proposed to auto-detect downhole vibrations during the drilling curve section using surface drilling data. The axial, torsional, and lateral drillstring vibration modes were detected using random forests (RF) machine learning models trained with real field data. The model was developed through comprehensive data-driven research, including data collection, preprocessing, analytics, model optimization, and performance evaluation. Overall, the developed machine learning model achieved high accuracy, with R values exceeding 0.87 and average absolute percentage error (AAPE) below 8.4% between actual readings and predictions. The proposed ML algorithm offers an intelligent solution for predicting drilling vibrations using only surface drilling parameters, eliminating the need for downhole sensors. Implementing this solution on drilling rigs enables real-time monitoring of vibrations and supports automated advisory systems. It provides valuable insights for directional drillers and drilling engineers, facilitating drilling optimization, and improved well planning.
Enhancing Rigless Intervention Efficiency in Bi-Lateral Oil Producer Through Coiled Tubing Optical Telemetry, Multilateral Tool, and Single-Phase Retarded Inorganic Acid: A Case Study from South Kuwait
Authors: Al-Mutairi F. , Sanyal S. , Al-Mutawa M. , Al-Ayyaf E. , Al-Bader A. , Al-Otaibi A. , Al-Anezi T. , Al-Dhafiri S. J. , Al-Najim A. , Aldawaish M. , Al-Otaibi A. , Hedi Slama M. , Badrawy K. , Molero N. , Ujagar U. , Adel Sebaih M. , Ayyad H. 
Published: October 2023

Abstract
Developments in horizontal drilling and completion techniques have enabled drilling an increasing number of wells. In the pursuit of cost optimization and enhanced recovery through maximized reservoir contact, operators are placing special interest on multilateral completions. However, multilateral wells add complexity to rigless intervention and production enhancement work as those activities are heavily dependent on lateral accessibility.
An advanced rigless intervention in a multilateral well relied on coiled tubing (CT) equipped with optical fiber and real-time downhole measurements and a multilateral entry tool (MLT). Downhole readings included casing collar locator (CCL), gamma ray, CT internal pressure, annulus pressure, annulus temperature, and axial force. Optical telemetry was used for lateral identification and for optimal actuation of the orienting and bent sub-components of the MLT while profiling and accessing the lateral. Throughout the stimulation treatment, optical telemetry was instrumental to understanding changing downhole conditions and keeping injection rates below fracturing pressure.
The candidate well was a carbonate bi-lateral oil producer completed through 6 1/8-in. uncased horizontal sections. Both laterals exhibited average length of 2,400 ft, and the reservoir featured a bottomhole temperature near 140°F and bottomhole pressure close to 3,050 psi. Because of real-time optical telemetry, profiling of the lateral was completed in less than 3 hours, which represents 50% reduction of the average profiling time in similar wells. Both laterals were stimulated via CT with a total of 4,000 bbl of single-phase retarded inorganic acid system (SPRIAS), which enables carbonate stimulation with better wormholing performance than emulsified acid while eliminating its drawbacks, such as high CT friction pressure and potential emulsion issues. In comparison with emulsified acid, the pumping time with SPRIAS was 35% lower, bringing additional efficiency to the intervention. The ability to make fast, informed decisions based on optical telemetry was the cornerstone of this intervention approach.
This paper documents a value case study for CT rigless intervention in South Kuwait, where the combination of an array of technologies, such as CT optical telemetry, MLT, and SPRIAS, enhanced rigless intervention efficiency, reducing total operation time by 30%, when compared to conventional CT stimulation approach in multilateral wells.
Tracing the Origin of Annulus B Oil Return Using Integrated Geochemical Analysis to Identify the Effective Barrier Remediation Strategies, Case Study in Giant Gas Condensate Field
Authors: Alsaeedi A. , Gadelhak A. , Koksalan T. , Mubarak Albadi M. , Yassein D. , AlSaadi N. , Yan J. 
Published: October 2023

Abstract
One of the key aspects of sustainable production is to maintain the health of the reservoirs. The objective of this Paper is to demonstrate the establishment of best practices of geochemistry and its direct impact on well integrity by performing a reservoir to annulus oil correlation using geochemical methods in an onshore setting to establish the source of oil in the annulus. This application will significantly assist in assets sustainable production, future failure predictions and preventions.
Upon frequent observation of abnormal oil return from Annulus B of five gas wells, the herein approach was to identify the source of oil through specific geochemical analysis that consists of an analytical and interpretive protocol that defined to address the issue in an optimal and prompt manner using CSIA and Biomarker data. Simultaneously, an exercise to screen the wells integrity within one km radius was conducted to ensure that this unique challenge will not affect the nearby wells.
It was the 5th well with unexpected oil return from annulus B, Integrity Alarm was raised,it was not an isolated case,collected oil samples looked differently compared to produced oil for the same field,
Immediately, a compositional analysis was proposed but the uncertainty would have been high and the compositional similarity between reservoirs would have made the results inconclusive. Therefore, it was decided to perform Biomarker and Carbon Specific Isotope Analysis (CSIA) analysis.
Afterwards, the challenges were addressed and mitigated since this was a unique study conducted in such that: Availability of analysis within the existing PVT contractSecuring BudgetReceiving management approvalCollecting samples from reference oil reservoir for comparison
This study presents an application of geochemical analytical and interpretive protocols that includes CSIA and biomarker compositions of saturate and aromatic fractions of producing and annulus-B oils. By the end of the study the source of the oil return was identified, and a certain course of actions were listed. Then, remedial mitigation plan was put on place. Furthermore, six months of continuous monitoring targeting the nearby well's integrity took place where the suspected wells were treated with a comprehensive action on curing the well integrity challenges across assets.
Aging wells are a worldwide challenge and maintaining the wells flowing in healthy condition for as long as possible to reach or to exceed the wells expected life is what any organization is aiming for. This study has a significant outcome that can be scaled to the other wells and/or fields that encounter similar integrity issues. This implementation costs you a PVT sample but its game changer in the possible source of oil.
ESG. A Challenge for the Oil & Gas Industry?
Authors: Arboleda J. M. 
Published: October 2023

Abstract
The oil and gas industry has been constantly facing investment problems since 2014. The effects of the pandemic, combined with the geopolitical crisis in Europe, have offset the efforts made by OPEC and its allies to bring investment back to the market. Oil and gas suppliers have yet to find the formula to recall investments from financial institutions and other capitalists unwilling to increase capital. Price volatility, uncertainty about the oil demand outlook, and climate concerns prevent investors from acting.
For those reasons, many investing decision-makers are starting to demand fossil fuel companies for sustainability and/or ESG agendas, even if those agendas are not the most profitable option. Implementing ESG strategies in the oil & gas industry is no longer a voluntary option. It has become an obligation, especially if the company seeks international capital. But the implementation of ESG agendas in the oil & gas industry has arrived with several challenges. The lack of clarity and standardization to estimate the performance of ESG has cost trillions to the fossil fuel industry, bringing questions about the necessity of implementing ESG strategies and the benefits of their results.
This paper walks us through the challenges the oil & gas industry faces while implementing ESG agendas, highlighting the differences between International Oil Companies (IOCs) and National Oil Companies (NOCs). Private and hybrid oil companies have shown themselves to be more successful in implementing ESG, as their business model provides more flexibility in implementing business agendas and because IOCs are more susceptible to public pressure. NOCs play under different priorities and rigid structures that do not allow them to jump into activities other than those initially planned for the company.
Achieving Greenhouse Gas Management Success: How we Exceeded Our Target 8 Years Ahead of Schedule
Authors: Sricharoen P. , Dhanasin P. , Lertwiriyaprapa K. 
Published: October 2023

Abstract
This paper presents a case study of a leading national exploration and production company in Thailand, focusing on its pathways to decarbonization and long-term greenhouse gas emissions management. The company recognizes the importance of transitioning to a low-carbon economy and has set ambitious targets for reducing Greenhouse Gas (GHG) emissions intensity. The journey began since 2013, the company has been committed to lowering its emissions through various projects implemented in both domestic and international assets. By seamlessly integrating sustainability into its framework and strategy, the company addresses the challenges associated with GHG emissions effectively. Specific targets for reducing emissions intensity, primarily focusing on Scope 1 and Scope 2 emissions within its E&P operations have been set. The company has implemented a robust framework and strategy to ensure accountability and sustainability practices throughout its operations.
The company's climate-related risk management approach involves proactive risk assessment, incorporating climate change risks and opportunities into its enterprise risk management framework. The company has developed a comprehensive climate management plan to mitigate identified risks and ensure operational resilience in the face of climate change impacts.
Following the climate management hierarchy, the company prioritizes avoidance, mitigation, and offsetting efforts to manage emissions and align with broader environmental goals. Avoidance measures include portfolio screening and management, carbon pricing, risk management, due diligence, and engineering design philosophy. Mitigation efforts include flare and flash gas recovery, energy efficiency improvements, production optimization, and methane leak detection & repair. The company also emphasizes transparency, adhering to international standards, and disclosing relevant climate-related information to stakeholders.
The paper highlights the company's achievements, including surpassing its GHG emissions intensity reduction target eight years ahead of schedule. The company has successfully reduced emissions intensity by over 25% compared to the 2012 base year. The company's commitment to sustainability is demonstrated through its pursuit of net-zero GHG emissions by 2050, with interim targets in place for 2030 and 2040. To achieve this, they plan to deploy Carbon Capture, Utilization, and Storage (CCUS) technologies and support land and mangrove reforestation efforts.
Through partnerships with low-carbon technology providers and ongoing research and development, the company remains at the forefront of emission reduction strategies and actively contributes to global climate action.
Qualification and Deployment of a Nanocomposite Wellbore Sealant Water-Based Mud for Drilling a High Temperature Well
Authors: Kerkhoff Erik , Ismail Ahmed , Vlajie Mihai , Al Balushi Abdullah , Rekieh Aubyii 
Published: October 2023

Abstract
This paper describes the validation testing and field application of a nanocomposite wellbore sealant (NCWS) in a high temperature well. The inclusion of the NCWS in the high temperature water-based mud (HTWBM) exhibited tight and stable filtration characteristics, measured by high pressure high temperature (HPHT) and permeability plugging tests (PPT), as well as a notable reduction in drilling fluid viscosity.
The improvement in rheological profile reduced equivalent circulation density (ECD) and standpipe pressure (SPP).
A NCWS was identified during the well planning phase as the ideal technology for addressing the filtration and rheology.
A comprehensive suite of laboratory tests was performed to qualify the HTWBM formulation inclusive of NCWS performance, which included PPT and HPHT testing at 150°C. Rheology measurements were performed on a six-speed rheometer at 50°C.
The utilization of nanocomposite-treated water-based mud (NCWBM) resulted in notable enhancements in fluid performance as evidenced by the test results and when compared to offset salt polymer fluid formulations.
Hydraulic modeling showed reduction in ECD and SPP values using the NCWBM rheology results.
The NCWS was used in two wells, and fluid properties achieved exceeded expectations. The improved rheological profile was observed, which reduced the ECD and SPP values while drilling both wells.
The stability of the fluid proved consistent and easy to maintain over extended periods ranging from 22 drilling days on the first well to 39 days on the second well.
Wireline logging operations have been performed successfully, eliminating issues experienced on offset wells. Tight hole conditions while carrying out logging operations had increased the time required to successfully complete the data acquisition scope.
The inclusion of the NCWS in the HTWBM formulation resulted in some simplification of the fluid whereby two polymeric fluid loss additives were removed and the concentration of two additives was reduced by 50% and 75% respectively. The simplification of the fluid formulation resulted in more efficient logistics and lower inventory holding at the rig site, as well as a reduction in the lifting operations, and reduced manual labor required for mixing of the additives.
The NCWS was the key technology that developed the unique properties for the WBM. The NCWS is a proprietary nanocomposite suspension that provides enhanced sealing capacity to water-based drilling fluids. The additive is produced and applied as an emulsion and thus avoids the inhalation hazards associated with handling of dry nanomaterials (Jay P. Deville, Preston A. May, and J. J. Miller 2022; Fröhlich and Salar - Behzadi 2014).
Impact of Produced EOR Polymer on Production Facilities
Authors: Al-Murayri M. T. , Kamal D. , de Kruijf A. , Andrianov A. 
Published: October 2023

Abstract
Back-produced polymer to surface facilities is a significant topic in the literature due to the specific properties of the polymer, which are beneficial in the effective displacement of oil in the reservoir but could give challenges in the producers and surface facilities. This literature review addresses the impact of polymer on the key components of the production facilities ranging from artificial lift to the oil refinery and produced water disposal or reuse. The main polymer properties to interfere are (1) the ability to increase the viscosity of the produced water and (2) the precipitation of the polymer with constituents in water or process chemicals. These two properties could cause equipment failure, off spec quality of the oil and water, leading to oil deferment and increased maintenance. The magnitude of these challenges depends on the level of back-produced polymer. From the literature it is difficult to diagnose at what polymer concentration, insignificant impact is observed and when the production issues begin. It is recommended to analyse each key component individually and assess at what polymer concentration impact is expected in the operations. Important to identify is that an optimal polymer selection for the subsurface reservoir, might not be the right choice for the production facility. Therefore, early involvement of surface and chemical engineers is crucial to a successful polymer flood. This review will discuss a selection of the available literature addressing the main challenges and showing several examples. The content of a monitoring plan is discussed as well as the critical & additional analysis are given to properly understand the production side of a polymer flood and assist with mitigation strategies.