bluuebunny/crossref_metadata_2025_split huggingface dataset:
Domain Driven Methodology Adopting Generative AI Application in Oil and Gas Drilling Sector
Authors: Ponomareva Daria , Droubi Nour El , Jundi Obeida El , Assaf Georges , Mustapha Hussein , Kindi Zainab Al 
Published: November 2024

AbstractIn dynamic landscape of oil and gas drilling, Generative Artificial Intelligence (Generative AI) emerges as the indispensable ally, leveraging historical drilling data to revolutionize operational efficiency, mitigate risks, and empower informed decision-making. Existing Generative AI methods and tools, such as Large Language Models (LLMs) and agents, require tuning and customization to the oil and gas drilling sector. Applying Generative AI in drilling confronts hurdles such as ensuring data quality and navigating the complexity of operations. A methodology integrating Generative AI into drilling demands is comprehensive and interdisciplinary. Agile strategy revolves around constructing a network of specialized agents of LLMs, meticulously crafted to understand industry-specific terminology and intricate operational relationships rooted in drilling domain expertise. Every agent is linked to manuals, standards, specific operational drilling data source and it has unique instructions optimizing computational efficiency and driving cost savings. Moreover, to ensure cost-effectiveness, LLMs are selectively employed, while repetitive user inquiries are addressed through data retrieval from an aggregated storage. Consistent responses to user queries are provided through text and graphs revealing insights from drilling operations, standards, manuals, practices, and lessons learned. Applied methodology efficiently navigates inside the pre-processed user database relying on custom agents developed. Communication with the user is set in the form of chat framed within a web application, and queries on the database about hundreds of wells are answered in less than a minute. Methodology can analyze data and graphs by comparing Key Performance Indicators (KPIs). A wide range of graph output is represented by bar charts, scatter plots, and maps, including self-explaining charts like Time versus Depth Curve (TVD) with Non-Productive Time (TVD) events marked with details underneath.Understanding the data content, data preparation steps, and user needs is fundamental to a successful methodology application. The proposed Generative AI methodology is not just a tool for data interpretation, but a catalyst for real-time decision-making in complex drilling environments. Its integration into oil and gas drilling operations signifies a pivotal advancement, showcasing its transformative potential in revolutionizing the industry's landscape. This approach leads to notable cost reductions, improved resource utilization, and increased productivity, paving the way for a new era in drilling operations. A method driven by selective, cost-effective, and domain specific LLM agents stands poised to revolutionize drilling operations, seamlessly integrating generative AI to amplify efficiency and propel informed decision-making within the oil and gas drilling sector.
Establishing Key Process Design Considerations for Carbon Capture, Utilization and Storage (CCUS) Towards Decarbonization of Existing Assets Operations
Authors: Sahak Muhammad Zakwan Mohd , Zain Masniroszaime Md , Alias Azila , Zulkifli Muhammad Yazid , Rohani Siti Nurliana , Rostani Khairul 
Published: November 2024

Abstract
With the net zero emission (NZE) commitment by 2050 following COP26 being pledged by country and industrial leaders, the technology focus for CCUS has shifted from high-CO2 gas field development to also include capturing CO2 from other industrial emission sources e.g. flaring and gas turbines. With the expanding scopes, careful consideration especially from process design perspective needs to be taken to ensure the overall CCUS conceptual design is techno-commercially feasible and viable to meet the CCUS end target and NZE aspiration in the long term. Process design intent shall start with the input-output specifications, where main input specifications would be looking at source or CCUS fluid (e.g. gas field/flare stack etc.) which will determine the type of CO2 capture technology required. Target output usage (storage/ utilization) will affect the tail-end process design, since both require different process setup. Other considerations would also be: (1) location (onshore vs offshore) which will affect the facilities network and logistics, (2) contaminants such as SOx and NOx which will determine other treatment requirements and affect the final use of the separated CO2-rich stream (utilization, storage strategy), and (3) material selection for the mixed contaminants stream. Depending on the concentration of CO2 in the source, a series of treatment steps may be required to get the optimum recovery for further utilization and storage. The presence of other contaminants is also discussed, which may affect the overall CCUS processes. Method to either utilize the separated CO2 stream or injection to reservoir for storage is also explored. An integrated approach is required to ensure a successful CCUS process design from start to end. Challenges and lesson-learnt from a conceptual CCUS system are analyzed including technology maturation, presence of other contaminants and final use of CO2-based products/storage. The technical and commercial aspects associated with each technology are also addressed. Key design elements are proposed with aspiration of a successful CCUS implementation in reducing future carbon footprint and realizing NZE aspiration and decarbonization goal, requiring planning for end-to-end solutions.
Using WAG Laboratory Data to Derisk Water Injection at the Gas-Oil Contact on a Giant Offshore Field
Authors: Bourgeois Marcel , Satken Bauyrzhan , Goyal Praffula , Al Eissaee Shaima Saeed , Cottin Christophe , Draoui Elyes 
Published: November 2024

Abstract
The current development strategy of this field is focused on the oil rim, it involves downdip water injection and gas injection in the gas cap to maintain the pressure. A co-development of the oil rim with the large gas cap is being tested at pilot scale and considered at large scale, it requires to create a water fence or water barrier by injection water in updip position, near the gas cap, to isolate if possible oil rim and gas cap, and avoid oil movement into the gas cap. This should enable production of gas and condensate from the gas cap, and still continue simultaneous oil production of the oil rim. This co-development program requires drilling of numerous inner ring water injectors, the well count and placement need to be optimized with help of 3D simulation, which requires relevant flow functions (like KRs). This paper is focusing on the laboratory program followed to quantify these 3-phase flow functions, which happened to be very close to the SCAL program used to constrain WAG operations.
Interesting findings related to these measures are presented and discussed. It was found that the near-miscible gas flood clearly outperformed waterflood, and the beneficial gas-oil interaction could be quantified. Three-phase flow (water and gas injection successively) clearly outperformed 2-phase flow, and a succession of several short slugs was also better than long slugs. Trapping of gas by water was also rather low, except if several cycles were followed. Water behavior was also quite surprising, as its mobility in presence of gas was measured higher than expected during imbibition, which implies to increase the water injection rates and water treatment facilities in order to maintain the water barrier in the project, but will also have implications on the water cut and eruptivity of oil producers in the oil rim.
When water injection ceases, as in WAG operations when switching to gas, or for intermittent water injection, water mobility was found to be very low for the drainage phase, and water trapping was clearly documented despite rate bumps in the gas injection. This could be interpreted by hysteresis affecting also the water phase, and can be explained logically by water being the least wetting phase in an oil-wet near-miscible environment. This mechanism may be of importance, as it may stabilize the updip water fence if water injection rates are reduced.
Study on Carbon Dioxide Flow Mechanism in Unconsolidated Sandstone Aquifer Based on Digital Imaging Techniques
Authors: Sun H. , Liu X. , Yuan C. , Ge T. , Ren X. , Shi W. , Sun L. , Zhang H. , Arif M. 
Published: November 2024

Abstract
The geological sequestration of carbon dioxide (CO2) pertains to the permanent storage of CO2 by injecting it into underground structural reservoirs. Saline aquifers are ideal locations for CO2 storage due to their extensive distribution and high storage capacity. Understanding the behavior of CO2 in such geological formations is of paramount importance for the efficient implementation of carbon capture and storage (CCS) strategies. However, many saline aquifers consist of unconsolidated sandstone, and some experimental procedures for exploring the flow behaviors of CO2 are rather challenging. In this study, three plugs of unconsolidated sandstone are selected from a drillhole situated in an offshore basin in China. Modern digital imaging techniques, such as X-ray computed tomography (XCT) and magnetic resonance imaging (MRI), are employed to obtain three-dimensional (3D) pore structures and record the CO2 flow behavior in the plugs during core flooding experiments. This study delves into the intricate relationship between CO2 injection rate, storage capacity, and storage efficiency, revealing a compelling trend. Specifically, as the injection rate of CO2 increases, there is a corresponding enhancement in the storage capacity, enabling a greater volume of CO2 to be trapped. Furthermore, this increased injection rate also leads to an improvement in storage efficiency, indicating that the process becomes more streamlined and effective. In summary, this study underscores the pivotal role of injection rate in optimizing the performance of CO2 sequestration, thereby contributing to more efficient and sustainable CO2 storage solutions. This study also reveals the migration behavior of supercritical CO2 in the connected rock pores from a microscopic scale and provides valuable insights into the fluid dynamics and transport processes of CO2 in the demonstration project of CCS.
Japan's New Laws Regarding CCS, Hydrogen, and Ammonia
Authors: Ishido Shimpei , Konno Hiroyasu , Muramoto Shizuka 
Published: November 2024

The year 2024 has marked the advent of the CCS industry and the hydrogen and ammonia industry in Japan. On 17 May 2024, the Japanese Diet (parliament) passed two legislations, namely, the Carbon Dioxide Storage Business Act ("CCS Act") and the Act on Promoting the Supply and Utilization of Low-Carbon Hydrogen, Etc, for a Smooth Transition to a Decarbonized Growth Economic Structure ("Hydrogen Society Promotion Act"). These legislations were promulgated on 24 May 2024.
The CCS Act is principally a domestic law governing the conduct of CCS activities within the territory of Japan, covering exploration and prospecting of reservoirs, storing CO2 in reservoirs, and pipeline transport of CO2 for storing CO2 in reservoirs (including reservoirs in foreign countries). The Hydrogen Society Promotion Act establishes a plan certification system for low-carbon hydrogen/ammonia supply and use projects, provides support measures and special regulatory measures for hydrogen/ammonia supply or use businesses that have received plan certification, and takes other measures to expand the supply and demand of low-carbon hydrogen/ammonia. These legislations are expected to promote the nascent CCS and hydrogen/ammonia industries in Japan.
In this paper, we will focus on the aspects of the regulatory regime under the CCS Act that are relevant to a cross-boarder CCS project in which CO2 captured in Japan is exported to and geologically stored in a reservoir abroad, and the aspects of the Hydrogen Society Promotion Act that are relevant to the procurement of low-carbon hydrogen and ammonia from abroad by Japanese users.
Reducing False Alarms for Early Kick and Loss Detection (EKLD) in Real-Time Application Using Knowledge-Assisted Case-Based Reasoning
Authors: Zhang Shang , Samuel Robello 
Published: November 2024

Abstract
Recent advancements in Early Kick and Loss Detection (EKLD) have leveraged various sensor information in real-time for detection and time-series trend analysis. However, the increase in data and complexity has led to a higher rate of false alarms, undermining the reliability and usability of the system. In this study, we developed a Knowledge-Assisted Case-Based Reasoning (KACBR) approach by integrating historical data with contextual knowledge to reduce the false alarm rate while maintaining detection capabilities. The expert system employs a hybrid methodology that combines the structured domain knowledge from Knowledge-Based Expert Systems (KBES) with the flexibility, robustness, and adaptability of Case-Based Reasoning (CBR). The model was validated and evaluated using real-time drilling data from the field. Employing the hybrid approach developed in this study, significantly reduced the overall false alarm rate while maintaining high performance in event detection. Field testing in real-time confirmed the system's effectiveness in detecting both kick and lost circulation events across all drilling phases without compromising the speed of real-time monitoring. Comparative analysis with traditional kick and loss detection methods and statistical trend-analysis-based systems revealed that the Knowledge-Assisted Case-Based Reasoning (KACBR) approach excels in reducing false alarms and maintaining detection reliability.
Enhancing Efficiency and Sustainability in Offshore Oil and Gas Operations through Digital Twin and AI Technology: A Practitioner's View
Authors: Zhang Yale , Lau Lukito , Yanchus Paul , Forootan Zaman , Marfatia Zaid 
Published: November 2024

Abstract
This paper explores the integration of digital twin technology and artificial intelligence (AI) to enhance efficiency and sustainability in offshore oil and gas operations. It demonstrates the benefits of combining digital twins with AI and first-principle modeling through two detailed use cases: an integrated power generation and electrical distribution system twin designed for emission reduction, and an upstream process twin for equipment constraint monitoring and process debottlenecking. Additionally, this study proposes a novel AI-based optimization strategy aimed at achieving integrated production optimization across topside and reservoir operations.
A Case Study on Engineering Techniques to Enhance the Reliability and Process Safety of Critical High Pressure Bolted Joints in the Oil & Gas Sector
Authors: Quraishi Tahirhasan , Sulaimani Mariam Mubarak Al 
Published: November 2024

Abstract
The bolted flanged joints assembly has a complex interaction between the bolts, gaskets and body of the flange. Joint integrity and sealing performance are dependent on the various characteristics such as gasket properties, geometry, material, bolt pretension loads, assembly process and service conditions. In accurate bolt pre-tensioning can be the prevailing cause for joint leakage. On the other hand, excessive pre-tensioning can lead to damage to the bolts and gaskets. Any upset or abnormal loads which may occur during the service period can also adversely affect the bolted flanges joint integrity and thereby increase their tendency to leak and elevate the risk of damage. Therefore, critical bolted flanged joints subjected to complex working conditions in the Oil & Gas Industry require a safe and reliable design approach.
This paper demonstrates a case study as how elastic-plastic stress analysis with the aid of cutting-edge Finite Element Analysis was applied to handle the modification of change of the 46″ New Main Gas Pipe Line (NMGL) which was impacting the large bolted flanged assemblies installed in the ADNOC Offshore upstream processing facility subject to the complex working conditions.
The key objective here is to determine the appropriate bolt pre-tension loads to maintain the joint's leak tightness without damaging the components, establish the maximum plastic collapse load for the assembly, assess the joint leakage performance for the complex service conditions thereby achieve optimal design, ensure joint integrity, process safety and prevent any major modifications to the associated facilities.
Planning and Implementation of the Shore Crossing Landfall of Heavy Pipelines Using High-Capacity Linear Winches
Authors: French G. , Massie S. 
Published: November 2024

An often-overlooked aspect of installing a new pipeline between offshore and onshore locations is the methodology of the shore crossing section of the installation. This is often a relatively short section of the pipeline which must cross the landfall interface between the marine and shore side installation sections which have well established and proven methods and equipment for their operations in their respective environments, but which cannot operate effectively in the shore crossing section.
It is therefore important to ensure this section is also fully considered, budgeted, planned, and prepared for in advance of commencement of the operational phase to minimize project issues, delays, and cost overruns.
Drawing on the experiences of the authors in providing turnkey solutions for these operations, this paper aims to provide some guidance to project managers of potential pipeline installations on some of the key considerations to contemplate to ensure sufficient preparations are in place at the onset of these projects.
Comprehensive Fluid Sampling Program Maps Compositional Gradients in Near-Critical Fluid Systems in a Giant Offshore Field
Authors: Bascialla G. , Mogensen K. , Javid K. , Almehairbi S.M. , Mohamed M. Ibrahem , Zirotti G. 
Published: November 2024

Abstract
This paper describes a fluid characterization study and equation of state (EOS) modelling for an offshore carbonate field composed of five reservoirs. The fluid column grades from gas condensate to black oil, passing through a critical point. Crest miscible gas injection was implemented soon after field start-up and peripheral water injection recently started for full pressure maintenance. The outcome of the sampling program has had a profound effect on the field development strategy. The understanding of the compositional gradient of the four main reservoirs of the field has been considered critical for the success of the project. More than a hundred downhole samples were taken at different depths during appraisal and development phases to delineate the gradient and model the fluid behavior. The detailed fluid database includes conventional PVT analysis as well as slim tube, swelling tests and equilibrium constant experiments. We calibrated the equations of state and regressed the observed gradient to implement it in the compositional reservoir simulator.
All the reservoirs showed complex, variable slope, compositional gradients. The observed data was used to fit a function with depth which accounts for the gravity segregation of the components and the steady heat flow effect. The saturation pressure changes with variable gradient across the thick fluid column. This had a major influence on the field development strategy; oil producers were drilled in the peripheral, deeper areas of the field to be able to reach higher pressure drawdown. In contrast, gas is injected at the crest, where highly volatile oil and gas condensate is located. Slim tube experiments at selected depths proved that the injected gas is miscible below the initial reservoir pressure. The current study describes the challenge of modelling and characterizing the reservoir fluids when a complex compositional gradient exists. It also shows the importance of understanding the distribution of the fluid properties for the success of the field development. We believe that the extent of the fluid sampling program to delineate the compositional gradients is unprecedented in the industry.
Revolutionizing Remote Areas Operation and Activities through Robotic Operator Round
Authors: Alkhoujah K. , Pankajkumar P. , Al Ghassani M. , Al Ali A. , Al Ameri M. 
Published: November 2024

Abstract
ADNOC Sour Gas operates a gas processing facility with over 23% H2S, requiring the safest possible operations in the hazardous area "red zone". To reduce human exposure, ADNOC Sour Gas aims to deploy an ATEX-certified, dust zone-rated robot to conduct automated operator rounds. The robot focuses on digitizing routine tasks, avoiding human hazards, detecting emissions, verifying field gauges, and monitoring toxic gases. By automating these activities, the robot will achieve an initial 30% reduction in manual work, leading to cost savings and the ability to redirect employees to more complex operations. While challenges remain, the robot solution demonstrates the transformative potential of automation in revolutionizing remote and hazardous industrial operations, specially that, in an environment such as in ADNOC Sour Gas H2S exposure can cause serious health effects, such as respiratory failure, eye irritation, loss of consciousness, and even death. The high concentration of H2S in the red zone poses a constant threat to the operators, who must wear protective equipment and follow strict safety protocols. The robot can reduce the risk of H2S exposure by performing tasks that would otherwise require human intervention, such as checking for leaks, measuring gas levels, and inspecting equipment. The robot can also alert the operators of any abnormal conditions or emergencies, enabling faster and safer responses. It is worth mentioning that the deployed robotic solution is limited to ground level activities due to its mobility systems and it does conduct any work at elevated levels at the plant, which is still a challenge that the industry did not solve for ATEX Zones and Dust one.