bluuebunny/crossref_metadata_2025_split huggingface dataset:
Maximizing & De-Bottlenecking Gas Export with A Sustainable Approach Using Six Sigma Tool
Authors: Al Kindi Zeyana , Al Hadhrami Abdullah , Al Maskari Mubarak , Al Saifi Saud , Bawdekar Mangesh Ashok 
Published: November 2024

Abstract
The implemented endeavor stands as a pivotal milestone in the nation's trajectory towards attaining cost competitiveness and curbing gas emissions, embodying a dual-fold value proposition characterized by both direct and indirect revenue implications. The debottlenecking of the Gas export system, culminating in a notable 5% increase of production in export gas flowrate serves as a direct catalyst for revenue augmentation, synergistically accompanied by a significant surge of approximately 2% in condensate production. Projections indicate a short-term cumulative revenue upswing of up to 10% annually direct revenue (Cash Flow), poised to ascend impressively to 25% of budget increase per annum over the long haul.
Indirectly, the amalgamation of stations and initiatives aimed at skill development underscores a broader spectrum of influence, encompassing the mitigation of excessive flaring, harmonization with low carbon emission targets, and the cultivation of human capital in accordance with national imperatives. These enhancements align seamlessly with Petroleum Development Oman's unwavering commitment to fulfilling SGL supply requisites, thereby bolstering the nation's standing on the global stage.
The undertaking, characterized by a 5% production of gas export amplification, reaffirms the organization's stature as a reliable gas provider, emblematic of its steadfast dedication to enhancing production efficiency. Emphasis on gas emission reduction and energy conservation, epitomized by heightened compressor efficacy and ensuing energy preservation, resonates with renewed HSE priorities.
Moreover, the project serves as a testament to innovation, evidenced by the prioritization of emergent gas technologies and the seamless integration of Six Sigma methodologies. Insights gleaned from this endeavor hold promise for replication across Petroleum Development Oman and Oman, promising streamlined energy utilization and cost mitigation to fortify competitiveness in the forthcoming energy landscape.
Experimental and Numerical Study of Anomalous Imbibition in Shale Gas Reservoirs
Authors: Zhang M. , Sun Q. , Ayala L. F. 
Published: November 2024

Abstract
This paper investigates the phenomenon of anomalous imbibition in shale reservoir rocks through a combination of numerical and experimental approaches. Shale gas reservoirs present unique challenges due to their low permeability and complex pore structure, significantly influencing fluid transport mechanisms. Spontaneous imbibition, where water (or fracturing fluids) infiltrates the shale matrix and displaces the gas driven by capillary force, plays a critical role in the recovery efficiency of shale gas reservoirs. Fluid spontaneous imbibition in heterogeneous porous media, such as tight and shale formations, often exhibits anomalous behavior dominated by multiple time-spatial scales. Based on direct experimental evidence of anomalous imbibition process, this work proposes a fractional derivative model to quantitatively analyze the complete early-to-late time dynamics of the anomalous imbibition in shale gas reservoirs. Prior research on the anomalous imbibition process has primarily focused on fractal models and has compared results with indirect indicators, such as the cumulative imbibed volume derived from imbibition experiments. This study introduces direct observations and quantifications of the anomalous imbibition dynamics, utilizing saturation distributions converted from Computed Tomography (CT) numbers. A fractional diffusion model is proposed, and the resulting non-linear fractional differential equations are solved numerically using the finite-difference method. The proposed model solution accurately captures the complete early-to-late time behavior of cumulative recovery volume and the wetting phase front propagations which exhibit anomalous phenomena.
Data Driven Alarm Rationalization: Implementing Effective Alarm Systems in Oil Field Operations
Authors: Al Shueili H. H. , Al Alawi R. M. , Al Amri A. 
Published: November 2024

As the oil and gas industries progressively relying on modern automated control systems to monitor, control and safeguard plants, alarms can be configured with very small effort and high volumes. Therefore, the number of alarms can become overwhelming for the operators dealing with more alarms than the usual. Subsequently, leading to alarm fatigue where important alarms can be ignored or missed. This increases the difficulty of responding to plants' upset which can lead to possible accidents or unplanned shutdowns.
Alarm rationalization is the critical process of analyzing, evaluating, and refining alarm systems to ensure that alarms are meaningful and actionable. This process involves reducing the high number of redundant or false alarms, categorizing them based on their priority, and ensuring that each alarm provides clear and actionable information. The main goal is to minimize unnecessary or false alarms, improve the plant's safety and enhance operational reliability by having the operators focus on the critical alerts.
In this paper, we explore how a data-driven approach was applied to improve alarm systems in a heavy oil field operation. By enforcing the "Alarm Documentation and Rationalization (D&R)" procedure, we developed a robust system that uses data analysis to create an action-driven alarm system. This system is designed to alert and guide operations to corrective actions without causing distraction, confusion, or conflict. We describe the methods, procedures, results, and conclusions of the project, showcasing how it significantly reduced unnecessary alarms and boosted operator efficiency.
A Study on Supply Chain Management of LNG Using Artificial Intelligence
Authors: Susan Koshy Nicy 
Published: November 2024

Abstract
The use of Artificial Intelligence (AI) in the supply chain management (SCM) of liquefied natural gas (LNG) is an important turning point with far reaching impact on the industry. It focuses on how AI technologies can help optimize different aspects of the LNG supply chain such as demand forecasting, inventory control, route optimization and risk management. The study looks into how it facilitates visibility across the entire supply chain, manage risks associated with international sanctions and embargoes and assesses its influence on energy efficiency and emissions. Employing mixed-method approach that includes qualitative interviews, case studies and quantitative analysis, this research provides comprehensive insights as well as actionable recommendations. The findings indicate that AI has potential to revolutionize LNG SCM through increased operational efficiencies, lower costs, and more sustainable/resilient operations.
Should We Worry About Our Field Development Planning due to Compaction Acceleration?
Authors: Bernadi B. , Ferdaos M. , Awadhi F. O. Al , Ameri S. A. Al , Shamsi A. B. Al , Albairaq A. , Ali R. Al , Dhanhani H. Al 
Published: November 2024

Abstract
Reservoir A is a mature carbonate gas-cap field that has been depleting gas for a long time. Reducing the compression pressure can increase the gas recovery. But this can also speed up the reservoir compaction due to higher withdrawals, which can cause subsidence, permeability reduction, wellbore instability, completion integrity, etc. To prevent this, history-matching exercises with Assisted History Matching (AHM) technique are used to investigate the minimum pressure that would start shrinking the porosity.
AHM is a way to find the best values of the uncertain parameters that minimize the mismatch between the simulated and observed data. Objective functions (OF) are used to match the production and pressure within a small defined tolerance. The reservoirs are split into 6 sectors for easier analysis. After doing AHM exercises, the best cases are chosen and various cross-plots are made to see how OF and history-matching variables are related. The cases with the strongest relationships are checked to see if modifying the rock compaction can be the most likely option to improve the history-matching.
In the initial attempt with AHM, the simulated pressure in the southern sector consistently surpasses the actual pressure, whereas the opposite is true for the northern sector, especially in recent times. This discrepancy remains even after adjusting factors such as permeability, fluid contact, reservoir pore volume, and transmissibility during the history-matching process. The variation in pressure might be due to different compaction rates across the gas cap zone. Utilizing two separate rock compaction tables that transition from fast to slow from north to south could potentially improve the pressure matching.
Future reservoir development, either through infill wells or field compression projects aimed at reducing abandonment pressure, may negatively impact the safety and economy of both sub-surface and surface facilities. To mitigate these risks, it is essential to avoid excessive production withdrawal, particularly in regions where a faster rate of compaction could pose a threat.
Compaction acceleration can affect the future development plan of reservoir A, by reducing the recovery factor, increasing the risk of reservoir subsidence, well issues, altering the optimal design of the new wells and the compression system. The study with AHM can help to evaluate how serious the compaction problem is for reservoir A, and it can recommend the need to initiate more sophisticated geomechanics modelling if it is essential.
Longest Lateral Section Drilled in Pakistan with the Underbalanced Drilling Methodology in a Challenging ERD Well in a Naturally Fractured Reservoir Structure – A Novel Approach Toward Innovative Drilling Techniques
Authors: Uzair Qadir Shaikh , Qasim Ashraf , Hassan Raja , Ahmed Qureshi Haris 
Published: November 2024

Abstract
The X Field, located in Sindh on the right bank of the Indus River, contains a shallow carbonate reservoir structure that is present at a depth of about 650m TVDSS. After continual production from the reservoir, the reservoir pressure has been depleted to sub-normal at ~0.6 SG equivalent mud weight (EMW).
While drilling with a conventional mud system encountered total losses and resorted to heavy lost-circulation material (LCM) pills to cure them. All bridging materials pumped in the hole to cure losses invaded the reservoir formation. As a result, the completed well required excessive cleanup operations to bring it into production. Therefore, faced additional costs of loss curing materials, damage to the reservoir formation, and a substantial amount of time for drilling and cleanup operations.
It was planned to look for a solution to not only reduce the costs associated with drilling this highly depleted reservoir formation, but also mitigate invasion damage that inevitably affects overall production. Although underbalanced drilling had been used in similar situations, but the challenges associated with this well were quite enormous. The horizontal well design contained a lateral of about 778m. Challenges to account for while drilling the horizontal leg included designing appropriate directional drilling equipment for use with a multiphase fluid, cleaning the hole in the horizontal leg, maintaining underbalanced wellbore pressures in the presence of high annular pressure loss.
For this reservoir pressure of 0.6 SG EMW, a nitrified foam system was designed to achieve an equivalent circulating density (ECD) below 0.6 SG EMW. This foam system was designed using a formulated polymer system to yield a high foam quality for suspension and cutting carrying capacity. Geosteering was also performed using RSS, EM-MWD and LWD tools in multiphase fluid system to optimize well placement. In addition, a downhole deployment valve (DDV) deployed inside the casing string enabled isolating the live well while tripping. Applying all these innovative methods the drilling of this cumbersome section was completed in just 4.5 days having an avg ROP of 26 m/hr. Most importantly this methodology helped us to achieve zero skin drilling hence resulting in unprecedented production enhancement from this well. The paper outlines the planning and design of this unorthodox well, its execution, and the results achieved.
Reservoir Operating Envelope Recommendations as Input into Limit Diagrams for HP/HT, Complex, Sour Carbonate Reservoirs
Authors: Saffar Al , Abdullah B. , Radha F. , Benkhalaf S. , Aldhoubi E. , Ameer A. , Sabti A. , AlJasmi S. , Emera A. Mohammed , Taheri S. , Nishi K. , Khakmedov Azat , Al Saleh A. , Al-Ajmi A. 
Published: November 2024

Abstract
Reservoir offtake limits can be imposed for fields or certain areas per field or certain reservoirs as deemed necessary for safe and optimized production/operation of a hydrocarbon bearing reservoir. Key reasons to limit the production offtake for a certain field can include: Safeguarding long-term URMinimizing water production, thus avoiding artificial lift or any integrity (corrosion) issuesMaximizing key hydrocarbon phase productionWell, Reservoir and Facility Management (WRFM) purposes
Reservoir offtake limits were established for HP/HT deep Middle Marrat (MM) reservoirs (gas condensate and volatile oil reservoirs) using the dynamic simulation models.
These reservoir offtake limits are the average rates that can be produced without negatively impacting the long-term value (i.e., UR) or short-term excessive water production. With all constraints removed from the dynamic simulators except flowing bottom hole pressure (FBHP) and/or drawdown (i.e., CIBHP – FBHP), these limits reflect the capability of the reservoirs with the current well stock independently of any restrictions in the tubing, choke or back pressures from the facilities.
Thus, these reservoir offtake limits may not be realizable with the current facility/well/choke/flowline arrangement., i.e., for example compression, pumps or artificial lift may need to be installed to deliver these rates. These limits are proposed to maximize the long-term revenue value ($). Next step is to use these reservoir limit into the system limit diagram to determine asset production limit considering all production system (reservoir, facility, well, chokes, and flowline). Output from this work is a list of production rates and constrains including DD limits in order to safely produce the reservoirs.
These analyses helped to support optimizing production from current producing wells in a safe and efficient way which enhance reservoir health and optimize operation envelop. This is a very important part to safely and optimally manage reservoir performance without impacting long term value through determine and reduce impact of any bottleneck in the production system.
Robust Workflow to Assess and Optimize Condensates Recovery from Rich Gas Reservoirs: A Case Study from Abu Dhabi, UAE
Authors: Ojha Aditya , Latypov E. , Sudarev M. , Bernadi B. , Albairaq A. , Alawadhi F. , Mengal S. , Al Shamsi A. 
Published: November 2024

ABSTRACT
Optimal recovery from a rich gas condensate reservoir is always a big question for an E&P operator, wherein the correct choice between prioritizing condensate recovery or gas exports must be made at the right time. This paper discusses a detailed technical evaluation workflow which highlights all the steps required to be executed to make an informed decision towards implementing an optimized reservoir management scheme, through a case study from onshore Abu Dhabi, UAE.
The workflow starts with an in-depth evaluation of available data followed by an exhaustive well screening and candidate selection for extracting sectors from an existing subsurface model. The sector selection process honors the variation of rock properties, wells' performance, expected condensates dropout volumes etc. The next task is to enhance the existing sector models to accurately model condensate drop out and blockage phenomena. The impact of Non-Darcy flow and velocity dependent relative permeability on wells' performance is captured and modeled appropriately. Assessment of the impact of CO2/N2/Chemical injection along with injection volumes & rates on sectoral performance, is made.
The detailed workflow has been used to identify and investigate several reservoir management strategies viz. drilling infill producers, MRC peripheral injector wells, non-HC gas injection, chemical injection etc. Furthermore, the optimized time for blowdown has been identified, precisely balancing the prioritization of condensates recovery along with gas sales.
It has been identified that after ~50 years of production under partial lean gas recycle mode, ~ 27% of the initial condensate in place has already dropped out as liquid in the reservoir, which would increase to ~34% in the next 60 years if the planned reservoir management scheme is not modified.
Appropriate non-HC gas (CO2 /N2) injection schemes along with carefully planned peripheral MRC gas injectors and infill wells, could potentially mitigate the risk of losing precious condensate in the reservoir and increase recovery to 75-80%. A carefully planned chemical injection scheme could also reduce the risk of near wellbore condensate blockage. The proposed development schemes need to go through further evaluation of risk assessment, project economics and piloting phases to substantiate the recovery numbers.
Integrated Approach to Enhance in Low-Performance Tight Reservoir Wells
Authors: Yaqoubi Nouf Al , Mengal Salman , Ojha Aditya , Bernadi Bondan , Shehhi Hajar Al , Morrow Timothy Ian , Agbari Zainah Al , Deshmukh Rohit V. , Almteiri Nama , Bairaq Ahmed Al , Dhanhani Helal Al 
Published: November 2024

Abstract
This paper delves into the establishment of a comprehensive procedure for the evaluation of underperforming wells, alongside an analysis of the present and anticipated future conditions of a significant, onshore natural gas asset located in the United Arab Emirates. The implemented process has brought to light viable opportunities that could significantly enhance productivity. These opportunities include the matrix stimulation of current wells, which is a technique designed to improve the flow of hydrocarbons by removing blockages within the wellbore, thereby optimizing the extraction process. Additionally, the process involves expanding the reservoir contact, which effectively increases the interface area between the well and the reservoir, allowing for a more efficient recovery of stranded potential reserves. This approach is particularly advantageous as it circumvents the need for drilling new wells, thereby reducing operational costs and minimizing environmental impact. The findings from this comprehensive evaluation suggest that by adopting these strategies, it is possible to revitalize existing assets and unlock additional value from the natural gas field.
Application of Generative AI to Derive Insight from Supply Chain & Logistics Contracts
Authors: Singh Ajay , Jia Tianxia , Nalagatla Varun , Cunningham Brian , Siwani Talib 
Published: November 2024

Abstract
Contract management is a critical process for energy companies operating across upstream, midstream, and downstream sectors. These companies deal with numerous complex contracts containing intricate legal language, cross-references, and long document lineages spanning amendments and supplemental materials. Manually extracting insights and managing obligations from these highly unstructured contracts is extremely time-consuming and error-prone. This paper presents a novel framework leveraging machine learning and generative AI (GenAI) to automate and streamline contract management. The proposed solution utilizes large language models (LLMs), prompt engineering, retrieval-augmented generation (RAG), and chain-of-thought reasoning to extract structured data (such as fees, escalations etc.) from contracts, perform analyses, and generate natural language responses. It enables use cases like optionality analysis, fee calculation, cross-contract insight generation, invoice processing, and user feedback integration. The architecture combines LLMs with contract knowledge bases and external data sources to optimize operations, mitigate risks, and enhance decision-making. Key capabilities include centralized repositories, clause extraction, compliance tracking, workflow automation, and advanced analytics leveraging LLM question-answering, summarization, and code generation abilities. The paper discusses technical details, use case scenarios applicable to crude oil transportation contracts in supply & chain, and highlights GenAI's potential to transform energy industry contract management practices. When conducting analyses involving hundreds of contracts, the proposed solution exhibited significant efficiency gains. Case studies showed that it reduced processing time by 10 to 100 times compared to manual methods.
Mechanical Response Study of Stability Analysis of Conductor Pipe in Shallow-Water Field
Authors: Abimbola Fatai Akorede , Yang Jin , Adetowubo Adenike Yeside 
Published: November 2024

Summary
Maintaining a vertical position of conductor pipe during drilling and non-drilling operations remains a challenge in shallow-water fields. In Tianjin shallow-water field, a conductor pipe left for evacuation was found displaced on resumption for drilling operation. This prompts the need to address the problem by investigating the stability of the conductor pipe and to prevent its future occurrence. In this work, a governing equation is presented to study the mechanical behavior of conductor pipe in a shallow-water field under combined effect of soil, waves, current, and wind. The displacement response equation of the conductor pipe was solved numerically from which other responses were obtained. Various influencing factors such as internal fluid, top-weight, and wall thickness are analyzed for the conductor pipe. Modal analysis carried out shows that the part of the conductor pipe in the soil tends to vibrate for higher modes which thus threatens the stability of the conductor. Results show that significant displacement occurs for the conductor part in water which indicates that combination of waves and current on the conductor prevails over the top free-boundary condition effect. Analysis results also show that drilling mud of higher density in conductor with applied top-weight on it improves the stability of conductor. The results have been validated using Abaqus simulation.