bluuebunny/crossref_metadata_2025_split huggingface dataset:
Technology Selection in CO2 Recovery in Relation to CO2 Breakthrough Progression in Upstream Facilities
Authors: Nandi Bashistha , Punja Aditya , Al Kaabi Khawla Obaid 
Published: November 2024

Abstract
The paper intends to share insights on importance of appropriate technology selection for CO2 recovery package in upstream oil and gas facilities in relation to initial to final breakthrough concentration and share knowledge gained during various concepts of EOR projects. Paper also intends to share end user's need to further optimize OEM's design and any development requirement to suit the OPCO's need.
The paper would like to first highlight valuable knowledge gained during concepts of EOR projects while dealing with multiple CO2 recovery package vendors. Then showcase merits and demerits/limitations on various selected technologies (such as 2-stage Amine absorption Vs Hybrid technologies comprising of membrane followed by selective Amine absorption) for a certain initial to final CO2 breakthrough concentrations including CAPEX and OPEX level comparison.
The paper will conclude by highlighting that after CO2 re-injection for EOR projects, the breakthrough concentration of CO2 and H2S (mol%) will be the determining factor for technology selection for CO2 recovery package. As breakthrough differs in various reservoir zones, so one set of technology selection cannot be made standard practice.
Following conclusions can be made:
If CO2 concentration is above about 10% and no H2S breakthrough is expected, then 2 stage membrane process can be selected. If CO2 concentration is lesser than 10% and H2S breakthrough is significant then 2 stage MDEA is a better proposition till the limitation of AMINE package, then switch over to Membrane technology can be evaluated as 2nd phase. If CO2 concentration is above 10% and H2S breakthrough is expected, then 2 stage membrane process clubbed with selective Amine absorption unit (to remove H2S) shall be selected. If initial CO2 concentration is lesser than 10% for a significant time period, then Only 2 stage MDEA process shall be considered and scope for future assessment shall be considered in overall design.
End user finds it extremely difficult to deal with the significant delta P that each stage of membrane requires. Hence urgent need is envisaged for further development of low pressure drop module to reduce the ever-increasing OPEX. Also envisages further development need for removal of H2S through membrane technology along with CO2.
Assessing Caprock Competency - A Comprehensive Geomechanical Study and Analysis in a Field in Middle East
Authors: Nathan Kumar , Kamarudin Muhamad Aizat , Mohammed Mustafa Jawad , Wang Arthur Goh Ji , Amat Hadi , Choon Tan Boon 
Published: November 2024

Abstract
When a well reaches its end of productive life, a well abandonment need to be safely executed to ensure the well does not pose any environmental or safety hazards. The process of well abandonment involves a thorough assessment and planning phase, which includes evaluating the well's condition and the abandonment procedure to ensure compliance with regulatory requirements and environmental standards. This process also involves isolating zones where oil and gas formations are present to prevent hydrocarbons from leaking to the surface and to avoid cross-contamination.
This study aims to analyze the caprock integrity of Field G which consists of both clastic and carbonate reservoir. It addresses the critical need for sustainable development and abandonment practices that ensure long-term environmental and reservoir containment. The created caprock model and workflow eliminates the necessity of performing conventional full abandonment of existing well and drilling new well to access the deeper oil-bearing reservoirs in Field G. The study consists of comprehensive analysis of various logs and core data. Synthetic logs were created through numerical methods, followed by the computation of static and dynamic geo-mechanical properties. Triaxial and uniaxial tests were meticulously planned and executed on core plugs extracted from four different wells across Field G, serving as calibration data for the geo-mechanical model. A UCS model specific to Field G was developed and compared with established correlations in Middle East. Additionally, drilling data including FIT and LOTs were utilized to construct the pressure profile of Field G. The created model and workflow are then used to assess the caprock competency. Multiple competent caprocks were identified by studying the geo-mechanical properties of the rock. The UCS model that were generated specifically for Field G gives accurate prediction of the strength of such caprocks.
This comprehensive caprock assessment has not only enabled us to make informed decisions regarding well deepening to appraise deeper reservoirs but has also facilitated partial abandonment of certain wells, allowing for production from shallower reservoirs without the necessity of drilling new wells. Additionally, the generated UCS model and correlation can be used as a reference for nearby fields to predict the rock strength in the absence of core data. This study provides valuable insights for the oil and gas industry regarding the assessment of caprock competency, aiding in informed decision-making during both development and abandonment stages. Such insights enable the industry to attain more reliable and cost-effective outcomes during abandonment processes, thereby contributing to sustainable resource management practices.
Improve Fuel Gas Thermal Efficiency of Once Through Steam Generator (OTSG) for Higher Ultimate Recovery
Authors: Al Fazari M. , Yazeedi Z. , Hinai A. , Subhi H. , Al Hajri S. 
Published: November 2024

Abstract
Petroleum Development Oman LLC (PDO) is Oman's premier oil and gas producer that operates several fields at "A". As "A" Thermal fields contain heavy oil, PDO plans to significantly increase oil recovery by increasing the steam injection which is having high energy intensity.
The main objective of this paper is to demonstrate how Lean Six Sigma (LSS) approach has been utilized in improving the Thermal efficiency of the Once Through Steam Generators (OTSG) package and reduce the emissions and improve on cost efficiency.
The OTSGs are designed to generate saturated steam of a nominal 80% quality, the heat input for which is produced by combusting natural gas fuel. It is contributed of around 40% of total thermal development and key enabler for thick oil production. Currently, these generators have an average thermal efficiency of around 75%, where design efficiency is between 82% to 86%.
Several lean and six sigma tools and techniques were used to define the thermal efficiency improvement opportunities including; A SIPOC (Suppliers, Inputs, Process, Outputs, Customers), cost of poor quality (COPQ), RASCI, stakeholder analysis, communication Plan, detailed process mapping, Process Capability analysis, graphical and statistical analysis, Effort and Impact matrix, failure modes and effects analysis (FMEA), control plan, and leader standard work (LSW) to sustain Improvements.
The utilized set of Lean Six Sigma techniques and statistical tools led to reducing the fuel gas consumed in These OTSGs by 17% and eliminated wastes and preventive maintenance cost with an expected savings of around 5% per year.
A structured action closure plan has been developed and completed for this project resulted in implementing the counter measures and prepare the required fixing reports and acquire necessary approvals. Below are the results of the selected OTSG pilot.
Implementation of quick win counter measures by running the OTSGs on stabilize mode, improve the gas fuel burning efficiency by 3%. While piloting the implementations in the selected OTSG, another pilot has been done for another OTSGs (two) with an additional of 2% improvement in fuel gas Thermal efficiency from 83% to 85%.
Enhancing Edge-Based SRP Production Optimization Algorithm with Fast Loop Mitigation
Authors: Hyder Zeshan , Yermekova Maya , Kemp Carl , Srivastava Saket , Gambaretto Agustin , Pazniak Yury , Pivtoratskaia Svetlana , Agarwal Ambica , Ambade Amey 
Published: November 2024

Abstract
Sucker rod pumps (SRPs) stand as the foremost artificial lift (AL) technique globally, with advancements dating back to the development of the wave equation in the 1960s. Leveraging edge-based technologies, a workflow has been devised, building upon the foundation of existing Pump-Off Controller (POC) capabilities. This workflow seamlessly integrates machine learning (ML) based dynamometer card classification for real-time event detection with forward-thinking logic to autonomously optimize SRP operation setpoints. Operating within an Industrial Internet of Things (IIoT) framework, high-frequency dynamometer cards and pump data are analyzed.
The workflow incorporates two distinct sets of controls tailored for SRPs. The first set, Fast Loop Mitigation controls, utilizes outputs from an ML algorithm to promptly process and classify surface and downhole dynamometer cards in real time (Bruns, Sharma and Whitley 2022). These mitigations are specifically designed to identify and address common SRP issues such as flatlining, fluid pound, gas interference, and tagging as they arise.
The second set of controls, known as the Production Optimization (POPT) Algorithm, collects operational data and monitors it through a dynamically shifting time window (Gambaretto, et al. 2024). This window provides a relevant snapshot of operational history, enabling the algorithm to synthesize trends into performance indicators. These indicators are then utilized to forecast the most optimal pump operating setpoint for enhanced efficiency and productivity.
Results from testing underscore the significant benefits achieved through the synergistic application of both control systems. On tested wells, inferred production saw a notable average increase of 15%, while runtime exhibited an average uptick of 3%. Concurrently, cycling decreased by an average of 29% by maintaining optimal pump fillage (Gambaretto, et al. 2024). Moreover, stable operating conditions were observed throughout.
This approach represents a paradigm shift, integrating the mitigation of short-term potential pump damaging issues, with the long-term POPT algorithm for maintaining optimal well production. By leveraging the strengths of both algorithms, it offers a holistic optimization strategy that addresses immediate challenges while aligning with long-term objectives, thereby providing a comprehensive solution for well optimization.
Petronas’ Journey in Developing Risk Based Maintenance Approach for its Offshore Pedestal Cranes
Authors: Basri H , Ekhwan A , Hun KP , Natarajan J 
Published: November 2024

Abstract
Over the last three years, PETRONAS has spent approximately USD 36 million on the maintenance of a total of 107 pedestal cranes. This has emerged as the main contributor for the overall static equipment maintenance costs. In the pursuit of operational efficiency and cost optimization, PETRONAS is pioneering a shift from traditional time-based maintenance to a Risk-Based Maintenance (RBM) approach. The RBM methodology aims to enhance safety and reliability while optimizing overall expenditures.
The proposed methodology systematically divides the pedestal crane into key systems/components, subjecting each to a comprehensive risk assessment. Risk is calculated as the product of Probability of Failure (POF) and Consequences of Failure (COF) for individual component. PETRONAS has crafted a methodology for determining POF and COF, considering factors such as historical failure data, remaining design life, compliance with maintenance programs, crane category as per API 2C, usage of the crane, location of the crane and prior derating instances.
A customized scoring system, harmonized with PETRONAS ‘s risk matrix, quantifies the POF and COF for each component, offering a refined evaluation of risk specific to the crane's configuration and operational context. This approach guides the formulation of a maintenance program, with higher-risk components receiving more focused and frequent action plan.
The integration of continuous evaluation into the maintenance process is crucial. Thus, post each maintenance cycle, risk assessments are dynamically re-evaluated, determining subsequent inspection schedules. This adaptive approach ensures that maintenance efforts align with the evolving risk profile of the crane, enhancing responsiveness to changing operational conditions over the years. Incorporating a systematic and data-driven RBM methodology for offshore pedestal cranes, this initiative epitomizes PETRONAS's commitment to innovation and efficiency. By shifting from a time-based to a risk-based, PETRONAS anticipates substantial reductions in overall maintenance costs, improved operational efficiency and heightened safety in offshore lifting operations.
Innovative Cold Start-Up Solution of BOG Compressors without Flaring at LNG Terminal
Authors: Ghosh Samiran , Deo Atul 
Published: November 2024

In October 2018, TotalEnergies and the Adani Ports and Special Economic Zone Limited (APSEZ), both as Co-Sponsors, signed an agreement to jointly develop a 5 metric ton per annum (MTPA) Nominal Capacity Liquefied Natural Gas (LNG) Regasification Terminal at Dhamra Port. Dharma LNG Terminal Private Limited (DLTPL), a wholly owned subsidiary of Adani Total Private Limited (ATPL), whereby ATPL is a 50-50 joint venture between TotalEnergies and APSEZ. Dhamra Port, located on India's eastern coast, is a modern seaport managed by The Dhamra Port Company Limited (DPCL).
The Project's location by Dhamra Port, a deep seaport with draft of up to 18 meters, is designed to handle large ships capable of accommodating super cape-size vessels up to 180 000 DWT and various other types of cargo. It is strategically placed between Haldia and Paradeep, close to resource-rich areas like Orissa, Jharkhand and West Bengal. Commissioned in April 2023 as the first terminal in the eastern region of the country, the terminal has been continuously operating since then.
The terminal is a marvel of modern engineering, boasting an array of sophisticated equipment essential for the efficient handling and processing of LNG. This includes unloading arms, full containment LNG tanks, Boil-Off Gas (BOG) compressors, Recondenser, High Pressure LNG pumps, LNG vaporizers, metering stations, dispatch facilities, LNG truck loading facility etc.
Reducing Greenhouse Gas Emissions of Mobile Offshore Units; Pathway and Case Study Alternative Fuels for Self-Propelled Multipurpose Jack-Ups
Authors: Wassink A. , van den Berg E. , Fuster Piza P. , van Maurik P. 
Published: November 2024

Abstract
The worldwide energy transition and greenhouse gas emission-reduction targets impact the offshore industry. The sector, as part of the maritime industry, is working to meet increasingly strict international and regional emission regulations through measures such as energy efficiency and alternative fuels.
In this paper we describe the generic pathway to reduction of the operational emission of greenhouse gases for Mobile Offshore Units (MOUs). This is a relative new area of attention in the offshore sector. The paper provides an overview of monitoring and energy efficiency measures that are suitable for MOUs and their operations. In addition, it discusses applicable regulations and explores solutions for reducing greenhouse gas emissions and their impact on design of MOUs.
Specifically, we have performed a fuel emissions and vessel design impact case study for a self-propelled jack-up with 1,500 t variable deck load for two typical operating profiles: making an accommodation service trip or a field move in the Middle East region. We compared the global warming contribution of the greenhouse gas emissions of the operation and the impact of fuel storage for five different types of fossil and e-fuels. This high level assessment of the greenhouse gas emissions is based on their contribution to global warming over a 100-year period. This is done for the well-to-wake emissions of the assessed fuel types.
The case study assessment shows that fossil-based alternative fuels, such as gray methanol, gray ammonia or gray hydrogen are to be avoided as marine fuels: they create more greenhouse gas emissions than marine gas oil. It also shows that green (i.e. bio- and electro-) fuels can achieve a reduction of 79% or more in greenhouse gas emissions. The volume and weight impact of alternative fuels on the design of offshore installation vessels are included in the assessment. These findings can also be applied to other types of MOUs.
By replacing a fossil fuel such as marine gas oil with green alternatives, the IMO emission-reduction target for 2040 is attainable. The IMO net-zero ambition for 2050 will require further development of energy carriers and energy conversion systems with net-zero well-to-wake emissions. The green alternative fuels come with challenges regarding the weight and volume for fuel storage.
The energy transition timetable is driven by regulatory requirements and political choices, as well as by technological developments and the associated costs and rewards. The regional availability of alternative fuels and fuel supply infrastructure for the maritime and offshore sector also play an important role.
Vacuumized Pipe-in-Pipe Solution for Efficient Geothermal Heat Extraction Everywhere for District Cooling and Heating
Authors: Maver K. G. , Rasmussen J. P. 
Published: November 2024

A new horizontal geothermal well solution is using a completely closed loop system for the circulation of a fluid in a vacuumized pipe-in-pipe (co-axial) system. The fluid is heated by the geological formation in the horizontal section of the well and returned to the surface with a very limited heat loss. With the closed loop solution there is no requirement for a geothermal reservoir with a certain porosity, permeability and flow characteristics and therefore the solution is independent of the geological setting and has a near universal application. This reduces most of the risks associated with conventional doublet hydrothermal well solutions, that often fails due to an impermeable heat reservoir.
For a successful execution, proven oilfield drilling technology and services are utilized. The drilled depth determines the temperature of the returning circulation fluid. The thermal conductivity of the geological formation of the horizontal well completion and the fluid flow rate controls the thermal energy output (MW).
The solution is suitable for initial subsurface temperatures around 150°C or lower. The formation temperature around the well will decrease over time due to the energy production. The temperature range makes the solution suitable for producing thermal energy for district cooling, directly for district heating and for various industrial usages.
Enhancing Operational Efficiency and Sustainability Through Al-Driven Fleet Management in the Caspian Sea, Cheleken Area
Authors: Espinoza R. , Butyrin A. , Vedat K. , Thatcher J. , Eldred M. 
Published: November 2024

Abstract
This paper explores the potential of Artificial Intelligence (AI) to enhance operational efficiency and sustainability in Dragon Oil's marine operations within the Cheleken Contract Area, Caspian Sea, Turkmenistan. Special attention is given to optimizing fleet capacity while addressing complex environmental and operational factors, such as variable channel depth, weather, operational priorities, and loading capacities. Through AI-driven optimization, the study identifies the optimal vessel plan to improve operational efficiency, reduce fuel consumption and costs, and lower CO2 emissions.
Smart Fracturing System for Screenless Sand Control Strategy in Cemented Monobore Completions
Authors: Surtman M. , Rozlan M. R. , Rasid M. F. , Bela S. M. , Zaman N. , Hussain M. , Makri M. H. , Amiruddin M. I. , Bohro M. N. , Deris M. N. M. , Thanaraju A. 
Published: November 2024

Abstract
Traditional fracpack designs generally involve setting up multi-zone downhole screen assemblies with isolation packers and pumping proppant slurry until screenout occurs. In contrast, the screenless fracpack using Smart Fracturing Systems avoids the need for costly wellbore cleanup operations, perforation, packer fluid, screens and packer assemblies, and proppant reversing procedures. Instead, communication with the reservoir is facilitated through frac sleeves and dissolvable darts for localized stimulation, which ensures uniform fracture propagation and sand placement in each stage. The reservoir is treated with Resin Coated Proppant (RCP) in a solid free carrier fluid, employing an underflush strategy to prevent nearwellbore collapse and proppant flowback during production. This innovative approach aims to reduce well construction costs while offering full-bore access throughout the entire wellbore. Production results demonstrated good productivity and effective sand control, with no proppant flowback at the surface.
The Future of Hydrates Management: NADAH – New Approach of Design Against Hydrates
Authors: Candelier C. , Lesage N. , Pierre T. Saint 
Published: November 2024

Abstract
Hydrates are formed of water and gas at high pressure and low temperature, conditions encountered in offshore environment. Lines plugging by hydrates is an undesirable outcome which must be avoided and has become a prevailing factor for the design and operation of subsea networks. Conventional design approach in deepwater developments consists in staying in the hydrates free domain whatever the scenario anticipated on the field. This approach often resulted in significant capital expenditure (CAPEX) with thermally insulated looped flowline, complex operating procedures having high impact on the operating efficiency and GHG emission.
This paper presents an innovative approach to manage hydrates risks in subsea developments, named NADAH (New Approach of Design Against Hydrates) and its implications for the future of offshore oil field development. NADAH is based on the understanding that some crudes have induction properties, which delay hydrate formation even when the pressure and temperature conditions reach the hydrate thermodynamic region. NADAH introduces a paradigm shift in hydrate management.
NADAH allows for mastered incursions of operating conditions into the hydrate thermodynamic region, but outside of the hydrate formation conditions, by taking into account the crude's induction capabilities at the early phase of the project. NADAH has been successfully applied on more than 5 projects, mainly in West of Africa, resulting in significant CAPEX and OPEX savings, as well as a reduction in production shortfalls and GHG emission.
For existing assets, NADAH allows simplifying the operations on site by extending the No Touch Time period and drastically delaying the requirement for any preservation operation, combining the natural capacities in delaying hydrates formation and the over-designed thermal specification. This optimization contributes to saving OPEX and production shortfalls reduction.