Gas Industry Research Articles

Анализ работы современных водолазных судов, оснащенных системой динамического позиционирования (DP)

. The principle of operation of modern diving vessels equipped with dynamic positioning (DP) systems is analyzed. The classification of diving operations on such vessels is considered. To perform certain construction work or maintenance of underwater facilities, a diving team is needed – the most important component in an integral part of the most difficult work, where the ROV (remote-controlled uninhabited underwater vehicle) of the working class, equipped with tools for certain purposes, is not adapted for complex tasks. The topic of limiting the length of the hose cable (a technology that ensures the delivery of vital consumables, signals and energy via cable to the diver) for underwater work is touched upon. An assessment of the safe working distance of divers near the bow thrusters and propeller columns of the DP vessel is carried out using the example of the most modern vessel in the Caspian Sea to support diving operations, as well as for the installation of underwater structures of the deep-sea bases of the Khankendi. Conclusions are drawn about the widespread use of DP systems on modern ships, in particular those involved in the oil and gas industry, as well as other areas of the marine industry. A study has been conducted to assess the safety of diving operations of a DP vessel operating in shallow water. An assessment is given to limit the movement of the vessel during diving operations. The specifics of the universal vessel involved in connection with the risks of human life, the working environment of divers, various environmental conditions, the proximity of the vessel's propulsion systems and many other additional risks that pose a danger are indicated. The thesis on the need for careful planning and management of diving operations has been confirmed.

Technological advancements in drilling: A comparative analysis of onshore and offshore applications

This paper examines the technological advancements in onshore and offshore drilling operations, emphasizing their significance, challenges, and environmental considerations. Technological innovations, including automation, data analytics, and real-time monitoring, have transformed drilling practices, enhancing efficiency, safety, and environmental sustainability. By comparing onshore and offshore applications, the paper evaluates the effectiveness of these advancements in addressing the unique challenges of each environment. Key areas of focus include efficiency improvements, safety enhancements, environmental impacts, and regulatory compliance. Through case studies and analysis, the study aims to provide valuable insights into the current state of onshore and offshore drilling operations and identify opportunities for innovation and improvement. Ultimately, the findings contribute to advancing sustainable practices, mitigating environmental risks, and fostering responsible resource extraction in the oil and gas industry. This comparative study delves into the dynamic landscape of technological advancements within onshore and offshore drilling operations. It explores the evolving role of automation, data analytics, and real-time monitoring in revolutionizing drilling practices, offering insights into their implications for efficiency, safety, and environmental stewardship. By juxtaposing the unique challenges and operational requirements of onshore and offshore environments, the study underscores the importance of a nuanced understanding of technological applications. Through rigorous analysis and case studies, it illuminates the interplay between advancements and environmental considerations, shedding light on opportunities for innovation and sustainable development. The study's comprehensive scope encompasses efficiency gains, safety protocols, environmental impact mitigation, and regulatory compliance, providing a holistic view of the transformative potential of technology in the drilling industry. Ultimately, the study serves as a catalyst for informed decision-making, fostering dialogue, and driving forward-looking strategies for the future of onshore and offshore drilling operations.

Resource classification of coal bed methane and its contribution in energy transition and decarbonization path of oil and gas industry (A synopsis of CBM Life Cycle Analysis)

World economies are becoming increasingly more dependent on energy and countries have a voracious appetite for energy therefore, the need for an abundant clean energy is becoming a necessity. Energy companies are challenging environmental costs of coal bed methane as with advancement of new technology the impact from production of coal bed methane can reduce and to a certain extent avoided or offset. Production of coal bed methane results in changes to the land, to surface water and to ground water systems. Carbon quantification is required to understand, monitor and manage these changes. Previous life cycle analysis for this resource class has lack of process design details because of which there is a knowledge gap in understanding of emission profile of coal bed methane’s production. The objective of this study is to add value and reduce the scientific gap with respect to the production techniques of coal bed methane and its environmental impact. Removal of water continuously from coal seams depletes ground water and may eventually lower surface water flows (streams and rivers). It can also change the flow of groundwater drawing fresh water into the coal seams. To better understand this phenomenon the work establishes the Coal Bed Methane production foundation by in depth understanding of · Coal Bed Methane reservoir types; · Coal Bed Methane depositional environment, generation, and geological distributions; · Coal Bed Methane resource energy supply methods by understanding its construction, production and processing. The study then uses Life Cycle Assessment approach and understands previous emission numbers of Coal Bed Methane’s resource development. The work does systematic analysis and summarizes the previously published Life Cycle Analysis to understand further the potential environmental impacts of resource development of Coal Bed Methane. This will help energy companies to understand the field development, production, and operations of coal bed methane’s resource in terms of carbon numbers thereby optimizing the operations through carbon management thus reducing the potential impacts.

Sustainability and environmental impact in the LNG value chain: Current trends and future opportunities

The liquefied natural gas (LNG) industry plays a crucial role in the global energy landscape, offering a cleaner alternative to traditional fossil fuels. However, the LNG value chain presents environmental challenges that must be addressed to ensure long-term sustainability. This paper examines current trends and future opportunities for enhancing sustainability and reducing environmental impact across the LNG value chain. The LNG value chain comprises several stages, including natural gas extraction, liquefaction, transportation, regasification, and distribution. Each stage presents unique sustainability challenges, such as methane emissions during extraction and transportation, energy-intensive liquefaction processes, and the carbon footprint of regasification and distribution. Current trends in the LNG industry focus on mitigating these challenges through various strategies. These include the adoption of advanced technologies for methane detection and reduction, the use of renewable energy sources for liquefaction, and the implementation of efficient regasification and distribution practices. Additionally, there is a growing emphasis on stakeholder engagement, transparency, and reporting to enhance sustainability performance across the value chain. Future opportunities for improving sustainability in the LNG value chain lie in the continued development and deployment of innovative technologies. These include carbon capture and storage (CCS) technologies to reduce emissions, the use of renewable natural gas (RNG) as a feedstock, and the integration of LNG with renewable energy sources to create hybrid energy systems. Addressing sustainability and environmental impact in the LNG value chain requires collaboration among industry stakeholders, governments, and regulatory bodies. By implementing best practices, embracing innovation, and prioritizing sustainability, the LNG industry can continue to play a vital role in the transition to a cleaner and more sustainable energy future.

AI-enhanced subsea maintenance for improved safety and efficiency: Exploring strategic approaches

As the oil and gas industry increasingly explores deeper and more remote offshore sites, the maintenance of subsea infrastructure becomes paramount. The use of Artificial Intelligence (AI) in subsea maintenance offers promising solutions to enhance safety and efficiency in these challenging environments. This review explores strategic approaches to integrating AI into subsea maintenance operations. AI facilitates predictive maintenance by analyzing vast amounts of data collected from sensors and historical maintenance records. Machine learning algorithms can detect patterns and predict equipment failures before they occur, enabling proactive maintenance scheduling. This predictive capability reduces downtime and minimizes the risk of accidents by addressing potential issues before they escalate. AI-enabled autonomous underwater vehicles (AUVs) and remotely operated vehicles (ROVs) play a crucial role in subsea inspections and repairs. These AI-enhanced robots can navigate complex subsea environments, perform inspections, and execute maintenance tasks with greater precision and efficiency than human divers. By reducing the need for human intervention in hazardous environments, AI-driven AUVs and ROVs significantly improve safety. Furthermore, AI algorithms can optimize maintenance schedules based on factors such as equipment condition, environmental conditions, and operational requirements. By dynamically adjusting maintenance plans, operators can maximize equipment uptime while minimizing costs and risks. This proactive approach ensures that maintenance activities are conducted at the most opportune times, reducing the likelihood of unplanned downtime and improving overall efficiency. Moreover, AI facilitates condition-based maintenance strategies, where equipment health is continuously monitored in real-time. Sensors installed on subsea infrastructure collect data on factors such as temperature, pressure, and vibration, which is then analyzed by AI algorithms to assess equipment condition. By detecting early signs of degradation or malfunction, AI enables timely interventions, preventing costly breakdowns and ensuring optimal performance. In addition to predictive and condition-based maintenance, AI-driven analytics offer insights into operational performance and asset integrity. By analyzing data from various sources, including sensors, historical records, and operational logs, AI can identify trends, anomalies, and optimization opportunities. These insights enable operators to make data-driven decisions that enhance overall system reliability and efficiency. Strategic approaches to implementing AI in subsea maintenance require collaboration between technology providers, operators, and regulatory bodies. Establishing industry standards and guidelines for AI applications in subsea operations is crucial to ensure safety, reliability, and interoperability. Furthermore, investing in research and development to enhance AI algorithms and robotics technology is essential to unlock the full potential of AI in subsea maintenance. AI-enhanced subsea maintenance offers significant benefits in terms of safety and efficiency. By leveraging predictive analytics, autonomous robotics, and real-time monitoring, operators can optimize maintenance activities, reduce downtime, and minimize risks. Strategic approaches to integrating AI into subsea operations require collaboration, investment, and a commitment to advancing technology to meet the challenges of offshore environments.

Enhanced H2S decomposition using membrane reactor

H2S is a toxic gas released during many industrial processes, especially oil and gas refining. Currently, H2S is converted to sulfur using Claus process, but it leads to loss of another valuable product, i.e., hydrogen, in the form of water. Thermal decomposition of H2S in a membrane reactor is a promising route for recovering both hydrogen as well as sulfur in an efficient manner. In the present work, the authors report H2S decomposition studies with packed-bed membrane reactor (PBMR) using in-house developed clay-alumina ceramic membrane. In order to have a comparative evaluation, these studies were conducted in packed bed reactor (PBR) as well as in single-tube PBMR at different operation parameters. In PBMR, conversion of ∼90% was obtained at 1573 K and 0.5 bar, whereas a conversion of ∼50% was obtained in PBR. CFD simulations for H2S decomposition using ceramic PBMR were carried out and validated using experimental results. 3D simulations for parametric optimisation of multi-tube PBMR were also carried out by extrapolation of validated model. This is for the first time, CFD studies on H2S decomposition and its validation using ceramic PBMR are being reported in this work.

A methane monitoring station siting method based on WRF-STILT and genetic algorithm

Reducing methane emissions in the oil and gas industry is a top priority for the current international community in addressing climate change. Methane emissions from the energy sector exhibit strong temporal variability and ground monitoring networks can provide time-continuous measurements of methane concentrations, enabling the rapid detection of sudden methane leaks in the oil and gas industry. Therefore, identifying specific locations within oil fields to establish a cost-effective and reliable methane monitoring ground network is an urgent and significant task. In response to this challenge, this study proposes a technical workflow that, utilizing emission inventories, atmospheric transport models, and intelligent computing techniques, automatically determines the optimal locations for monitoring stations based on the input quantity of monitoring sites. This methodology can automatically and quantitatively assess the observational effectiveness of the monitoring network. The effectiveness of the proposed technical workflow is demonstrated using the Shengli Oilfield, the second-largest oil and gas extraction base in China, as a case study. We found that the Genetic Algorithm can help find the optimum locations effectively. Besides, the overall observation effectiveness grew from 1.7 to 5.6 when the number of site increased from 1 to 9. However, the growth decreased with the increasing site number. Such a technology can assist the oil and gas industry in better monitoring methane emissions resulting from oil and gas extraction.

Changes in well control training to meet the challenge of reducing well control incidents

The number of safety related incidents in the Oil and Gas industry has steadily declined over the past 20 years. However, the frequency of well control incidents has not followed the same trend. The Norwegian regulator (Petroleum Safety Authority) has recently documented this finding as related to the Norwegian sector of the North Sea. Globally, the International Association of Oil and Gas Producers (IOGP) Report 637 and recent data from Wild Well Control also support this conclusion – in fact, Wild Well Control data shows that the frequency of well control incidents may be increasing. The loss of experienced personnel due to reduced activity during the COVID-19 pandemic may have contributed to this. Now that activity is increasing again, the industry faces a challenge in recruiting skilled personnel. Current well control courses predominantly cover the well construction process, with minor emphasis on the whole life cycle of the well. However, a significant number (in some areas close to half) of well control incidents occur after the well construction process is completed. Based on analysis of the main contributory factors to well control incidents, IOGP has recently updated Report 476 ‘Recommendations for enhancements to well control training, examination and certification’. This paper reviews the changes to Report 476 and discusses how International Well Control Forum can contribute to reduce the well control incident rate with focus on the Well Control in Design and Lifecycle Management course.

The rising significance of the Perth Basin

Amid a nationwide struggle to revitalise exploration and development activity in the Australian oil and gas industry, the Perth Basin emerges as a beacon of hope. During 2003–2005, the basin experienced a peak in exploration activity, averaging an impressive 13 wells drilled per year. However, mirroring the sector’s broader nationwide trend, the Perth Basin then saw a decline in drilling, with an annual average of just three exploration wells over 2006–2022. Nevertheless, a turnaround is in progress, with the basin poised for the drilling of eight exploration and appraisal wells in 2024. The turning point for the basin can be traced back to the Waitsia discovery in 2014 which rekindled interest and activity in the region, resulting in nine distinct gas discoveries and a subsequent doubling of the basin’s estimated gas resources. Against the backdrop of projected gas shortfalls in Western Australia’s domestic market, players in the basin have ambitious development plans amid rising gas prices. We expect that the Perth Basin could contribute up to 30% of WA’s domestic gas supplies by 2030, compared to a modest 5% in 2023. Notably, a substantial portion of WA’s new gas supplies are expected to originate from the Perth Basin. This paper examines the resurgence of activity and interest in the Perth Basin, driven by surging valuations and its growing significance within the domestic gas market. It also examines the commercialisation pathways in light of the updated ban on onshore gas exports in WA.

Steps to accelerate net zero delivery

Worley and Princeton University’s Andlinger Center for Energy and the Environment are working together to shift the net zero narrative from what is needed, to how to meet this immense infrastructure delivery challenge. Together, we assert that this challenge cannot be met through a traditional project delivery approach. We have developed a new delivery paradigm, which identifies five key shifts in infrastructure delivery practices to build the durable, responsible, and pragmatic means of achieving the required scale and speed of mid-century net zero. We believe that the new delivery paradigm needs to be in place by 2030, and an annual survey conducted by Princeton University is tracking the uptake by industry. The third instalment in our thought leadership series ‘From Ambition to Reality (FATR): Steps to accelerate net zero delivery’, explores the scale of the EU’s 2030 Hydrogen ambition and how the five key shifts could accelerate the delivery of 10 million tonnes per annum of renewable hydrogen in the next 6 years. This has led to our proposed EU Renewable H2 Plan, which has been further globalised to our 2024 FATR Plan for application to any low carbon sector or supply chain. In this paper, we examine the initiatives set out in the 2024 FATR Plan in the context of the Australian oil and gas industry. We outline the steps that can be taken right now to support the decarbonisation of the Australian oil and gas industry alongside the development of a new hydrogen industry.

The Bayu-Undan liquid CO2 import facilities – finding an effective solution

Carbon capture and storage (CCS) is widely considered to be one of the key enablers to decarbonising the economy. It is currently being implemented in a number of projects in gas, power, chemicals, cement, steel, and other industries. In the Asia–Pacific region, shipping of liquid carbon dioxide (LCO2) is widely seen as a key component of the CCS value chain. Shipping allows the emitters located in the industrial centres of Japan, Korea, and Singapore to access distant CO2 storage locations. The repurposing of the Bayu-Undan (BU) platforms and pipeline from gas production to CO2 injection presents a regional opportunity for the disposal of shipped CO2. Multiple LCO2 development concepts were assessed for unloading and storing the imported LCO2. Unloading can be carrier-to-shore, carrier-to-ship/barge, or carrier-to-platform; storage can be onshore, nearshore, offshore or no buffer storage at all with direct injection from carriers. These concepts required evaluation for technical functionality, maturity, complexity, operability, and availability. Imported LCO2 is too cold and low pressure to be transported or injected at the carrier transport conditions. The pressure needs to be boosted and temperature increased to meet the requirements of the injection system. This requires sources of power and heat. An evaluation of existing facilities, their condition, available space and spare capacity, and their constructability considerations revealed important opportunities and constraints. A study was carried out, which evaluated options for the BU LCO2 import using key evaluation criteria to select the most appropriate concept. This paper explores addressing the challenges involved.

Charting a path to low-carbon leadership: unlocking up to 90% emissions reductions in greenfield LNG

The liquefied natural gas (LNG) industry stands at the cusp of a transformation driven by the climate imperative. Focussing on the Middle Arm Industrial Precinct, this paper shows how carbon dioxide (CO2) emissions are being reduced in a proposed world-class LNG project by assessing, screening and selecting known technologies using a Marginal Abatement philosophy linked to key emissions drivers. (1) We propose a new breed of electrified LNG facilities that could deliver an up to 90% reduction in CO2 intensity. (2) We show that through developing strategic partnerships in upstream renewable power, hydrogen supply, and enabled downstream carbon capture and storage (CCS), the significant low carbon energy requirements of an LNG facility can be delivered. (3) We discuss a Marginal Abatement assessment strategy which ensures a pathway to viable lowest cost opportunities selected in an ‘Avoid & Mitigate’ first approach. This proposed strategy ensures that CO2 emission reduction opportunities are assessed and selected consistently to determine both a lifecycle cost ($) and volume (tons CO2e) of emission reduction. These innovative strategies collectively articulate a roadmap for a low carbon future for LNG and other heavy industrial industries, underlining Australia’s potential to become a leading provider of low-carbon natural resources.

The greenhouse gas reduction effect of critical peak pricing for industrial electricity: Evidence from 285 Chinese cities, 2003–2019

This paper assesses the impact of the Pilot of Critical Peak Pricing for Industrial Electricity (PCPPIE) on industrial Greenhouse Gas (GHG) emissions by employing the Difference-in-Differences (DID) methodology. It is found that the cities participating in PCPPIE underwent a significant 11.3% reduction in the GHGs emitted per industrial enterprise. These findings remain robust across various methodologies, including staggered DID estimators, propensity score matching, instrumental variable methods, and spatial econometric regression. The generalized DID analysis shows that a higher critical peak price corresponds to a more substantial decrease in GHG emissions. PCPPIE achieves weaker GHG reduction in higher-administrative level cities but stronger in those with higher industrial share, and the effectiveness of PCPPIE is compromised by cross-regional electricity imports. PCPPIE reduces GHG emission intensity of the power industry and contributes to additional reductions in GHG emissions from other sources by fostering green technological innovation and facilitating energy substitution. The practical significance of this paper is to reveal a richer dynamic mechanism for China's green and sustainable development, indicating that critical peak pricing is a power pricing strategy worthy of strengthening and optimization in the process of China's carbon peak and carbon neutrality.

Omniphobic/superhydrophobic surface effect on oil and gas flow: A critical review

AbstractFlow assurance in the petroleum business of the oil and gas industry ensures the efficient and continuous flow of hydrocarbons from production facilities to consumers. Impurities in oil and gas can cause corrosion and erosion, hydrate formation, scaling, and fouling, resulting in flow limits and reduced operating efficiency. The significant flow assurance issues must be managed through systematic exploration of effective mitigation and management approaches. The objective of this paper is to highlight the latest research in the field of flow assurance, including the application of superhydrophobic or omniphobic coatings to prevent scale growth, asphaltene precipitation, wax deposition, and hydrate formation. This review will provide new perspectives into the basic mechanistic mechanisms of deposition and blockage in oil and gas production systems, assisting in the development of novel methods compared to the employment of commercial chemical or mechanical techniques. Overall, the flow assurance engineers will gain new perspectives from this study regarding how to deal with the risk of pipeline blockage caused by the problems mentioned earlier.

Leadership and talent attraction and retention – an existential risk to our industry

Political, social, shareholder – and increasingly talent – pressure is driving a seismic shift as oil and gas operators are required to transform into diversified energy companies. Attracting and retaining the required leadership and talent to drive this transformation is an existential risk to our industry. 10.5% of the total workforce left the industry during the 2019/2020 oil price crash. Since 2020 the experienced oil and gas industry workforce has aged and will take critical skills and experience with them into retirement. 40% of Australian oil and gas recruiters believe retaining this knowledge and replacing these skills are the industry’s biggest challenges. In parallel, events in August 2023 in Western Australia have demonstrated the immediate market impact workforce unrest can have. Concurrently, it is becoming harder to attract talent to the industry. The competition for adaptive leaders and high-skilled workers has been accentuated as the oil and gas sector continues to evolve and now competes for these skills sets with other industries. Environmental, Social and Governance (ESG) performance is increasingly becoming an important factor in the industry’s ability to attract and retain talent. In a recent global talent index report, 85% of respondents stated ESG is a factor in whether they will stay or leave an oil and gas organisation. Interestingly, 55% of those open to switching sectors would be interested in switching to renewables. In this paper, I provide oil and gas companies with pragmatic guidance on how to quantify the impact of these challenges, adapt the industry narrative, and re-position as an employer of choice.

The effect of PVP and PVA on hydrate formation kinetics of ethane and propane mixture in the presence of kaolin nanoparticles

AbstractThe blockage of gas transmission pipelines due to gas hydrates poses a significant challenge for the gas industry. Low‐dosage hydrate inhibitors (LDHI) are utilized to influence the kinetics of hydrate formation, including nucleation, growth, and/or agglomeration. In the current study, a series of batch, isochoric, and isothermal tests were carried out to investigate the impacts of two LDHIs, poly N‐vinylpyrrolidone (PVP) and polyvinyl alcohols (PVA). This study examined the influence of these inhibitors on nucleation and growth of ethane+propane mixture in the presence of kaolin nanoparticles. In laboratory studies and using pure constituents, the rate of hydrate formation is low to investigate the inhibitors effect. To enhance the rate of hydrate formation, kaolin nanoparticles were utilized as they serve as a suitable representative for solid minerals commonly found in pipelines. The gas phase's compositional change were measured using a gas chromatograph. The results revealed that the growth stage of mixed‐gas exhibited two distinct steps, attributed to the formation of two different structures known as structure II and structure I. During the first step, structure II was formed, and the cavities were occupied by both gas components. In the second stage, structure I was formed by ethane. The effect of temperature on the induction time (nucleation rate) and the growth rate during the second stage was lower than that at the first stage. The increase in PVA concentration resulted in an increase in the induction time and a decrease in the rate of growth during the first stage. The performance of PVA was found to be affected by temperature. Lower temperatures resulted in the formation of less foam, providing improved performance for PVA at −0.5°C. PVP had a stronger impact on induction time and both growth steps compared to PVA, indicating stronger inhibitory impact of PVP on nucleation of hydrates initiated by propane and the growth of both propane and ethane hydrates.

Toward sustainable recycled methanol production from CO2 and steel by-product gases in South Korea; process design and assessment

Methanol is receiving considerable attention as an alternative fuel because of its potential role as a transitional option in mitigating greenhouse gas emissions and enabling the transition towards biofuels. Recycled methanol, produced using captured CO2 or industrial by-product gases, emerges as an attractive alternative in South Korea, especially considering the excessive emissions from its energy and industrial sectors. However, assessing technological superiority amongst a range of alternatives remains challenging. This study aims to assess and compare various methanol production pathways utilizing captured CO2 and by-product gases from steel industry within context of South Korea. The selected technologies are either currently in industrial use or pivotal for future industrial applications. A unified process design and assessment framework was employed to model and simulate eight technological conversion processes. These processes underwent evaluation based on key performance indicators, accompanied by comprehensive techno-economic and environmental life cycle assessments. Additionally, comparisons were made with conventional fossil-based methanol production, considering different hydrogen and electricity production routes. This study provides valuable insights into the viability of recycled methanol pathways in terms of process performance, economic and environmental feasibility and will facilitate the practical implementation of recycled methanol, contributing towards achieving carbon neutrality objectives.

Innovative waste management approaches in LNG operations: A detailed review

As the liquefied natural gas (LNG) industry continues to expand globally, the imperative to address environmental concerns and enhance sustainability within LNG operations becomes paramount. This paper conducts a comprehensive and detailed review of innovative waste management approaches within the LNG sector. Traditional waste management practices in LNG operations, including disposal and recycling, are examined, highlighting the associated challenges. The focus then shifts to innovative approaches, encompassing recycling and circular economy initiatives, advanced waste-to-energy technologies, and the adoption of sustainable packaging solutions. Case studies and examples illustrate successful implementations of innovative waste management strategies in various LNG facilities, providing insights into the environmental and operational benefits achieved. The paper explores the implications of these approaches, emphasizing reduced carbon footprints, enhanced resource efficiency, and cost-effectiveness. Additionally, the review delves into the barriers and challenges hindering widespread adoption, including technological, economic, and regulatory considerations. This detailed examination aims to contribute valuable insights for industry stakeholders, policymakers, and researchers, fostering the integration of sustainable and innovative waste management practices in the ever-evolving landscape of LNG operations. Keywords: Innovative, Waste, Management, LNG operations, Review.

Environmental stewardship in the oil and gas sector: Current practices and future directions

This paper provides an overview of the current practices and future directions in environmental stewardship within the oil and gas industry, focusing on key areas of concern and strategies for improvement. The oil and gas industry has made significant strides in environmental stewardship in recent years, driven by a combination of regulatory requirements, corporate initiatives, and stakeholder pressure. One of the primary areas of focus has been the reduction of greenhouse gas emissions associated with extraction, refining, and transportation processes. Companies have implemented technologies such as carbon capture and storage to minimize their carbon footprint, alongside investments in renewable energy sources and energy efficiency measures to transition towards cleaner energy alternatives. Furthermore, the industry has placed increasing emphasis on the responsible management of water resources, recognizing the potential environmental impacts of water extraction and usage in oil and gas operations. Strategies for water recycling, reuse, and wastewater treatment have been adopted to mitigate pollution and minimize strain on local ecosystems. Biodiversity conservation has also emerged as a critical aspect of environmental stewardship in the oil and gas sector, with companies undertaking environmental impact assessments and collaborating with conservation organizations to minimize habitat disruption and restore ecosystems affected by their operations. Community engagement and social responsibility are integral components of environmental stewardship, with companies seeking to address the social impacts of their operations through employment opportunities, infrastructure development, and social programs benefiting local communities. However, the industry continues to face challenges and limitations in its efforts to minimize environmental impact. Accidental spills, leaks, and other incidents pose significant ecological risks, highlighting the importance of stringent safety regulations and emergency response protocols. Moreover, the transition to renewable energy presents challenges for traditional oil and gas companies, requiring substantial capital investment and strategic planning. To address these challenges and advance environmental stewardship, several future directions are proposed. These include accelerating the transition to renewable energy, enhancing transparency and accountability in reporting environmental performance, strengthening environmental regulations and enforcement, investing in research and development of innovative technologies, and fostering collaboration among industry stakeholders, governments, NGOs, and local communities. Keywords: Stewardship, Oil, Gas, Sustainability, Climate, Mitigation

Polyvinyl Alcohol/Zr-based Metal Organic Framework Mixed-matrix Membranes Synthesis and Application for Hydrogen Separation

AbstractMembrane gas separation is an environmentally friendly and economical method used to separate valuable gases, industrial process gas wastes, and carbon dioxide from mixed gases. The most important part of this method is the membranes. Gas separation membranes are expected to have high separation and permeability performance, high mechanical strength, easy and fast production capability, and low prices. Polymer-based membranes are mostly preferred depending on the ease of modification capability. In this study, a zirconium-based metal organic framework (Zr-MOF, MIL-140 A) was synthesized and used as a filler within polyvinyl alcohol (PVA) matrix for the selective separation of hydrogen (H2) from carbon dioxide (CO2). The effect of MIL-140 A addition on the mechanical, structural, and morphological properties of PVA was evaluated. The MIL-140 A significantly improved the mechanical strength of the membrane. According to the gas separation results, the increasing concentration of MIL-140 A increased the selective separation performance of the nanocomposite membrane. The highest mechanical strength (43.1 MPa) and best film-forming ability were obtained with 3 wt% MIL-140 A loaded membrane. The ideal H2/CO2 selectivity and hydrogen permeability were obtained as 5.6 and 944 Barrer, respectively at 2 bar feed pressure and room temperature. The highest ideal H2/CO2 selectivity was obtained as 6.3 with the H2 permeability of 959 Barrer when the MIL-140 A ratio was 4 wt%.