Journal articles on the topic 'American Gas Accumulator Company'

In some respects, the prospect of returning to some degree of normality is evident on the horizon. However, climate and the future of energy show little sign of a return to prepandemic normalcy. The future of our energy system is being transformed, and oil and gas are crucial for energy stability as well as the transformation. One of the miracles over the past year has been the accumulated knowledge around the human genome and application of this science to the rapid development of efficacious vaccines. As within oil and gas, humans can rise to the challenge to solve complex problems when identified. This is playing out as we see societal drivers around climate change and net-zero carbon emissions. Over the past year, SPE produced 11 events focused on the energy transition and continued the development of the Gaia Sustainability Program initiated by the SPE Health, Safety, Environment, and Sustainability (HSES) discipline. It is now a thriving community of SPE members across all disciplines committed to enabling and empowering all members and other interested parties who wish to engage in the alignment of the future of energy with sustainable development. An on-demand library of Gaia Talks and other resources has been built using the strategic programming framework (www.spe.org/en/gaia). Advances in our understanding and application of technology, and the development of those who can use it to better the world, are highlighted in the selections made for this month’s Technology Focus—genome sequencing of invasive species, technology to identify fatigue, and development of human capital for the industry in Kazakhstan. We must not forget the key element in any strategic improvement of performance: the human being. This starts with developing human capital at the university level. The industry is also working on progressing our understanding and application of human factors and human performance. As mentioned in the October 2020 JPT, the oil and gas industry has formed the Human Performance Oil and Gas (HPOG) alliance modeled after the very successful Dropped Objects Prevention Scheme program. The return to a more-normal life also means that our traditional conference model can reengage membership. Face-to-face meetings accelerate networking and the transfer of knowledge, which is core to the SPE mission. Events focusing on HSES this year include a planned in-person gathering the first week of November: HSES Focus on the Future—Responding to Changes and How the HSES Function Will Grow (3–5 November). This event will primarily cover health, environment, and sustainability with one panel on land transportation safety. It is strategically planned for the same week and at the same hotel in Fort Worth, Texas, where the American Institute of Mining, Metallurgical, and Petroleum Engineers will hold its first Joint Congress on Safety (1–3 November). A key element in building strategies within the SPE HSES discipline is the future of the function. Leading the efforts around this will be the newly formed HSES Executive Advisory Committee (EAC). This EAC, led by Fawaz (Fuzzy) Bitar, senior vice president of HSE and carbon at BP and former chair of the International Association of Oil and Gas Producers, includes HSE leadership from various upstream operators and contractors and will help with guidance and direction for SPE HSES Technical Director Annamaria Petrone. The EAC will hold a meeting and participate in plenary panels during the SPE HSES event in November. Recommended additional reading at OnePetro: www.onepetro.org. SPE 202737 6×6 Occupational Health Hazard Risk Rating Matrix: A Useful Tool in the Determination of Risk Levels of Workplace Health Hazards by Bufford Ang, Abu Dhabi National Oil Company, et al. OTC 30840 Self-Certification and Safety Compliance for Robotics Platforms by Osama Farouk Zaki, Heriot-Watt University, et al. SPE 201312 Long-Term, Periodic Aerial Surveys Cost-Effectively Mitigate Methane Emissions by Sri Sridharan, Pioneer Natural Resources, et al.

This study highlights the C O 2 , e -emission reduction potentials and related economic consequences for changing steam generation from fossil to renewable. Seven different utility concepts are developed, including a steam accumulator for load management. Peculiarities for the integration of biogas boilers, biomass-fuelled boilers, electrode steam boilers, biomethane-fuelled solid oxide fuel cells, micro gas turbine, solar energy systems, heat pumps and steam accumulators into a steam system with fluctuating steam demand are explained and the energy balance based models for the simulation study are described. The characteristics of batch processes, start up times and part load efficiency are considered via an annual dynamic simulation. Based on a detailed process analysis and dimensioning of the utilities and the accumulator a comprehensive simulation study is conducted for a pet food processing company having an average steam demand of 18,000 MWh at around 9 bar and 3 t/h. The results show that the highest C O 2 , e -emissions reduction of up to 63% is achieved by the transition to a solid biomass-fuelled boiler system. This leads to an increase of the operating costs by 27.8%.

Industrial stocks are stocks issued by industrial enterprises that produce non-consumer materials. Industries producing non-consumer data generally include extractive industry, manufacturing industry, electric power industry, gas industry and so on. The stocks issued by these industrial enterprises that produce non-consumer materials are called industrial stocks. Industrial stocks have a long history in United States. As early as 1900, industrial stocks became the majority of American stocks. In the same year that the United States overtook Britain as the country with the biggest economy in the world. Even today, more than a hundred years later, industrial stocks still play an important role in the U.S. economy and offer great investment value. In this article, three industrial stocks are selected and analyzed in different investing aspects, which can provide reference for the investors who are interested in industrial stocks. Three companies are the Boeing Company (BA), General Electric Company (GE), Ford Motor Company (F). The results show that BA is most risky and F is most profitable.

This article presents thoughts and experiences of R. Tom Sawyer, founder of International Gas Turbine Institute’s (IGTI) Turbo Expo. Sawyer founded gas turbine technical institute, and set its course for its first four decades, during which time the gas turbine itself, became one of the world’s most useful energy converters. Sawyer joined the American Locomotive Company where he was involved with both diesel and gas turbine projects from 1930 to 1956. R. He served as first chairman of the ASME Gas Turbine Power Division or Gas Turbine Division (GTD). Sawyer was a key organizer, helping to make the exhibit a successful revenue-producing part of the conference. R. Tom Sawyer was involved with IGTI to the end of his life in 1986.

Introduction: B cell lymphoma/leukemias (BCL) are a diverse set of malignancies. The genomic landscape of many BCL subtypes have been described. However, genomic ancestry has rarely been investigated. We applied SNP-based genomic ancestry prediction to comprehensive genomic profiling (CGP) data to identify significant enrichment of ancestry by subtype. We also explored enrichment of genomic alterations (GAs) by ancestry. Methods: During routine clinical care, 2834 unique patient (pt) samples of BCLs underwent CGP for 406 DNA genes and 265 RNA genes to detect all classes of GAs on the FoundationOne® Heme platform. This dataset was enriched for relapsed/refractory pts as they are more likely to have genomic testing as part of clinical care (referral bias). Each pt was assigned an ancestry of American (AMR), African (AFR), East Asian (EAS), European (EUR), or South Asian (SAS) using a SNP-based machine learning methodology (J. Newberg et al., AACR 2019). AMR was defined using a mix of Hispanic and Latin American populations. Enrichment analyses were performed using Fisher's exact test with FDR correction. Results: We compared the ancestry composition of each BCL subtype to the overall ancestry composition of the rest of the sample set (Fig 1A). Pts of AFR ancestry were overrepresented in plasmablastic lymphoma (PBL) (OR=7.2, P<0.05); EAS pts were overrepresented in Burkitt lymphoma (BL) (OR=4.99, P<0.05); and AMR pts were overrepresented in acute B-cell lymphoblastic leukemia/lymphoma (B-ALL) (OR=3.2, P<0.001). AMR SNPs have been associated with increased risk of B-ALL and worse prognosis (PMID: 21297632). We also investigated GAs enriched in specific ancestries. B-ALL AMR pts were enriched for GAs in IL7R, IGH, CRLF2, JAK2, and IKZF1 compared to other ancestries in B-ALL (Fig 1B). These genes were associated with the high-risk Philadelphia chromosome-like ALL (Ph-like ALL) molecular subtype of B-ALL (PMID: 30181314). We found 33% of all B-ALL contained GAs consistent with Ph-like ALL (PMID: 30181314). While we noted enrichment of AMR pts in the overall B-ALL cohort, we identified additional enrichment in the Ph-like B-ALL cohort with 47% of Ph-like B-ALL pts being of AMR ancestry (OR=1.85, p<0.001). AMR pts accounted for almost half the Ph-ALL pts in this cohort; however, even in B-ALL pts without Ph-like genomic features, 32% were of AMR ancestry suggesting this enrichment is not simply due to increased CGP testing in Ph-ALL. In diffuse large B cell lymphoma (DLBCL), we found pts to be primarily of EUR ancestry, however we identified ancestry bias in GAs (Fig 1C). CD79B alterations were enriched in DLBCL pts of SAS ancestry, although not significant after FDR correction, consistent with previous reports of increased Activate B-Cell (ABC) cell of origin (COO) subtype and BTK signaling in pts from South East Asia (PMID: 31189540). CDKN2A, also frequently altered in ABC COO subtype, trended towards enrichment in EAS ancestry. CUX1, a tumor suppressor involved in PI3K signaling, was strongly enriched in AFR pts in both DLBCL and B-ALL. One CUX1 insertion variant (G870_G871insSGG) was particularly common in AFR pts with BCL (7/9 AFR, 2/9 AMR), which has been reported previously in Myelodysplastic syndromes (PMID: 24030381). CUX1 alterations have been reported to be associated with increased PI3K signaling suggesting in part PI3K inhibitor trials should proactively include pts of AFR ancestry (PMID: 24316979). Finally, EZH2 alterations were slightly enriched in AMR DLBCL pts, but showed no ancestry bias in follicular lymphoma (FL) pts, of interest given the recent EZH2 inhibitor approval in FL. Conclusions: This study described multiple important genomic differences in BCL using genomic ancestry rather than patient-reported descriptive variables. Enrichment of AMR ancestry was observed in B-ALL overall, and in Ph-like B-ALL. In addition, enrichment of CUX1 alterations was observed in both DLBCL and B-ALL of AFR ancestry. While precision medicine holds the promise to advance cancer care, many acknowledge the potential to unintentionally deepen existing health disparities (PMID: 31112478). Further analysis of ancestry informative markers in BCL, including enrichment of ancestry markers in specific cancer subtypes and ancestry-associated enrichment of specific GAs, may lead to insights into cancer biology and contribute to ongoing cancer health disparities research. Disclosures Moore: Foundation Medicine, Inc: Current Employment; Roche Holdings: Current equity holder in publicly-traded company. Evens:Abbvie: Consultancy, Honoraria; Mylteni: Consultancy, Honoraria; Research To Practice: Honoraria, Speakers Bureau; MorphoSys: Consultancy, Honoraria; Novartis: Consultancy, Honoraria; Pharmacyclics: Consultancy, Honoraria; Merck: Consultancy, Honoraria, Research Funding; Epizyme: Consultancy, Honoraria, Research Funding; Seattle Genetics: Consultancy, Honoraria, Research Funding. Newberg:Roche Holdings: Current equity holder in publicly-traded company; Foundation Medicine, Inc: Current Employment. Severson:Foundation Medicine, Inc: Current Employment; Roche Holdings: Current equity holder in publicly-traded company. Mills:Foundation Medicine, Inc: Current Employment; Abbvie: Current equity holder in publicly-traded company; Roche Holdings: Current equity holder in publicly-traded company; Abbott: Current equity holder in publicly-traded company; Merck: Current equity holder in publicly-traded company. Vergilio:Roche Holdings: Current equity holder in publicly-traded company; Foundation Medicine, Inc: Current Employment. Trabucco:F. Hoffmann-La Roche, Bristol-Myers Squibb Co., BioNTech: Current equity holder in publicly-traded company; Patent pending with Foundation Medicine and Genentech: Patents & Royalties: Patent pending; Foundation Medicine, Inc.: Current Employment; Bristol-Myers Squibb Co: Current equity holder in publicly-traded company; BioNTech: Current equity holder in publicly-traded company; Loxo Oncology: Divested equity in a private or publicly-traded company in the past 24 months. Ganesan:M2GEN: Research Funding; Foundation Medicine, Inc: Consultancy; Inspirata: Consultancy; Merck: Consultancy, Current Employment, Current equity holder in publicly-traded company; Silagene: Consultancy; Foghorn Therapeutics: Consultancy; Roche: Consultancy; Novartis: Consultancy.

Oil and gas (O&G) production activities emits greenhouse gases (GHG) which must be well estimated to improve accountability and formulating efficient mitigation. The Indonesia’s GHG emission reported thru Nationally Determined Contribution (NDC) was estimated by Tier-1 Intergovernmental Panel on Climate Change (IPCC) method, while the O&G company adopts different methodology. This leads to asynchronous GHG emission contribution of this industry to national GHG emission. This paper aims to estimate the GHG inventory from O&G offshore production facility by using American Petroleum Institute (API) Compendium Methodology and compare it with Tier-1 IPCC Methodology. It found that GHG emission estimated by API method is significantly lower than IPCC method. Both methods shown fuel combustion sources are the dominant. GHG emission sources from fuel combustion and flaring have been well identified, but emission sources from venting and fugitive need to be improved. Moreover this study identified that to have more accurate national GHG inventory, the GHG calculation method might be different for each industry segment. This evaluation could improve the future national GHG inventory and as reference for the industry. National emission factors database for O&G industry segment is highly suggested to be developed.

Introduction. A scientific research examining the concern of Gazprom PJSC (a leading Russian energy company) stock quote forecasts is relevant because it could determine investment prospects in the stock market of the Russian Federation. The key idea of this work is to find the most profitable and investable Russian company and outline the factors among many others that affect its stock quotes. Purpose . The author attempts to construct multiple linear regression equations reflecting the impact of the economic factors (the prices of the American natural gas, the USD/RUB currency pair, the M2 monetary aggregate in Russia) on the Gazprom PJSC stock quotes. These multiple linear regression equations are used to develop economic and mathematical models with the projected values of the factors. Materials and Methods . The paper refers to the general and special scientific methods – analysis, synthesis, a monographic method, and statistical methods – graphs, tables, trend spotting, correlation and regression analysis. The choice of independent variables in the correlation and regression analysis was driven by several factors: global natural gas prices determine the fi nancial performance of the Russian energy companies; the revenue of the Russian exporters has long been dependent on the USD/RUB currency pair; security quotes rose at the stock markets due to the monetary policy of central banks which strive to build up the monetary supply. Results. The study developed the equations of multiple linear regressions for the selected four periods with different economic scenarios. This proves the relevancy of the issue under analysis. These equations reflect the dependence of the Gazprom PJSC stock quotes from the prices of the American natural gas, the USD/RUB currency pair, and the money supply in Russia. They could give rise to the economic and mathematical models with the projected values of the analyzed factors and their possible correlations. Conclusion . The economic factors in question could have a positive impact on the Gazprom PJSC stock quotes against a weak Russian ruble and the national energy companies refocusing their attention on other markets. This information could be of use for the economic entities to boost their investment performance.

Large rectangular gas ducts installed in power plants usually need inner supports to ensure their stability. Generally two schemes are used for setting inner supports. One is National Standard Specification (NSS) and the other is an American Combustion Engineering company design criterion (CE). The design level of inner supports in flue pipe has a great effect on flow distribution. In this paper, three kinds of inner supports which are common in power plants are simulated by using computational fluid dynamics (CFD). Through a comprehensive analysis of their flow fields and pressure, it can be concluded that NSS inner supports which are thinner, vertical to each other and have more rows is the best design scheme among these three kinds of inner supports.

Knowledge’s processes enrich the information bringing value to organizations. These formal or informal, processes increase the value of information and useful knowledge of people and organizations. Therefore, in order to identify good practices that promote the improvement of processes for the implementation of knowledge management in the area of transport hydrocarbon, this exploratory study it perform on ECOPETROL, Colombia's largest oil company. Due to its size, it belongs to 40 largest oil and gas companies in the world´s group and recognize as one of the four major in Latin American. The study target the workshops developed within the Operations and Maintenance teams using the methodology of the Knowledge Assurance Guide. The results show positive impacts identifying best practices that support process improvement in the tactical, strategic and operational levels.

The avant-garde Japanese company Ban'yu Inryoku was formed following the death in 1983 of the inspirational writer and director Shuji Terayama, who has subsequently become a cult figure. This article explores his influence – both limiting and liberating – on the production by one of the founders of the company, his disciple J. A. Seazer, of an experimental musical version of King Lear, as Ria O. Douglas Kerr places the production – seen in England during the Japan Festival of 1991 – within the context of evolving attitudes towards the avant-garde theatrical movement in Japan during the late 'sixties, notably as modified by the national trauma of the gas attack in Tokyo of 1995. Adapting Shakespeare was a break with the Terayama tradition of presenting only works collectively created by the ensemble – and it also made their work more accessible to the intercultural festival circuit. Explicated by the printed synopsis which forms a ‘map’ of the play for its audiences, the production also used Brechtian signboards to signal the titles of scenes, while being predicated also on the ‘representation of the inner and the outer experience’ which was Artaud's perception of Balinese performance. Lear himself was in this sense the entranced dancer, depending on the guidance of his supporters. Douglas Kerr, who explores here the tensions between the cultural elements employed and between the ideological pulls for conservatism and for social change, is currently an advanced PhD student at Stanford University in American Literature. His interests include Performance Poetics and Buddhism in contemporary American poetry.

Uncertainty of crude oil market causes the value of oil and gas exploration assets to fluctuate upward, remain unchanged, and fluctuate downward. So exploration project investment is usually chartered by multistages. This brings many challenges to investment decisions regarding the sustainable utilization of exploration assets. To avoid the investment risk of exploration projects, a portfolio option method based on the trigeminal tree model was proposed. By analysing the real options involved in oil and gas exploration assets, the investment process is divided into European options and American options. The pricing model of portfolio options is constructed by the trigeminal tree method, and sequential compound diagram and compound option diagram are built. Volatility is predicted based on the GARCH model, and then, the trinomial tree of the underlying asset value, evolution chart, sequential compound option chart, and portfolio option chart is established, respectively. Finally, the project option value is calculated. The application shows that the ROV of oil and gas exploration project of company A is 1.39 million US$ (USMM$), and the project value is 279.87 USMM$. Compared with the binary tree model, the model is superior to the traditional option pricing method in the application effect, which provides a scientific basis for investment decision-making.

A gas well blowout in south central Texas in November 2019 that lasted for 20 days provided a unique opportunity to test the Hybrid Single-Particle Lagrangian Integrated Trajectory (HYSPLIT) model’s plume dispersion against hydrocarbon air monitoring data at two nearby state monitoring stations. We estimated daily blowout hydrocarbon emission rates from satellite measurement-based results on methane emissions in conjunction with previously reported composition data of the local hydrocarbon resource. Using highly elevated hydrocarbon mixing ratios observed during several days at the two downwind monitoring stations, we calculated excess abundances above expected local background mixing ratios. Subsequent comparisons to HYSPLIT plume dispersion model outputs, generated using High-Resolution Rapid Refresh (HRRR) or North American Mesoscale (NAM) forecast meteorological input data, showed that the model generally reproduces both the timing and magnitude of the plume in various meteorological conditions. Absolute hydrocarbon mixing ratios could typically be reproduced within a factor of two. However, when lower emission rate estimates provided by the company in charge of the well were used, downwind hydrocarbon observations could not be reproduced. Overall, our results suggest that HYSPLIT, in combination with high-resolution meteorological input data, is a useful tool to accurately forecast chemical plume dispersion and potential human exposure in disaster situations.

_ Early January brought with it significant changes in the environmental side of the oil and gas industry. ExxonMobil and Chevron, the two largest US oil producers, announced they will exit California, and the Biden administration froze LNG export approvals. After 50 years of producing oil in California, ExxonMobil will take a $2.5 billion writedown of the value of some of its California properties to be recorded in its fourth-quarter earnings. The company said the decision is primarily related to its Santa Ynez operations off the coast of Santa Barbara. Its US Securities and Exchange Commission (SEC) filing said, “While the Corporation is progressing efforts to enable a restart of production, continuing challenges in the state regulatory environment have impeded progress in restoring operations.” After the Refugio oil spill in May 2015 (approximately 100,000 gal), resulting from a leak from a pipeline owned by Plains All American Pipeline, ExxonMobil acquired the damaged asset in October 2015. Just a few months before the purchase, the Santa Barbara County Board denied ExxonMobil’s request to truck its oil produced off the coast of Gaviota to its Las Flores Canyon processing facility and on to refiners located in Pentland, California. Seeking an alternative, ExxonMobil planned to replace two stretches of the 112-mile corroded pipeline for transit of its oil. Met with opposition to replace the damaged pipeline and denied permission to repair and restart production at the site (halted since 2015), ExxonMobil is now selling the Santa Ynez operation to Sable Offshore, a blank-check company created in 2020. The company will loan Sable the money for the purchase of its three offshore production platforms, pipeline, and onshore processing facility. Sable’s agreement with ExxonMobil requires production to be started by early 2026 or the assets and liabilities revert to ExxonMobil. Chevron, headquartered in San Ramon, California, will write down $3.5 billion to $4 billion in assets, citing its home state’s regulations that “have resulted in lower anticipated future investment levels.” The company intends to continue operating its oil fields and related assets. In the SEC filing, Chevron wrote it also will incur fourth-quarter charges related to decommissioning of US Gulf of Mexico assets that have reached the end of their productive lives. The company sold some of those assets, but US law stipulates that previous owners may be responsible for those costs if the current owner declares bankruptcy. Chevron wrote it’s “probable” that it may see such costs. January closed with another unexpected announcement on 26 January. The Biden administration paused decisions on permits to export LNG to non-free trade agreement countries to review current projects seeking approvals. US Energy Secretary Jennifer Granholm stated, “We must review export applications using the most comprehensive, up-to-date analysis of the economic, environmental, and national security considerations.” She added that this was not a ban on exports and would not affect already authorized exports, which when combined with existing plants, total 48 Bcf/D. “Within this decade another 12 Bcf/D of US export capacity already authorized and under construction will come online,” Granholm said. While environmental impact (greenhouse gas emissions including CO2 and methane) was one of the reasons for the decision, along with market, economic, national security, and energy security, Granholm pointed out that facilities totaling 22 Bcf/D of capacity have been approved but have not yet started construction. This capacity, combined with existing infrastructure, is “more than enough to make the US a ‘behemoth’ in the LNG field,” according to Holland & Knight in an analysis dated 29 January. The international law firm said this raises the question of whether further development of LNG facilities could hurt US citizens as higher percentages of produced gas are exported. “This line of thinking follows the historical rhetoric on this issue as domestic users of natural gas want to ensure their feedstock price is stable. To support those claims, recent studies have concluded that ‘higher LNG exports create a tighter domestic natural gas market (all else held equal), increasing domestic natural gas prices.’” Could unintended consequences of these recent announcements rear up in the future? And could they be a behemoth for the US or global markets? For Further Reading Growth in 2022 US LNG Liquefaction Capacity Hits Top of the Charts by Pat Davis Szymczak, SPE Oil and Gas Facilities.

With respect to the problem of the low accuracy of traditional building energy prediction methods, this paper proposes a novel prediction method for building energy consumption, which is based on the seamless integration of the deep neural network and transfer reinforcement learning (DNN-TRL). The method introduces a stack denoising autoencoder to extract the deep features of the building energy consumption, and shares the hidden layer structure to transfer the common information between different building energy consumption problems. The output of the DNN model is used as the input of the Sarsa algorithm to improve the prediction performance of the target building energy consumption. To verify the performance of the DNN-TRL algorithm, based on the data recorded by American Power Balti Gas and Electric Power Company, and compared with Sarsa, ADE-BPNN, and BP-Adaboost algorithms, the experimental results show that the DNN-TRL algorithm can effectively improve the prediction accuracy of the building energy consumption.

This paper explores the relationship between information access and environmental and ecological justice through an historical comparison of two controversial coastal developments in Aberdeenshire, North-east Scotland: the building of a North Sea gas reception terminal by the British Gas Council and the French exploration company Total Oil Marine in the 1970s; and the more recent construction of ‘the greatest golf course anywhere in the world’ by the American property tycoon, Donald Trump. These two projects have much in common, not least because each one has had actual or potential impacts on an environmentally sensitive site, and because each has also been affected by plans for another major structure in its immediate vicinity. But the Trump golf course project has taken place during a period when access to information and citizens’ influence on major planning decisions in Scotland has been significantly greater, at least theoretically. With these points in mind, the paper considers whether or not environmental justice (more specifically, procedural environmental justice) and ecological justice are now more attainable in the current era of supposed openness, transparency and public engagement, than in the more secretive and less participative 1970s. It reveals that, at the planning application stage, information on the potential environmental impact of Trump’s golf resort was more readily obtainable, compared with that provided by the Gas Council and Total forty years earlier. However, during and after the construction stage, when considering whether or not the developments have met environmental planning conditions – and whether or not ecological justice has been done – the situation with the gas terminal has been far clearer than with Trump’s golf resort. Despite the golf course being built in an era of government openness, there remain a number of unanswered questions concerning its environmental impact.

The goal of this work is to look into how the glow discharge plasma jet system changes the chemical and physical features of water. In this work, the physical and chemical properties of water were studied by using a plasma jet with Argon gas. 10 cm3 of distilled water was put in a glass dish with a diameter of 5 cm and a depth of 1 cm. The system was run with an AC voltage of 12 kV and a frequency of 20 kHz, and the exposure time ranged from 1 to 30 minutes. With amounts of 0.7, 1.0, 1.5, and 2.1 l/min, kits made by the American company Bartvation were used to measure the types of reactive oxygen and nitrogen species (RONS) that were formed. The data showed that the levels of NO2, NO3, and H2O2 were all too high. It gets bigger over time and as the flow rate goes up. The pH goes down with time until it hits 3, and the temperature goes up until it reaches 33°C. However, the pH goes up with storage time, and after 24 hours the water is back to its natural pH of 7. The amount of NO2, NO3, in the air goes up a little bit, and then starts to go down rapidly after 6 hours. After 24 hours, it is close to zero. From this, it's clear that the glow discharge plasma jet device can make RONS, which can be used for biological purposes.

The article presents experiments for the development of the welding technology for plates of the steel S355JR, according to EN 10025-2:2004, for ship building and harbor structures.Marine steel plate grades for ship hull, according to ABS, American Bureau of Shipping, are presented, compared with the S355JR steel.For applications on board ships, the standard EN ISO 5778:1998 is also mentioned. It specifies the materials and quality levels for small weathertight steel hatches.The filler metal is the copper-coated, manganese-silicon-alloyed solid wire, type SG-3, according to EN ISO 14341:2020. The shielding gas is the gas mixture CORGON 18/82, according to EN ISO 14175:2008, type M21.As a welding travel unit, the modular drive system MDS-1, made by the company BUG-O Systems, of USA was used. It has the following main components: 1- rack-based track; 2- carriage; 3- master drive unit; 4- clutch; 5- weaver control module; 6- linear weaver unit; 7- linear weaver cross arm; 8- gun mounting group; 9- welding gun.The welding source is the Inverter MIG 300 A type, manufactured by Mahe GmbH, Germany.The sizes of the two plates for the welding test piece are: length 700 mm; width 200 mm; thickness 15 mm, I groove with 8 mm gap.The welding parameters used for all the layers (root, fill #1 - fill #4) are presented in a common table, for comparison.The parameter ranges are as follows: welding current 177-251 A; welding voltage 21.9-23.1 V; wire advance speed 6.5-7.2 m/min; shielding gas flow rate 20.8-21.8 liters/min; welding speed 20-45 cm/min. A special spin-arc welding method was applied on all weld layers. The execution of the welding test piece is described with specific details and photos.Upon visual inspection after the execution of each layer, the appearance is adequate. No defects or imperfections are observed.On ultrasonic examination, the results are adequate.Metallographic examination, tensile, bending and Charpy V impact tests are presented with appropriate results.The conclusions mention the adequate results obtained, regarding the ranges of the welding parameters and the use of the innovative spin-arc technology. Possible applications of the S355JR steel are recommended.The references present titles related to ship building steels, filler metal, shielding gas, welding equipment and some specific technologies.

The synthetic ammonia industry, originally based on Fritz Haber's 1909 invention of a catalytic high-pressure method as scaled up by Carl Bosch at BASF, grew globally in the years following World War I, based on the processes of Brunner, Mond & Co. (Britain), Luigi Casale (Italy), Georges Claude (France), and Giacomo Fauser (Italy). The ammonia was mainly converted into ammonium sulphate fertilizer. There was less impetus in the United States for taking up these developments, because America relied on ammonium sulphate from its by-product coke ovens, sodium nitrate (Chilean nitrate) from South America, ammonia from coal gas works, and calcium cyanamide as manufactured by the American Cyanamid Company. Even when a synthetic ammonia industry started up in the United States, it was on a smaller scale than in Europe. However there emerged just before the Wall Street Crash two major producers of synthetic ammonia, Allied Chemical and Du Pont. This article presents a historical reconstruction of the early synthetic ammonia industry in the United States focusing on the 1920s, paying particular attention to Du Pont's success, which relied on the ammonia process of Casale. Standard accounts suggest that Du Pont acquired Casale technology as the result of a straightforward business acquisition. However, the situation, as shown here, was far more complex. Du Pont had to engage in aggresive litigation in order to acquire rights to the Casale process in 1927.

The Russia-Ukraine war led to disruptions in the global energy supply chain and increased inflation. Western countries imposed sanctions to restrict Russian energy exports, triggering market shocks. This essay analyzes how the confrontation between Russia and Ukraine on February 24, 2022 may affect stock markets and energy markets throughout the world. The article selects the closing price of Chevron's stock from January 3, 2011 to July 28, 2023 as the raw data, and uses an ARIMA model to analyze the changes in Chevron's stock price and demonstrate the war between Russia and Ukraine's effects on it from multiple perspectives. It has been discovered that geopolitical developments may possess a significant short-term influence on stock values, but over time, the market gradually shifts its focus from a single event to a wider range of market factors, thus weakening the impact of geopolitical events on stock prices. This paper aims to fill the research gap on the stock price reactions of oil and gas companies in the face of conflict by analyzing the stock price changes of the energy company Chevron to show how global developments affect the American energy market, and to aid investors in evaluating the risks and possibilities, as well as to shed light on the market volatility and long- and short-term impacts of the energy sector. Finally, the paper provides investment recommendations that summarize the main points of the full paper.

The purpose of the article is to summarize and present the fundamental trends of the last decade related to the formation of the role and place of risk management in the system of corporate governance of multinational enterprises (MNEs). The analysis is based on the latest research by leading international researchers, such as American scientists Warren Bennis, Bert Nanus, Hugh Grove and Lorenzo Patelli, British scientists Mingzhui Wang, Elizabeth Kelan and Kevin Crowley, international organizations Basel Committee on Banking Supervision, Group of Thirty, Institute of international finance and the Organization for Economic Cooperation and Development. The conducted analysis clearly indicates that failures in MNEs risk management over many years led to catastrophic losses in various industries, when such failures, as in the energy sector, led not only to financial, but also to significant environmental consequences. Among the most significant incidents, we can highlight the accidents on the oil platform "Deepwater Horizon" of the British oil and gas company BP in 2010 in the Gulf of Mexico and the Japanese nuclear power plant Fukushima-1 in 2011. Often these failures also contributed to failures in corporate governance, where boards of directors did not fully consider the risks that MNEs were taking and/or imperfect risk management systems. Thus, the conceptualization of risk management in the system of corporate governance of MNEs becomes an important component of achieving medium and long-term strategic goals of MNEs in conditions of growing macroeconomic and geopolitical uncertainty.

The oil and gas industry is recovering along with the health situation and the world’s economy following one of the largest downturns in its 160-year history caused by the COVID-19 pandemic. What comes ahead brings its own challenges. The recent Intergovernmental Panel on Climate Change’s (IPCC) Working Group 1 contribution to the IPCC’s Sixth Assessment Report, Climate Change 2021: The Physical Science Basis, published in August, highlighted the “widespread and rapid acceleration of climate change,” with the 1.5°C threshold reached as early as the end of this decade. The dramatic weather events around the globe this summer (in the Northern Hemisphere) with historical temperature records on the North American Pacific Coast and in the central and eastern Mediterranean regions, and huge fires impacting those regions and others such as Siberia, were a reminder that the transformation is occurring now. In this context, the energy mix that the world uses today needs to evolve to a more rational use through energy efficiency and with a lower carbon content, starting from the use of coal. The oil and gas industry has been pioneering the development of technologies such as carbon capture and underground storage and blue hydrogen. International oil companies and national oil companies rank amongst the largest technology investors in renewables and energy storage. Renewables also have a strong potential in applications such as steam injection. Collaboration among the industry and with other peripheral sectors will be an essential ingredient to accelerate the transformation of the energy sector. I personally started in the oil and gas industry more than 4 decades ago in research and development (R&D) with a large oilfield service company, where I led a team of scientists investigating hydraulic fracturing. One of the projects was related to acid fracturing, which required the injection of a viscous non-Newtonian pad to fracture the formation and keep the fracture open, followed by acid which had a much lower viscosity. The two-fluid displacement inside the fracture led to an instability called viscous fingering. In order to understand the phenomenon, we put together a very diverse team, comprising a mathematician, an astrophysicist, a physicochemist, and a geologist. The team was unable to initially work well together and collaborate. The breakthrough came when a high-level scientist from Boston University, a specialist in critical phenomena, was added as a catalyst to the team. Within a few months, the team managed to develop and validate a model for viscous fingering using diffusion-limited aggregation and fractal theory, and its work was published in Nature and the American Physical Society’s Physical Reviews Journals. The team then developed a new set of models for wormholes created by the injection of acid through matrix acidizing and fracture acidizing which were used to create the required chemistry to ensure effectiveness of the treatments. I remain convinced that if we had not included the diversity of the skills and used a catalyst for collaboration, we would not have cracked the research code so rapidly.

The Asri and Sunda Basin are located offshore Southeast Sumatra under the SE Sumatera Production Sharing Contract (PSC). Currently, Pertamina Hulu Energi OSES operates in the Asri and Sunda Basins, known as Southeast Sumatra (SES) Block. As one of Indonesian prime oil and gas producing area in the past 50 years, these basins have produced cumulatively more than 1,500 MMBOE with an average of 90,000 BOPD. Both Asri and Sunda Basins are part of a series of Cenozoic half grabens developed on the Asian continental margin, that have occupied a retro arc setting since early Neogene times.Hydrocarbon exploration activities in the offshore southeastern Sumatra began with a signed agreement of Contract Sharing between IIAPCO (Independent Indonesian American Petroleum Company) and Pertamina on 6 September 1968.The contract area included the offshore areas east of Sumatra and south of Bangka - Belitung Islands, covering an area of 124,000 km2. After the final relinquishment in 2008, the current PSC boundary covers an area of 5,851 km2.This paper presents the results of integrated petroleum geosciences framework, its implications for Oligo-Miocene reservoirs and hydrocarbon prospectivity of the basins using near field exploration approaches. A four-fold division comprising rift initiation, rift climax, immediate post rift and late-post rift stages of basin evolution characterize the basin filling. Seismic expression of these kinematic units gives an idea about the linkage of their deposition with different stages of rift evolution. The present study has also identified a new potential play concept in Oligo -Miocene reservoirs.

The present article presents cumulative works, which were carried out in the field of micro-alloying steel processing at Central Metallurgical R&D Institute (CMRDI) and/or full scale trials in collaboration with the Egyptian steel industry.It was agreed upon defining three main generations of processing micro-alloying steel. The 1stgeneration starts officially on 1975 and continues up to 1995, where it deals with using Ti and V as micro-alloying elements for steel long products. On the year 1985, Central Metallurgical R&D Institute (CMRDI) succeeded to implement of HSLA V-micro-alloyed rebar steel grades at Delta steel mills instead of conventional rebar grades.The 2nd generation was starting on late 1995 and continued to 2005. It was dealing mainly with low carbon content steel (0.04-0.08 %) for flat products (plate and sheet). The most successfully used micro-alloying element was Nb. Beside its precipitate forming effect, Nb is working as substitution solid solution strengthener. Moreover, it raises the recrystallization temperature (Tr). Mainly, micro-alloyed flat steels were developed to fulfill the requirements of the American Petroleum Institute (API) specifications 5L- Product Specification Levels (PSL1) and (PSL2) for manufacturing oil and natural gas pipelines. Meanwhile, a newly born Compact Slab Processing (CSP)-hot strip direct rolling technology was created. On years 2002, the metal forming department in CMRDI succeeded to implement controlled rolling of hot strip Nb-steel sheet at the Compact Slab Process (CSP) Machine in Alexandria National Iron and Steel (ANSDK) Company. Controlled hot rolling schedules were used and followed by early and late cooling at the run out table (ROT). Both contracts were fruitfully succeeded to introduce the API X52 grade at ANSDK Company, followed by X60, and X70 steel grades at Ezz Flat Steel (EFS) Company. The essential mechanical properties of the processed API steel sheets were matched with the API 5L-PSL2 specifications.The 3rd generation was initially developed after 2005 and continued up to day. It deals with micro-alloying with special functional elements like Boron (B). Boron was favored as a micro-alloying element for bilateral effects. Boron carbide (B4C) precipitates are the hardest after diamond, which would be reflected on raising the mechanical properties of the steel. Moreover, Boron was favorably used because it delays the temper embrittlement phenomena. On year 2014, the National for Military Industrialization authority requested from CMRDI to collaborate with Military Factory 100 to develop a technology package for processing armor steel plates. Trials were started with a 3rd generation B-micro-alloyed steel alloy. Many other alloying elements were used beside Boron to develop extra high strength 6.0 mm thickness plates. Finish hot rolled plates were then subjected to a subsequent water quenching from 900 °C and followed by tempering at 250 °C for 20 min. Representation 50X50 cm2 steel plates were successfully passed after 3 bullets in front and 3 bullets rear shooting.

Active petroleum exploration in East Greenland is of fairly recent date and was preceded by a much longer history of scientific work and mineral exploration. The discovery in 1948 of lead-zinc mineralisation at Mestersvig resulted in the formation of Nordisk Mineselskab AIS in 1952. In the beginning of the seventies Nordisk Mineselskab initiated cooperation with the American oil company Atlantic Richfield (ARCO) in order to undertake petroleum exploration in Jameson Land. The Jameson Land basin contains a very thick Upper Palaeozoic - Mesozoic sedimentary sequence. Important potential source rocks are Lower Permian lacustrine mudstone, Upper Permian black marine mudstone, Middle Triassic dark marine limestone, uppermost Triassic black marginal marine mudstone, Lower Jurassic black mudstone and Upper Jurassic deep shelf black mudstone. Tbe Upper Permian mudstone, which is the most promising source rock, is immature to weakly mature along the western basin margin and is expected to be in the oil or gas-generating zone when deeply buried in the central part of the basin. Potential reservoir rocks include Upper Permian bank and mound limestones, uppermost Permian fan delta sandstones, Lower Triassic aeolian and braided river sandstones, and Lower, Middle and Upper Jurassic sandstones. The most important trap types are expected to be stratigraphic, such as Upper Permian limestone bodies, or combination stratigraphic-structural such as uppermost Permian or Lower Triassic sandstones in Early Triassic tilted fault blocks. In the offshore areas additional play types are probably to be found in tilted Jurassic fault blocks containing thick Lower, Middle and Upper Jurassic sandstones and lowermost Cretaceous sandstones and conglomerates. The recognition of the potential of the Upper Permian in petroleum exploration in East Greenland has important implications for petroleum exploration on the Norwegian shelf.

The use of low frequency or DC (i.e., direct current) operation in the electroslag remelting process may lead to the electrolysis of some oxides in the slag pool, which will adversely affect the cleanliness of the electroslag ingot. In order to confirm this view, the effect of different power supply modes on the oxygen content and inclusions in electroslag ingot has been studied by adopting the self-designed electroslag remelting furnace as experimental equipment. The pulse heating inert gas fusion-infra-red absorption method is used for analyzing oxygen content. The analysis of non-metallic inclusion is conducted using an automatic SEM (i.e., scanning electron microscope) made by the American ASPEX Company, where the inclusion type and the inclusion size are determined. Results show that the oxygen content in the electroslag ingot increase significantly compared with that in the consumable metal electrode, whether under the frequency of 50 Hz, low-frequency, or DC. When DCSP (i.e., the consumable electrode is connected to the cathode of the DC power supply), DCRP (i.e., the consumable electrode is connected to the anode of the DC power supply), 2 Hz, 10 Hz, and 50 Hz power supply modes are adopted, the oxygen content in electroslag ingot is 155.3 ppm, 100.4 ppm, 75.8 ppm, 66.3 ppm, and 43.2 ppm respectively. With the increase in oxygen content, the number of inclusions in electroslag ingots increases significantly, and the increased inclusions are mainly Al2O3 inclusions. Regardless of the power supply mode, the largest diameter of inclusion is less than 20 μm. The electrolysis of Al2O3 is the direct reason for the increase in oxygen in the electroslag ingot when CaF2-Al2O3 slag is used. With the decrease in frequency, the electrolysis trend increases, and the oxygen content and the number of inclusions also increase. However, most of the inclusions are regenerated with the decrease in metal pool temperature and solidification, so the size is fine.

2022 SPE President Kamel Ben-Naceur Kamel Ben-Naceur is CEO of Nomadia Energy Consulting, where he advises on sustainable energy policies and global and regional energy economics and outlooks. He has worked as the chief economist for a major oil and gas company and for an oilfield services company. Ben-Naceur has also worked as a director of the International Energy Agency and as the industry, energy, and mines minister for the Tunisian government. He has chaired several SPE global committees, including Business Management and Leadership, the International Forum Series, and CO2 Capture, Utilization, and Storage. He has also taught several SPE courses on global energy and strategic thinking and planning. He was technical director for the Management and Information discipline on the SPE International Board of Directors from 2008 to 2011. Ben-Naceur was also an SPE Distinguished Lecturer during the 2009–2010 season and received an SPE Distinguished Member Award and SPE Distinguished Service Award in 2014, the AIME Charles F. Rand Memorial Gold Award in 2019, and the 2020 Sustainability and Stewardship in the Oil and Gas Industry Award. He has coauthored more than 150 publications and 17 books. Ben-Naceur holds the Agrégation de Mathématiques degree from the École normale supérieure and a master’s degree in engineering from École Polytechnique in Paris. What key issues will you emphasize as 2022 SPE President? Our industry, along with many other economical sectors, has experienced a major impact from the pandemic. The magnitude of the drop in oil demand in 2020, both in absolute and relative terms, is unprecedented. It led also to a major reduction in oilfield investment activity around the world, in the order of 30% compared to pre-COVID-19 levels. The fast-track development of vaccines and their availability, even though progress is still required to ensure that they are distributed fairly around the world, is raising hope that the worst may be behind us. SPE members have also been impacted in their ability to meet at technical conferences and exhibitions and participate in workshops or forums. As 2022 SPE President, the theme I wish to develop is the “sustainable recovery” for our industry and for SPE. The industry has experienced in 2020–2021 a major loss of valuable employees ranging from young professionals to senior members. This has followed a major downcycle in 2014–2015. After a 30% drop in Capex in 2020 compared to 2019, 2021 should see a modest recovery in activity (6–8% increase). The next year should welcome a 10–12% activity surge, providing an increase in employment opportunities for our members in transition, as well as for our student members. Barring new negative developments in the pandemic, the recovery in activity should strengthen to reach pre-COVID levels by 2025, albeit 15–20% below the level that was expected before. The recovery of demand and activity should also be linked to a more sustainable trajectory of energy demand and supply. Sustainability will be my second area of focus, with SPE having already engaged significantly. I had the opportunity to participate in the startup of the SPE GAIA Sustainability Program, which is now developing into many different directions, thanks to the efforts of SPE volunteers. 2019 SPE President Sami Al-Nuaim had put sustainability at the heart of his presidency, and I am pleased to see several of his initiatives materialize. The third area of focus will be a gradual restart of physical meetings, where we will transition with the increase of hybrid (in-person/virtual) events, which is eagerly anticipated by our members. The fourth area of focus is related to the development of the new SPE Strategic Plan. Last but not least, is the proposed merger between SPE and the American Association of Petroleum Geologists (AAPG).

Uranium-zirconium carbonitride has been developed at the Federal State Unitarian Enterprise Scientific Research Institute the Scientific Industrial Association "Luch" (LUCH FSUE) and is a high-density high-temperature fuel with high heat conductivity capable of being used in various types of reactors, including fast reactors. The main problem hindering wide application of this fuel is insufficient knowledge of its behavior under irradiation, especially at high burnup. In the USSR, HEU UZrCN (96% by U-235) fuel underwent reactor testing to a low burnup of approximately 1%. However, to confirm practical applicability of this fuel, the fuel needs to be reactor tested at a high burnup. In the framework of a joint Belarussian-American-Russian effort, LEU (19.75% by U-235) UZrCN fuel will undergo reactor testing to a burnup of approximately 40% in the SM-3 reactor at the Joint Stock Company "State Scientific Center Research Institute of Atomic Reactors" (JSC "SSC RIAR"). To conduct the prolonged reactor experiment, an irradiating device with an experimental capsule containing UZrCN pellets has been made, neutronic analysis and thermophysical analysis have been carried out and a programme of pre-irradiation experiments has been implemented. In June 2019 a methodical experiment was carried out in the SM-3 reactor at the JSC "SSC RIAR" in order to confirm operability of the irradiating device developed. Testing of the irradiating device and refinement of the prolonged irradiation experiment procedure were carried out at cell 11 of the reflector of the SM-3 reactor at the JSC "SSC RIAR". The period of irradiation equaled 23.3 effective days. The mean power density in the tested pellets throughout the methodical reactor testing was 516 W=cm3. Burnup achieved for the pellets studied was 0.63% FIFA. The "Giacint" and "Kristal", critical facilities of the State Scientific Institution "The Joint Institute for Power and Nuclear Research - Sosny" (the Scientific Institution "JIPNR - Sosny") will be used for studying neutronic characteristics of critical and subcritical fast assemblies simulating the physical particulars of the cores of advanced gas- or liquid metal cooled fast reactor systems and accelerator driven systems. This paper provides a detailed description of the results of preparatory works for conducting the reactor testing and the results of the methodical reactor experiment. Also the experimental programme and the descriptions of the design and composition of the fast critical assemblies with UZrCN fuel are presented.

Abstract Promoting innovation in the construction sector is one of the cornerstones of sustainability, since it is one of the main responsible for GHG emissions. This paper provides a proposal for sustainable housing: the industrialized passive home of American Building System Company (ABS) and its suitability to be incorporated into the construction system. Following the comparative analysis of the energy demands of this model versus an equivalent house which follows the regulations of the CTE. These data will be simulated by the SG SAVE software that perform the energy simulation of the both systems, based on the transmittance values of enclosures and glass and the final tightness of the homes. From these results about the savings in energy consumption, an economic analysis has been carried out and an assessment of the amortization period of the proposed house facing the other. In addition, through the calculation coefficients of equivalent CO2 emissions from the Spanish Ministry of Industry, the reduction of greenhouse gas emissions associated with energy consumption during the use stage has been obtained. Finally, for a standardize comfort conditions, the modelling and the assessment allow us to conclude that the deployment of ABS house in comparison with the conventional Spanish system supposes a reduction of 60% in energy demand, a 90% in CO2 emissions, and an amortization period of 12 years. With all these evidences we should start to think why this system has not been already integrated in the Spanish construction sector. Resumen Fomentar la innovación en el sector de la construcción es una de las piedras angulares de la sostenibilidad, pues la construcción es uno de los sectores responsables de las emisiones de GEI. Este artículo busca ofrecer una propuesta para la construcción sostenible: la vivienda pasiva industrializada de la empresa American Building System (ABS) y su idoneidad para ser incorporada como sistema constructivo tras el análisis comparativo de sus demandas energéticas frente a los de una vivienda equivalente que sigue la normativa del Código Técnico de la Edificación. Estos datos han sido obtenidos a partir del modelado energético de la vivienda a través del software SG SAVE, en función de los valores de transmitancia de cerramientos y vidrios y la estanqueidad final de la vivienda. A partir de estos resultados se ha realizado un análisis económico y se ha calculado el periodo de amortización de la vivienda propuesta frente a la del sistema convencional. Por otro lado, mediante los coeficientes de cálculo de emisiones del Ministerio de Industria Español, ha sido posible estimar la reducción emisiones de CO2 asociadas al consumo de energía durante la etapa de uso como consecuencia de la reducción de demanda energética entre ambas viviendas. Finalmente, para unas condiciones de confort normalizadas, la modelización energética y el análisis de resultados nos permiten concluir que la vivienda ABS en comparación con la vivienda del sistema convencional español nos permite reducir la demanda energética en hasta un 60%, las emisiones de CO2 en hasta un 90%, con un período de amortización de 12 años. Con todas estas evidencias de mejoría se plantea una reflexión final que es la de por qué este tipo de sistemas constructivos no están todavía integrados en el modelo constructivo español .

GOM Lease Sale Generates $121 Million in High Bids; Shell Offshore Takes Top Spot Regionwide US Gulf of Mexico (GOM) Lease Sale 256 generated $120,868,274 in high bids for 93 tracts in federal waters. The sale on 18 November featured 14,862 unleased blocks covering 121,875 square miles. With $27,877,809 spanning 21 high bids, Shell Offshore Inc. took the top spot among 23 competing companies. A total of $135,558,336 was offered in 105 bids. Among the majors, Shell, Equinor, BP, and Chevron submitted some of the highest bids. Each company claimed high bids of over $17 million, signaling the GOM remains a priority in their portfolios. Last year was a record year for American offshore oil production at 596.9 million bbl, or 15% of domestic oil production, and $5.7 billion in direct revenues to the government. Offshore oil and gas supported 275,000 total domestic jobs and $60 billion total economic contributions in the US. “The sustained presence of large deposits of hydrocarbons in these waters will continue to draw the interest of industry for decades to come,” Deputy Secretary of the Interior Kate MacGregor said. Still, as Mfon Usoro, senior research analyst at Wood Mackenzie, noted, “Although bidding activity increased by 30% from the March 2020 sale, the high bid amount of $121 million still trends below the average high bid amount seen in previous regionwide lease sales, proving that companies are still being conservative with exploration spend.” Although the Bureau of Ocean Energy Management has proposed another regionwide GOM lease sale in March 2021, Usoro predicted that Lease Sale 256 “could potentially be one of the last lease sales.” “With the Biden administration set to inaugurate next year and possibly ban future lease sales, a massive land grab might have ensued,” he continued. “But companies are constrained by tight budgets due to the prevailing low oil price. Additionally, companies in the region have existing drilling inventory to sustain them in the near term. The best blocks with the highest potential reserves are likely already leased. As a result, we do not expect a potential ban on leasing to materially impact production in the region until the end of the decade.” This was the seventh offshore sale held under the 2017–2022 National Outer Continental Shelf Oil and Gas Leasing Program; two sales a year for 10 total regionwide lease sales are scheduled for the gulf. Nine Areas on Norwegian Continental Shelf Open for Bids The 25th licensing round on the Norwegian Continental Shelf, comprising eight areas in the Barents Sea and one in the Norwegian Sea, has been announced by the Norwegian Ministry of Petroleum and Energy. Known for being a country with some of the greenest credentials and policies in the world, Norway surprised observers in June by announcing plans for a licensing round that signaled further oil exploration in the Norwegian sector of the Arctic Sea. In this round, 136 blocks/parts of blocks will be available: 11 in the Norwegian Sea and 125 in the Barents Sea. The application deadline for companies is 23 February 2021. New production licenses will be awarded in Q2 2021. Johan Sverdrup Capacity Increased to Half Million B/D Following positive results in a November capacity test, the Johan Sverdrup field is set to increase daily production capacity. Capacity will rise from today’s 470,000 to around 500,000 B/D in the second increase since the field came on stream just over a year ago. The move will increase the field’s total production capacity by around 60,000 bbl more than the original basis when the field came on line. Overall, the field is estimated to have resources of 2.7 billion BOE. “The field has low operating costs, providing revenue for the companies and Norwegian society, even in periods with low prices,” said Jez Averty, Equinor’s senior vice president for operations south in development and production, Norway. The Johan Sverdrup field uses water injection to secure high recovery of reserves and maintain production at a high level. An increase in the water-injection capacity should further increase production capacity by mid-2021, according to Rune Nedregaard, vice president for Johan Sverdrup operations. Phase 2 production starting in Q4 2022 will raise the Johan Sverdrup full-field plateau production capacity from 690,000 to around 720,000 B/D. Equinor operates the field with 42.6% stake; other partners include Lundin Norway (20%), Petoro (17.36%), Aker BP (11.57%), and Total (8.44%). ConocoPhillips Makes Significant Gas Discovery Offshore Norway ConocoPhillips announced a new natural-gas condensate discovery in production license 1009, located 22 miles northwest of the Heidrun oil and gas field and 150 miles offshore Norway in the Norwegian Sea. The wildcat well 6507/4-1 (Warka) was drilled in 1,312 ft of water to a total depth of 16,355 ft. Preliminary estimates place the size of the discovery between 50 and 190 million BOE. Further appraisals will determine potential flow rates, the reservoir’s ultimate resource recovery, and plans for development. “The Warka discovery and potential future opportunities represent very low cost-of-supply resource additions that can extend our multi-decade success on the Norwegian Continental Shelf,” said Matt Fox, executive vice president and chief operating officer. The drilling operation, which was permitted to ConocoPhillips in August 2020, was performed by the Transocean-managed Leiv Eiriksson semisubmersible rig. ConocoPhillips Skandinavia AS is the main operator of the license with a 65% working interest; PGNiG Upstream Norway AS holds the remaining stake. Lundin Energy Completes Barents Sea Exploration Well, Comes Up Dry Lundin Energy has completed exploration well 7221/4-1, targeting the Polmak prospect in licenses PL609 and PL1027, in the southern Barents Sea. The well was meant to prove hydrocarbons in Triassic-aged sandstones within the Kobbe formation of the Polmak prospect. After finding indications of hydrocarbons in a 9-m interval in poor-quality reservoir in the targeted formation, the well was classified as dry. The well was drilled 30 km east of the Johan Castberg discovery, by the Seadrill-operated West Bollsta semisubmersible rig. Lundin Energy, operator of Polmak, holds a 47.51% working interest. Partners are Wintershall DEA Norge AS (25%), Inpex Norge AS (10%), DNO Norge AS (10%), and Idemitsu Petroleum Norge AS (7.5%). Polmak is the first of Lundin’s three high-impact exploration prospects drilled this quarter in the Barents Sea; the wells target gross unrisked prospective resources of over 800 million bbl of oil. The West Bollsta rig will now proceed to drill the Lundin Energy-operated Bask prospect in PL533B. Well 7219/11-1 will target Paleocene-aged sandstones, estimated to hold gross unrisked prospective resources of 250 million bbl of oil. Tullow Sells Remaining Stake in Ugandan Oil Field Tullow Oil has completed the 10 November sale of its assets in Uganda to French giant Total for $500 million. Tullow will also receive $75 million when a final investment decision is taken on the development project, calculated to hold 1.7 billion bbl of crude oil. Contingent payments are payable after production begins if Brent crude prices rise above $62/bbl. The completion of this transaction marks Tullow’s exit from its licenses in Uganda after 16 years of operations in the Lake Albert basin. The deal is designed to strengthen Tullow’s balance sheet, as tumbling crude prices combined with exploration setbacks have created problems for the company. In September, the company reported that it had lost $1.3 billion in the first 6 months of 2020 as falling oil prices forced it to write down the value of its assets. The deal cut Tullow’s net debt to $2.4 billion; it has $1 billion in cash.

_ In a world populated by over 8 billion people and counting, the demand for energy has never been higher. Despite the push from the green energy movement advocating for renewable sources like wind and solar, the harsh reality is that these alternatives alone cannot sustain the world's voracious appetite for power—not currently or in the foreseeable future. The truth is that oil remains an indispensable and irreplaceable part of the global energy mix. According to Statista, more than 100 million bbl of oil are needed daily to meet the world's steadily rising energy requirements. From transportation and manufacturing to heating, electricity generation, and countless other vital applications, oil is the lifeblood that keeps modern civilization running smoothly. As convenient, efficient, and highly energy-dense sources, natural gas and oil are simply unmatched by any currently available alternatives. This fundamental reality is what drives me to explore and drill for new oil reserves to help secure the energy supplies that will power human progress. America’s Rising Importance in the Global Oil Equation In the global quest to locate and extract new, viable oil supplies to meet escalating demand, the US has emerged as an increasingly vital player. With its well-developed infrastructure, business-friendly policies, and decades of industry experience, America provides an attractive environment for bringing new barrels of oil online more rapidly than many other regions around the world. However, despite these advantages and increasing calls for greater domestic production, US oil companies have shown surprising restraint in substantially ramping up output, even with oil prices averaging around $90/bbl as of April 2024 before it "settled at $84/bbl on 2 May." There appears to be a concerning lack of investment and growth in American oil production at a time when the world is desperate for more supply. The Relentless Pursuit of New Oil Reserves As the CEO of an oil exploration and production company, I firmly believe that boldly pursuing new oil reserves is crucial to meeting the world's growing energy needs. It is this conviction that drives me and the rest of my team to uncover the next sources of oil to power human progress. Through strategic exploration initiatives guided by the latest geologic data, cutting-edge drilling technologies, and an unwavering determination, we are seeking out untapped oil reserves. Our goal is not only to increase production levels but also to make a meaningful contribution to US oil output and global energy security. While some industry voices chase fleeting trends or pander to mainstream narratives, our approach remains resolutely aligned with energy pioneers like Doug Sheridan, managing director and founder of EnergyPoint Research based in Houston, and Chris Wright, CEO and chairman of the board of Liberty Energy.

Every year, the unusual mix of minerals in the Hajar Mountains near the coast of Oman traps 100,000 tons of carbon in the rock. That estimate is a tiny fraction of the potential of the mountain range and a few others like it in the world. Based on decades of work by geologists studying this unique formation—known as the Samail Ophiolite—the highly reactive rocks called peridotites can theoretically trap one-half ton of CO2 per ton of that rock in the Hajar Mountains, which extend into the UAE. A leading voice among the researchers who made the 100,000-ton estimate and developed ideas for removing trillions of tons of carbon from the atmosphere is Peter Kelemen, a professor at Columbia University in New York City. In a 2019 story in Scientific American, Kelemen said that if it is possible to speed the pace of mineralization “by a factor of a million”—something he thinks is doable with a bit of engineering—“then you end up with a billion tons of CO2 per cubic kilometer of rock per year.” That potential inspired an Omani entrepreneur, Talal Hasan, to start a company based on the work of Kelemen and colleagues including Juerg Matter, a geochemist now working at the University of Southampton in England. The result was startup 44.01, named for the molecular mass of carbon, where Kelemen serves as an advisor and Matter works part time. The company’s website describes its plan: “Carbon mineralization in peridotite is happening all the time—we simply speed up the natural process.” It is a simple-sounding goal. But what it will take to realize the vast potential is anything but simple. In an interview, Kelemen identified why: “The main concern is that the rocks are not very porous.” Or very permeable, which helps explain why large amounts of highly reactive elements have remained untouched over the 96 million years these reactive minerals have been on land. The hard rocks in this formation, particularly magnesium-rich olivine, were produced when magma flowed up from the mantle to a mid-ocean ridge where it cooled and the thick layer of rock spread out toward what is now Oman and the UAE, and something extraordinary happened. When it reached the boundary between two plates, it normally would have returned to the depths of the earth. Instead, it collided with another ophioplite and was ultimately thrust up onto land. When the theory of plate tectonics transformed geological thinking during the second half of the 20th century, this giant anomaly became a destination for geologists eager to study a rare outcrop of rock from the mantle, including Kelemen. They also could have gone to New Guinea to look at a similar display of mantle rock or scattered sites in the western US, among other places, where ophiolites are present. But the Hajar Mountains comprise the biggest ophiolite of them all. Speeding carbon mineralization from geological rates to the pace needed to help stop global warming poses a fundamental problem common to unconventional oil and gas—creating flow paths in tight rock on a limited budget.

The big oil producers are balancing the chasing of more production with delivering dividends to shareholders. So far, the scale is tipping in favor of shareholders. While recent quarterly reports have made this clear, it was reemphasized at a US House Energy and Commerce Committee hearing in April when executives from Chevron, BP America, Devon Energy, ExxonMobil, Pioneer Natural Resources, and Shell USA addressed alleged “price gouging” at the gas pump and rejected pressure to shift their record profits from paying dividends and stock buybacks to ramp up production and lower prices. The executives’ statements ranged from “We can increase production and return value to our shareholders” (Chevron CEO Michael Wirth) to Devon Energy CEO Richard Muncrief and Pioneer Natural Resources CEO Scott Sheffield stating “the answer is no” when asked if they would reduce buybacks and dividends. Gretchen Watkins, Shell USA president, said her company intends to make investor returns and increase production and investments in renewable energy. Several of the executives pointed to their industry’s record losses during the pandemic when demand tanked (global fuel consumption fell by more than 25%) and West Texas Intermediate fell off a cliff to –$40/bbl on 20 April 2020 and slowly crept up. Even if the oil price drops, retail gas prices won’t immediately follow to stem the allegations of price gouging. Garrett Golding, a senior business economist at the Federal Reserve Bank of Dallas, wrote, “In the energy economics world, this phenomenon is known as ‘rockets and feathers,’ where it is commonly observed that prices at the pump shoot up with oil prices like a rocket, but fall like a feather back to the ground after oil prices drop. There are two reasons for this scenario repeating itself during oil-price spikes: the macro-level logistics of how oil and refined products churn through the physical market and the micro-level economic decisions of service station owners and their customers.” Today, demand is strong even at average oil prices of about $103/bbl over the past 6 weeks. Now, the summer driving season is around the corner and consumers are eager to hit the road and fly the skies, finally free(r) of pandemic restrictions and concerns. Yet, the Permian rig count has remained fairly flat over the same period. Despite high oil prices (WTI just below $114/bbl on 17 May), drillers aren’t ramping up activity. Many interrelated factors affect supply and demand. Simplifying the complexity of the global market shines, at best, a narrow beam on some of the factors affecting production. The supply side is dealing with volatility of oil prices; the uncertainty of Europe’s energy supplies, including Europe’s potential embargo on Russian oil; the varied focus on energy transition; sustained fiscal restraint by smaller operators as they continue to reduce or avoid debt; the shortage of sand needed for fracturing in the North American shale plays; labor shortages; the reactivation of idled equipment; and supply chain disruptions. A supply bottleneck is affecting oil country tubular goods (OCTG), which have seen volatility related to the “weak domestic demand in China due to COVID-19 lockdowns and Chinese currency depreciation,” wrote Rystad senior analyst Marina Bozkurt in a recent market note. Business activity has been affected by shutdowns and logistics problems. “OCTG prices may remain pretty high this year, driven by higher costs of raw materials due to geopolitical tensions globally and government regulations to reduce carbon emissions.” Prices continue to increase at Japanese OCTG mills, where the focus is primarily on value-added products such as 13Cr material. Propping up prices are “tight global availability and strong demand. Despite a possible price fluctuation for raw materials, prices will unlikely cool down significantly as long as the Russia-Ukraine situation continues.” In an April report, the Federal Reserve Bank of Dallas said the growing gap between OPEC+ production quotas and actual oil production is being driven by production capacity constraints in several OPEC+ countries, largely attributable to Angola, Nigeria, and Saudi Arabia. Their capacity is limited by “infrastructure issues and the difficulty of attracting sufficient investment to offset production declines at existing wells.” The shortfall was nearly 1.1 million B/D in February, the most recent month for which there were official production data available. In May, JP Morgan lowered its outlook for 2022 global oil demand by 1 million B/D, citing higher oil prices, a weakening growth outlook, and escalating geopolitical tensions. How this plays out will affect producers’ appetite to increase or decrease their production or reconsider their priorities.

As an indicator of the evolving global energy marketplace, recycled battery metals just earned their own spot pricing assessments for China and Europe. S&P Global Commodity Insights launched nine new daily “black mass” evaluations last month “to bring greater transparency to pricing of the battery raw materials market.” These complement its existing suite of daily battery metals assessments. The hunt is ongoing, and escalating, for virgin sources of metals such as lithium, manganese, cobalt, and nickel for use in lithium-ion batteries ranging from those in watches and devices to utility-scale storage, electric vehicles (EVs), and oil- and gas-related applications. In this issue of JPT, the use of oilfield technologies in deep-sea mining for these metals is highlighted. An ExxonMobil researcher, M. Stanley Whittingham, created the first examples of the rechargeable lithium-ion battery in the 1970s. He and two other researchers were awarded the 2019 Nobel Prize in Chemistry for the development of these batteries. For decades, lithium-ion batteries have been used in oil- and gas-related applications such as downhole tools related to drilling, measurement, testing, wireline, and well intervention. They can operate under extreme conditions and temperatures (from 220°C to –50°C, in the deep subsea) and are safe in potentially inflammable and explosive environments. Their long operation life and reliability are vital because of the high costs associated with downhole battery failures. More familiar to many is the use of lithium-ion batteries in EVs. The annual demand for EV batteries (in kilotonnes) is forecast to more than double from 2019 to 2030, according to the International Energy Agency’s Global EV Outlook 2020. The increased demand is due largely to their high energy density. They hold more energy in a smaller area than other types of batteries. New technologies enable the recovery and reuse of core components when these batteries reach the end of their useful lives. The battery pack can be collected, dismantled, and shredded. The shredded material is then processed to produce so-called “black mass” from which these high-value critical metals can be extracted and reused in new battery production. Although the demand is expected to mushroom, the global supply of these metals is finite. Their mining is energy- and labor-intensive. Mining the ore creates environmental effects such as land disruption and emissions; refining brine yields lower-grade lithium and recovers less of the metal present than is recovered from ore. Mining in Chile, a major lithium exporter, consumes 65% of the country’s water. In September 2022, the American Chemical Society estimated only 5% of the world’s lithium-ion batteries were recycled from the projected 8 million tons of waste. S&P Global expects recycled battery materials to make up an increasing share of the supply chain well beyond 2030. The potential availability of recycled materials would account for 30% of nickel, 27% of lithium, and 40% of cobalt demand between 2020 and 2050. Recycled metals have the potential to be cheaper than their virgin equivalents and provide supply in regions that do not have the natural resources available. In addition to reducing the need for virgin materials, recycling/reuse reduces the carbon emissions associated with new mining activities. But recycling of spent lithium-ion batteries, as a relatively nascent process, has its problems. Both physical and chemical processes are involved. Physical processes include pretreatment and recovery of electrode materials which include disassembly, crushing, screening, magnetic separation, washing, and heating treatment. Chemical processes involve leaching, separation, extraction, and chemical/electrochemical precipitation. Challenges remain to achieve the required “perfect” recovery in terms of safety, low cost, low energy consumption, and no pollution. Another challenge is to convince carmakers to use recycled materials. In an IEEE Spectrum article, Yan Wang, a professor of mechanical engineering at Worcester Polytechnic Institute, said, “Battery companies still hesitate to use recycled material in their batteries.” A study by Wang and researchers from the US Advanced Battery Consortium and A123 Systems, a battery company, concluded, “it becomes clear that recycled materials can be as good as or even better than the high-quality control materials.” As with most rapidly advancing technologies and processes, the concept must be proven, and the economics must make sense to increase widespread adoption. In the circular economy, the recycling and reuse of these high-value, limited-resource metals have the potential to be a shining star.

Hydrogen has been regarded as a promising energy carrier for renewable energy systems with net zero emissions [1]. However, the vast majority of industrial hydrogen has been produced from fossil fuels with high carbon dioxide (CO2) emissions [2]. An emerging method for hydrogen production potentially free of greenhouse gas emissions (so-called green hydrogen) is water electrolysis coupled to renewable energy sources such as wind, solar, hydropower, etc [3]. Among several water electrolysis technologies, proton exchange membrane water electrolyzers (PEMWEs) are the most promising due to several inherent advantages [4]. However, the large amount of iridium (Ir) used in current PEMWEs versus the limited amount of Ir resource on earth impedes large-scale and sustainable deployment of PEMWEs [5]. Lowering the amount of Ir used to efficiently catalyze the oxygen evolution reaction (OER) at PEMWE anodes might be achieved through the development of novel electrocatalysts. One strategy to reduce the Ir content of PEMWE anodes is to put Ir onto a support. This strategy can not only reduce the Ir content by improving Ir utilization in comparison with unsupported Ir-based electrocatalysts, but also decrease the Ir packing density [6]. Low Ir packing density is required for electrocatalyst layers with low Ir-contents to be sufficiently thick to ensure robust interfaces between the electrocatalyst layer and the porous transport layer (PTL) and membrane [7]. This strategy has two critical steps: (1) finding/developing a robust support and (2) depositing Ir onto the support with desired morphology with a method that is affordable, scalable, and manufacturable [8]. Here we report a one-step deposition of Ir onto nanoscale tungsten-doped titanium dioxide (W-TiO2) powders via sputtering. Characterization shows that Ir is deposited onto the surface of W-TiO2 (Figure 1) in the mixed form of metallic Ir and Ir oxides with particle sizes smaller than 2 nm. The catalyst exhibits an OER mass activity twice that of Ir black in acidic media. Powder conductivity measurements confirm that the electrocatalyst is electrically conductive (~24 S/cm) despite the low conductivity of the W-TiO2 powders (~1×10-4 S/cm). Our study suggests that sputtering is a feasible deposition method for large-scale production of supported Ir-based OER electrocatalysts. Acknowledgement. This study is sponsored by internal funding from Plug Power. The sputter was done at Exothermics Inc., 14 Columbia Dr, Amherst, NH 03031 References [1] Hydrogen for Net-Zero. In A critical cost-competitive energy vector. Edited by. Hydrogen Council, McKinsey & Company; 2021. [2] IEA (2021), Global Hydrogen Review 2021, IEA, Paris (available via the Internet at: https://www.iea.org/reports/global-hydrogen-review-2021) [3] Emonts, B., Müller, M., Hehemann, M., Janßen, H., Keller, R., Stähler, M., ... & Kasselmann, S. (2022). A Holistic Consideration of Megawatt Electrolysis as a Key Component of Sector Coupling. Energies, 15(10), 3656. [4] Zhang, K., Liang, X., Wang, L., Sun, K., Wang, Y., Xie, Z., ... & Zou, X. (2022). Status and perspectives of key materials for PEM electrolyzer. Nano Research Energy, 1(3), e9120032. [5] Mittelsteadt, C. (Invited) Ir Strangelove: Or How I Learned to Stop Worrying and Embrace the PEM. ECS Meeting Abstracts MA2022-01, 1335-1335 (2022). [6] Bernt, M., Hartig‐Weiß, A., Tovini, M. F., El‐Sayed, H. A., Schramm, C., Schröter, J., ... & Gasteiger, H. A. (2020). Current challenges in catalyst development for PEM water electrolyzers. Chemie Ingenieur Technik, 92(1-2), 31-39. [7] Bernt, M., Siebel, A., & Gasteiger, H. A. (2018). Analysis of voltage losses in PEM water electrolyzers with low platinum group metal loadings. Journal of The Electrochemical Society, 165(5), F305. [8] Jia, Q., Ghoshal, S., Li, J., Liang, W., Meng, G., Che, H., ... & Mukerjee, S. (2017). Metal and metal oxide interactions and their catalytic consequences for oxygen reduction reaction. Journal of the American Chemical Society, 139(23), 7893-7903. Figure 1

_ Metallica, an iconic American heavy metal band, began the European leg of its M72 World Tour in Europe on 24 May, rocking in Munich, Germany. Although their high-decibel signature guitar riffs, dynamic drumming, and fast tempos have been widely celebrated and anticipated, their tour buses have attracted their own dedicated groupies. These groupies are interested in the alternative fuels keeping the buses rolling on the 2-month, 7,200-mile journey across nine countries and include Shell, big-rig and electric vehicle manufacturers, and producers of hydrogen, biofuels, and LNG. The band’s gear will be hauled using a diverse fleet of special-edition vehicles built by Italian manufacturer Iveco. Ten Iveco S-Way heavy-duty natural gas vehicles and four S-Way trucks powered by renewable diesel will utilize Shell’s refueling network. The fleet will include a convoy for additional logistics and show support, comprising two S-eWay trucks—the first fully electric heavy-duty trucks manufactured by the company—two S-Way LNG trucks, and one more S-Way powered by renewable diesel. An S-eWay fuel-cell truck will also join the convoy for the final Spanish dates. Iveco’s sister brand, Iveco Bus, will shuttle the band’s crew on-site at the venues with eDaily minibuses and an Evadys coach. Shell’s renewable diesel, BioLNG, LNG, and FuelSave diesel will be used in the trucks. Iveco’s hydrogen fuel-cell trucks are powered by fuel-cell systems from HTWO, a hydrogen business brand of Hyundai Motor Group, and use hydrogen produced by Air Liquide. The truck manufacturer displayed its first prototype of a heavy-duty fuel-cell truck in June 2023 during the opening of Air Liquide’s hydrogen refueling station in Fos-sur-Mer (Marseille). The large-capacity high-pressure station (1 ton/day) is supplied with hydrogen through pipeline and features a fast refueling time at 700-bar pressure. The Fos-sur-Mer station is part of the HyAMMED project supported by French funding. The new station is also part of H2Haul, the European project cofinanced by the Clean Hydrogen Partnership. Air Liquide and Iveco were among the first partners of the H2Haul project when it was launched in 2019. A second high-capacity station (700 bar, 2 tons/day) dedicated to heavy vehicles will be installed in Salon-de-Provence to supply a potential fleet of 50 hydrogen Iveco trucks from 2025 as part of the R’HySE project which aims to deploy new infrastructure to distribute hydrogen sources in the south of France. Not Without Challenges Although Europe has available more alternative-fuel infrastructure than the US, Metallica’s route is experiencing some issues. The longest leg of the journey will be from Warsaw to Madrid, about 1,800 miles. Consider the following ranges of the Iveco tour trucks: EV models, 311 miles; LNG 994; and fuel cell EVs, 500. Iveco CEO Gerrit Marx said in a recent Wall Street Journal article that the lack of charging and fueling stations between venues means the battery-electric and hydrogen trucks will be mostly for promotional use at concerts. Natasha Highcroft, a director of TransAm Trucking, which provides logistics for Metallica, added, “We use alternative fuels as and when we can, as much as possible, but until the infrastructure is there, it’s very difficult.” “There is no silver bullet solution that alone will enable the whole transport industry to decarbonize. Instead, we are seeing a range of alternative fuels available and being developed, each with their own strengths and weaknesses. The key is to evaluate each and see which is the best fit,” wrote Volvo Trucks Environment and Innovation Director Lars Mårtensson on Volvo’s website. This tour fits the bill by providing a real-world example of the use of various alternative fuels on a large scale, and how far innovation and development have come. Metallica’s high profile and popularity draws attention in much of the world. Less so may be the carbon footprint associated with the metal band genre. A 2022 study by Power Play used Billboard rankings to find the most-popular touring musicians in six genres, then analyzed their 2022 tour dates to estimate their carbon emissions. The estimates considered factors such as total flight and total driving emissions (metric tons of CO2), average distance traveled per tour, and average number of shows. Metallica ranked No. 6 in the top 10 emitters in the metal genre for total flight (804 metric tons of CO2) and total driving emissions (40 metric tons of CO2). Iveco said in a statement, “Metallica will make a significant leap forward on its decarbonization journey. Environmental sustainability and social responsibility are the common ground on which the partnership between Iveco and Metallica is built.” The truck manufacturer aims to keep the buzz alive. In the latter half of the year, it will offer a limited run of 72 heavy-duty trucks with “exclusive outfitting inspired by Metallica.” References Iveco Goes Big (https://focusontransport.co.za/iveco-goes-big/), Focus on Transport and Logistics. What Is the Best Alternative Fuel for Heavy-Duty Trucks? (https://www.volvotrucks.com/en-en/news-stories/insights/articles/2024/apr/what-is-the-best-alternative-fuel-for-your-truck.html) by Lars Mårtensson, Volvo Trucks. Bands With the Biggest Carbon Footprint, Battle of the Bands: 2022 Emissions Edition (https://paylesspower.com/blog/bands-with-the-biggest-carbon-footprint/?sscid=51k8_sogkx), Payless Power.

This work proposes the design of a monitoring system for the sensing of variables in a well control system (accumulator), for which reengineering is applied to measure pressure and system level, with activation of sound and visual alarms. An accumulator is a unit used to operate hydraulically BOP (Blowout Preventer) components. The monitoring system in the proposed accumulator is based on the sensing of three variables: system pressure, manifold pressure, and annular pressure. In this project, to develop the design, an in-depth study, and analysis of the BOP system is carried out to avoid errors that affect the accumulator's physical integrity. API (American Petroleum Institute) standards are also considered. As a result, the proposed design serves as the basis for the company to take an interest in deploying electronics to the other workover equipment to make them safer and more reliable.

Purpose With increasing globalization, the importance of referring to cross-cultural contexts is also amplifying in the contemporary era. The models, framework and dimensions devoted to such situations are increasingly mannered in practice today. With due consideration derivation to the input manner, an organization’s performance is also taken aside for its increasing marginality. The following study aims to examine the American multinational oil and gas company operating in Kuwait's oil sector to evaluate the respect. The branch has a total of 600 employees, which were all included in the data collection phase. Hence, the results derived with cumulative aspects of leadership, power distance and organizational value as their impact on human resource management (HRM) functions. Design/methodology/approach Through the quantitative approach of a self-adapted questionnaire, 101 responses were collected, and through SPSS Version 22, results were discreet. Findings The results reverted with the manual that the cultural dimension of Hofstede, i.e. power distance, did not have an apparent impact on the HRM functions. Whilst leadership and organizational values had their dissolved set of effects on HRM functions of the chosen firm. However, HRM functions were apparent enough to have its impact upon leadership, power distance (PD) and organizational value accumulated. Opening to the opportunities where in the future studies, a greater extent of population as well as variables could be considered for a better impact. Research limitations/implications The Major limitation of the study is related to the number of respondents as the research was conducted solely for the chosen branch of this private oil and gas firm in Kuwait, which makes its results limited and narrowed in the analysis phase. Moreover, the methodology selection did not do justice to the resulting research’s agenda, which was restricted due to the pandemic’s situation. Where with a better and respective methodology approach, better results could be attached. Originality/value The rationale of research refers to the gap concerning theoretical aspects within a field of business. As for the resulting study, in a cross-cultural management setting, the relevancy and implication of HRM functions concerning their transparency have not been explored. Globally, in different industries, the, study of similar nature has been conducted but has not examined, the fossil fuel industry particularly, which would be the focal point of this research.

This study will identify the extent in which American oil companies make billions daily from oil production, while local Nigerians suffer daily from poverty. The focus of this research will be on the population of Niger Delta, Shell Oil Company and the Nigerian government. I will define and establish an illustration of the poverty-structured environment that surrounds Niger Delta and the revenue success of Shell Oil Company and Nigerias government. This research will open the eyes of American oil companies, Nigerias federal government and people around the world to the revenue that is coming into Nigeria, but the communities are still living in poverty. Something needs to be done; if something is not done, some the people of Niger Delta will continue to retaliate.

Background: Accidents may occur for varying reasons, including unsafe behaviors, which originate from the safety culture of the organization. Job stress and mental load may also be contributory to accidents. This study aimed to assess safety culture and its relationship with mental load and job stress in a national gas company in Iran. Methods: This is a cross-sectional study conducted over a period of one year. This study used the NASA-TLX task load index, a standard questionnaire approved by the American National Institute of Mental Health to measure job stress, and the standard Health and Safety Executive safety culture questionnaire. All personnel was counted, and the total number of employees was 122. Statistical methods of t-test, correlation coefficient, and averaging have been used. Data were collected and analyzed in SPSS software and Microsoft Excel software. Results: The average mental load of employees was 61.51, i.e., moderate level. The average job stress and employee safety culture were 180.43, i.e., high level, and 331.34, i.e., desired level. The mental load was assessed as moderate, safety culture was optimal, and job stress was high. A significant relation was found between safety culture and mental load (correlation coefficient: -0.278; p = 0.03). Besides, the mental load was significantly related to job stress (correlation coefficient=0.293; p = 0.2). Conclusion: Controlling stress and reducing the mental load in sensitive work environments is important and can lead to a higher level of safety culture in the organization.

Purpose: This article focused on the main business insights of the use of Real Options valuation analysis in the eyes of a finance professional. It used a case study of an investment opportunity in the oil and gas field services industry in Latin America to discuss the methodology implementation and its insights. As a secondary objective, it discussed the insights and options embedded in this investment opportunity.Methodology: The investment opportunity was examined using the Real Options Analysis (ROA) framework and the results compared to the traditional methodology of Net Present Value. The valuation technique was performed as if it had been applied at the time the project was approved.Findings: The most important of Real Option valuation is not the results, but how one arrives at them. After the project value is calculated and the project approved or not, the Real Option valuation requires and supports the monitoring of the project. By understanding how the options are created, managers can make better decisions about the project after it was approved.Practical implications: A relevant contribution from the study was the discussion, as a practitioner, of the methodology implementation in a real world corporation. Originality & value: The case study evaluated two types of real options: first, the effect of an option to cancel a contract that was assessed from the perspective of the client contracting the project; and second, the option to abandon and defer, from the perspective of the company that will perform the investment to provide the services. By incorporating the cost of the put option that the company puts forth for the client (cancellation option) it reduces the project value by giving flexibility to its clients.

Unconventional energy sources have become increasingly important to the global energy mix. These include coal seam gas, shale gas and shale oil. The unconventional gas industry was pioneered in the United States and embraced following the first oil shock in 1973 (Rogers). As has been the case with many global resources (Hiscock), many of the same companies that worked in the USA carried their experience in this industry to early Australian explorations. Recently the USA has secured significant energy security with the development of unconventional energy deposits such as the Marcellus shale gas and the Bakken shale oil (Dobb; McGraw). But this has not come without environmental impact, including contamination to underground water supply (Osborn, Vengosh, Warner, Jackson) and potential greenhouse gas contributions (Howarth, Santoro, Ingraffea; McKenna). The environmental impact of unconventional gas extraction has raised serious public concern about the introduction and growth of the industry in Australia. In coal rich Australia coal seam gas is currently the major source of unconventional gas. Large gas deposits have been found in prime agricultural land along eastern Australia, such as the Liverpool Plains in New South Wales and the Darling Downs in Queensland. Competing land-uses and a series of environmental incidents from the coal seam gas industry have warranted major protest from a coalition of environmentalists and farmers (Berry; McLeish). Conflict between energy companies wanting development and environmentalists warning precaution is an easy script to cast for frontline media coverage. But historical perspectives are often missing in these contemporary debates. While coal mining and natural gas have often received “boosting” historical coverage (Diamond; Wilkinson), and although historical themes of “development” and “rushes” remain predominant when observing the span of the industry (AGA; Blainey), the history of unconventional gas, particularly the history of its environmental impact, has been little studied. Few people are aware, for example, that the first shale gas exploratory well was completed in late 2010 in the Cooper Basin in Central Australia (Molan) and is considered as a “new” frontier in Australian unconventional gas. Moreover many people are unaware that the first coal seam gas wells were completed in 1976 in Queensland. The first four wells offer an important moment for reflection in light of the industry’s recent move into Central Australia. By locating and analysing the first four coal seam gas wells, this essay identifies the roots of the unconventional gas industry in Australia and explores the early environmental impact of these wells. By analysing exploration reports that have been placed online by the Queensland Department of Natural Resources and Mines through the lens of environmental history, the dominant developmental narrative of this industry can also be scrutinised. These narratives often place more significance on economic and national benefits while displacing the environmental and social impacts of the industry (Connor, Higginbotham, Freeman, Albrecht; Duus; McEachern; Trigger). This essay therefore seeks to bring an environmental insight into early unconventional gas mining in Australia. As the author, I am concerned that nearly four decades on and it seems that no one has heeded the warning gleaned from these early wells and early exploration reports, as gas exploration in Australia continues under little scrutiny. Arrival The first four unconventional gas wells in Australia appear at the beginning of the industry world-wide (Schraufnagel, McBane, and Kuuskraa; McClanahan). The wells were explored by Houston Oils and Minerals—a company that entered the Australian mining scene by sharing a mining prospect with International Australian Energy Company (Wiltshire). The International Australian Energy Company was owned by Black Giant Oil Company in the US, which in turn was owned by International Royalty and Oil Company also based in the US. The Texan oilman Robert Kanton held a sixteen percent share in the latter. Kanton had an idea that the Mimosa Syncline in the south-eastern Bowen Basin was a gas trap waiting to be exploited. To test the theory he needed capital. Kanton presented the idea to Houston Oil and Minerals which had the financial backing to take the risk. Shotover No. 1 was drilled by Houston Oil and Minerals thirty miles south-east of the coal mining town of Blackwater. By late August 1975 it was drilled to 2,717 metres, discovered to have little gas, spudded, and, after a spend of $610,000, abandoned. The data from the Shotover well showed that the porosity of the rocks in the area was not a trap, and the Mimosa Syncline was therefore downgraded as a possible hydrocarbon location. There was, however, a small amount of gas found in the coal seams (Benbow 16). The well had passed through the huge coal seams of both the Bowen and Surat basins—important basins for the future of both the coal and gas industries. Mining Concepts In 1975, while Houston Oil and Minerals was drilling the Shotover well, US Steel and the US Bureau of Mines used hydraulic fracture, a technique already used in the petroleum industry, to drill vertical surface wells to drain gas from a coal seam (Methane Drainage Taskforce 102). They were able to remove gas from the coal seam before it was mined and sold enough to make a profit. With the well data from the Shotover well in Australia compiled, Houston returned to the US to research the possibility of harvesting methane in Australia. As the company saw it, methane drainage was “a novel exploitation concept” and the methane in the Bowen Basin was an “enormous hydrocarbon resource” (Wiltshire 7). The Shotover well passed through a section of the German Creek Coal measures and this became their next target. In September 1976 the Shotover well was re-opened and plugged at 1499 meters to become Australia’s first exploratory unconventional gas well. By the end of the month the rig was released and gas production tested. At one point an employee on the drilling operation observed a gas flame “the size of a 44 gal drum” (HOMA, “Shotover # 1” 9). But apart from the brief show, no gas flowed. And yet, Houston Oil and Minerals was not deterred, as they had already taken out other leases for further prospecting (Wiltshire 4). Only a week after the Shotover well had failed, Houston moved the methane search south-east to an area five miles north of the Moura township. Houston Oil and Minerals had researched the coal exploration seismic surveys of the area that were conducted in 1969, 1972, and 1973 to choose the location. Over the next two months in late 1976, two new wells—Kinma No.1 and Carra No.1—were drilled within a mile from each other and completed as gas wells. Houston Oil and Minerals also purchased the old oil exploration well Moura No. 1 from the Queensland Government and completed it as a suspended gas well. The company must have mined the Department of Mines archive to find Moura No.1, as the previous exploration report from 1969 noted methane given off from the coal seams (Sell). By December 1976 Houston Oil and Minerals had three gas wells in the vicinity of each other and by early 1977 testing had occurred. The results were disappointing with minimal gas flow at Kinma and Carra, but Moura showed a little more promise. Here, the drillers were able to convert their Fairbanks-Morse engine driving the pump from an engine run on LPG to one run on methane produced from the well (Porter, “Moura # 1”). Drink This? Although there was not much gas to find in the test production phase, there was a lot of water. The exploration reports produced by the company are incomplete (indeed no report was available for the Shotover well), but the information available shows that a large amount of water was extracted before gas started to flow (Porter, “Carra # 1”; Porter, “Moura # 1”; Porter, “Kinma # 1”). As Porter’s reports outline, prior to gas flowing, the water produced at Carra, Kinma and Moura totalled 37,600 litres, 11,900 and 2,900 respectively. It should be noted that the method used to test the amount of water was not continuous and these amounts were not the full amount of water produced; also, upon gas coming to the surface some of the wells continued to produce water. In short, before any gas flowed at the first unconventional gas wells in Australia at least 50,000 litres of water were taken from underground. Results show that the water was not ready to drink (Mathers, “Moura # 1”; Mathers, “Appendix 1”; HOMA, “Miscellaneous Pages” 21-24). The water had total dissolved solids (minerals) well over the average set by the authorities (WHO; Apps Laboratories; NHMRC; QDAFF). The well at Kinma recorded the highest levels, almost two and a half times the unacceptable standard. On average the water from the Moura well was of reasonable standard, possibly because some water was extracted from the well when it was originally sunk in 1969; but the water from Kinma and Carra was very poor quality, not good enough for crops, stock or to be let run into creeks. The biggest issue was the sodium concentration; all wells had very high salt levels. Kinma and Carra were four and two times the maximum standard respectively. In short, there was a substantial amount of poor quality water produced from drilling and testing the three wells. Fracking Australia Hydraulic fracturing is an artificial process that can encourage more gas to flow to the surface (McGraw; Fischetti; Senate). Prior to the testing phase at the Moura field, well data was sent to the Chemical Research and Development Department at Halliburton in Oklahoma, to examine the ability to fracture the coal and shale in the Australian wells. Halliburton was the founding father of hydraulic fracture. In Oklahoma on 17 March 1949, operating under an exclusive license from Standard Oil, this company conducted the first ever hydraulic fracture of an oil well (Montgomery and Smith). To come up with a program of hydraulic fracturing for the Australian field, Halliburton went back to the laboratory. They bonded together small slabs of coal and shale similar to Australian samples, drilled one-inch holes into the sample, then pressurised the holes and completed a “hydro-frac” in miniature. “These samples were difficult to prepare,” they wrote in their report to Houston Oil and Minerals (HOMA, “Miscellaneous Pages” 10). Their program for fracturing was informed by a field of science that had been evolving since the first hydraulic fracture but had rapidly progressed since the first oil shock. Halliburton’s laboratory test had confirmed that the model of Perkins and Kern developed for widths of hydraulic fracture—in an article that defined the field—should also apply to Australian coals (Perkins and Kern). By late January 1977 Halliburton had issued Houston Oil and Minerals with a program of hydraulic fracture to use on the central Queensland wells. On the final page of their report they warned: “There are many unknowns in a vertical fracture design procedure” (HOMA, “Miscellaneous Pages” 17). In July 1977, Moura No. 1 became the first coal seam gas well hydraulically fractured in Australia. The exploration report states: “During July 1977 the well was killed with 1% KCL solution and the tubing and packer were pulled from the well … and pumping commenced” (Porter 2-3). The use of the word “kill” is interesting—potassium chloride (KCl) is the third and final drug administered in the lethal injection of humans on death row in the USA. Potassium chloride was used to minimise the effect on parts of the coal seam that were water-sensitive and was the recommended solution prior to adding other chemicals (Montgomery and Smith 28); but a word such as “kill” also implies that the well and the larger environment were alive before fracking commenced (Giblett; Trigger). Pumping recommenced after the fracturing fluid was unloaded. Initially gas supply was very good. It increased from an average estimate of 7,000 cubic feet per day to 30,000, but this only lasted two days before coal and sand started flowing back up to the surface. In effect, the cleats were propped open but the coal did not close and hold onto them which meant coal particles and sand flowed back up the pipe with diminishing amounts of gas (Walters 12). Although there were some interesting results, the program was considered a failure. In April 1978, Houston Oil and Minerals finally abandoned the methane concept. Following the failure, they reflected on the possibilities for a coal seam gas industry given the gas prices in Queensland: “Methane drainage wells appear to offer no economic potential” (Wooldridge 2). At the wells they let the tubing drop into the hole, put a fifteen foot cement plug at the top of the hole, covered it with a steel plate and by their own description restored the area to its “original state” (Wiltshire 8). Houston Oil and Minerals now turned to “conventional targets” which included coal exploration (Wiltshire 7). A Thousand Memories The first four wells show some of the critical environmental issues that were present from the outset of the industry in Australia. The process of hydraulic fracture was not just a failure, but conducted on a science that had never been tested in Australia, was ponderous at best, and by Halliburton’s own admission had “many unknowns”. There was also the role of large multinationals providing “experience” (Briody; Hiscock) and conducting these tests while having limited knowledge of the Australian landscape. Before any gas came to the surface, a large amount of water was produced that was loaded with a mixture of salt and other heavy minerals. The source of water for both the mud drilling of Carra and Kinma, as well as the hydraulic fracture job on Moura, was extracted from Kianga Creek three miles from the site (HOMA, “Carra # 1” 5; HOMA, “Kinma # 1” 5; Porter, “Moura # 1”). No location was listed for the disposal of the water from the wells, including the hydraulic fracture liquid. Considering the poor quality of water, if the water was disposed on site or let drain into a creek, this would have had significant environmental impact. Nobody has yet answered the question of where all this water went. The environmental issues of water extraction, saline water and hydraulic fracture were present at the first four wells. At the first four wells environmental concern was not a priority. The complexity of inter-company relations, as witnessed at the Shotover well, shows there was little time. The re-use of old wells, such as the Moura well, also shows that economic priorities were more important. Even if environmental information was considered important at the time, no one would have had access to it because, as handwritten notes on some of the reports show, many of the reports were “confidential” (Sell). Even though coal mines commenced filing Environmental Impact Statements in the early 1970s, there is no such documentation for gas exploration conducted by Houston Oil and Minerals. A lack of broader awareness for the surrounding environment, from floral and faunal health to the impact on habitat quality, can be gleaned when reading across all the exploration reports. Nearly four decades on and we now have thousands of wells throughout the world. Yet, the challenges of unconventional gas still persist. The implications of the environmental history of the first four wells in Australia for contemporary unconventional gas exploration and development in this country and beyond are significant. Many environmental issues were present from the beginning of the coal seam gas industry in Australia. Owning up to this history would place policy makers and regulators in a position to strengthen current regulation. The industry continues to face the same challenges today as it did at the start of development—including water extraction, hydraulic fracturing and problems associated with drilling through underground aquifers. Looking more broadly at the unconventional gas industry, shale gas has appeared as the next target for energy resources in Australia. Reflecting on the first exploratory shale gas wells drilled in Central Australia, the chief executive of the company responsible for the shale gas wells noted their deliberate decision to locate their activities in semi-desert country away from “an area of prime agricultural land” and conflict with environmentalists (quoted in Molan). Moreover, the journalist Paul Cleary recently complained about the coal seam gas industry polluting Australia’s food-bowl but concluded that the “next frontier” should be in “remote” Central Australia with shale gas (Cleary 195). It appears that preference is to move the industry to the arid centre of Australia, to the ecologically and culturally unique Lake Eyre Basin region (Robin and Smith). 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This article aims to verify the influence of people engagement on the perception of organizational management systems, according to the Job-Demands Resources model in companies in the oil and gas segment that opted to obtain certifications of their management systems through the API (American Petroleum Institute), as well as the benefits of obtaining such engagement and the barriers faced. The research has a qualitative character, and used the triangulation of techniques for obtaining and analyzing data in order to provide an attentive view of the subjective aspects, focusing on the observation of employee involvement, the adoption of good practices and critical success factors in the implementation of the Quality Management System (SGQ)[3]. During the implementation of the SGQ, some challenges were reported with the involvement of employees, need for constant support and feedback, through continuous communication and regarding employees, difficulty in concentrating and prioritizing activities, need for training, more manpower and resistance to change. However, there was a strong positive impact on all the organizations interviewed, contributing to internal improvement, increased customer satisfaction, good reputation, efficient relationship with suppliers, greater control of processes and productivity. It is expected to have contributed to the elaboration, by organizations in the sector, of new people management approaches that strengthen the employee-company relationship, as well as through the exposed questionnaire, a diagnostic mechanism that can be applied in the future by organizations.

Industrial engineering is manufacturing and service Design, analysis of operations and systems, and related to control. Past At the time, an industrial engineer was in a manufacturing plant Working and workers and machines Engaged in functional capacity. Industrial Engineers To eliminate waste in production processes Find ways. a product or service Labor, machinery, materials, information to supply, and efficient systems for integrating energy They create. Industry Engineering every year countless international attracts students. It's great engineering and Committed to business. It is provides undergraduate students with key concepts in the design, planning and optimization of manufacturing and production processes. That is the basis of a Bachelor of Industrial Engineering degree. Petroleum engineer tops our list of highest paying engineering jobs. The primary responsibility of petroleum engineers is to design and develop ways to extract the natural resources of oil and gas from the earth. Elon Musk is a South African-born American who is an Industrial Engineer with Paypal Co-founded and Space Transportation Service He founded the company Space X. He is an electric car Among the early investors in the company Tesla Was and is one company's CEO. SPSS statistics is a SOA, SHO, GWO, PSO, MVO, SCA, GSA, GA, DE. The Cronbach's Alpha Reliability The overall Cronbach's Alpha value for the model is 0.991 which Indicates 70 % reliability. From the literature review, the above 80 % Cronbach's Alpha value model can be considered for analysis.

Introduction: Air pollution from industrial sources is a growing problem increasing the amount of air pollution by emitting various gaseous pollutants such as Nitrogen Oxides (NOx). This study analyzed Nitrogen dioxide (NO2) emissions using American Meteorological Society/Environmental Protection Agency Regulatory Model (AERMOD) from the stacks and flares of a gas refinery in the Middle East. Materials and methods: The NO2 emissions were measured from the stacks and flare of the refinery (231 samples). The distribution of emissions was investigated over a statistical period of 1 year for an average time of 1 h using the AERMOD dispersion model in an area of 25×25 km2. The predicted concentrations were compared with national and international standards and are plotted for the desired zones. Results: Comparison of simulation results with national and international clean air standards showed that NO2 emission modeled in all periods of 4 seasons is higher than the standard. Examination of NO2 emission and distribution maps also showed that the maximum concentration of NO2 pollutants occurred in the central parts and the area close to the refinery. The highest maximum concentration of 1-h NO2 was 3744.3716 μg/m3 in summer in the west and south of the refinery. Validation results also showed a high correlation between the predicted and actual results. Conclusion: The power of resources in emission and distribution, topographic conditions, and meteorological characteristics of the region are three important and influential factors in the distribution of NO2 pollutants. So pollution reduction strategies are needed due to the different types of use, surrounding residential areas, personnel, and people involved in the gas refining company.

ABSTRACT Purpose: This research aims to identify the probability of default of infrastructure companies considering the sector specificities of their activities. In addition, the work seeks to identify the application of structural variables of probability of default in a model in a reduced way in order to identify the significance of its use. For this purpose, we investigated 1,520 North American companies from six different sectors linked to infrastructure. Originality/value: The analyzes carried out to identify the probability of a company going bankrupt hardly consider its sectorial particularity. Although most models bring important inputs for risk assessment, most of them do not consider this sectoral view. Then, this work has as value and originality the contribution to fill this gap and identify the existence of sectorial differences in the analysis of default risk in infrastructure companies in the North American market in the period between 2006 and 2018. Design/methodology/approach: The study performed a logistic regression (logit model) using 11 model variables established in calculating the probability of default. It also used the variable distance to default as an explanatory variable in order to identify its ability to explain the researched phenomenon. Findings: The study identified that, in addition to the size of the companies, the distance to default variable is the only variable that can be applied with significance in all the analyzed sectors. In addition, it was identified that companies in the oil and gas sector have less sensitivity to this variable than companies in the other sectors.

Sustainable development is an extremely important area of activity for all businesses - the environmental component. This means that along with the main goal of any business - to make a profit while meeting the needs of the consumer - entrepreneurs must pay attention to the environmental consequences of their production activities. Of great importance for solving the problems of environmental safety, ensuring sustainable development is the preparation of production, which would guarantee the maximum effect from the introduction of innovative technologies and products, at least at a certain level of technological excellence. Such issues are already being developed and implemented in European and North American countries. In Ukraine, on the other hand, these aspects are still insufficiently studied and require both environmental and economic justification. The article is devoted to the study of the basic principles of the formation of sustainable development projects in enterprises, the establishment of cooperation between economic entities and financial institutions in order to ensure the effective achievement of the goals of the strategy of sustainable transformation of the state. The object of research in the article is the substantiation of methodological and applied recommendations for the creation of a special intermediary fund between enterprises and financial institutions for scientific, technological and environmental preparation of production (STEPP). Each enterprise that conducts work on the development of innovative projects, and therefore organizes the preparation of production, should form an appropriate fund for STEPP, which should be responsible for the quality of projects of product designs and production schemes that will ensure environmental safety of the enterprise. Such a fund, created directly at the production plant, would be an accumulator of funds received for the development of technologies, taking into account the requirements of sustainable development. Accordingly, such a fund should act on behalf of the company with the initiative to obtain the necessary credit resources and enter into relations with commercial banks or credit unions. Employees of the fund should cooperate with credit institutions in order to obtain the necessary loans. Research methods: dialectical method and methods of analysis and synthesis - to study the features of the implementation of innovative works at the stage of scientific, technological and environmental preparation of production in the formation of sustainable development projects; structural and logical analysis - development of theoretical and methodological principles of the fund to ensure cooperation in financing sustainable development projects. The article proposes the formation of the stage of scientific-technological-environmental preparation of production for enterprises that are working on the development of innovative projects. The environmental component should be added to the development of structures and technologies in the technical and economic aspect.

Cement is a major component in oil and gas drilling operations that is used to maintain the integrity of boreholes by preventing the movement of formation fluids through the annular space and outside the casing. In 2019, Iraq National Oil Company ordered all international oil and gas companies which are working in Iraq to use Iraqi cement (made in Iraq) in all Iraqi oil fields; however, the X-ray fluorescence (XRF) and compressive strength results in this study show that this cement is not matching with American Petroleum Institute (API) standards. During this study, barolift was used to improve the properties of Iraqi cement used in oil wells at high pressure and high temperature (HPHT). Barolift (1 g) was added to cement admixture to evaluate its influence on improving the performance of cement, mainly related to the property of toughness. Primarily, the quality and quantity of cement contents were determined using X-ray fluorescence. Experiments were conducted to examine the characteristics of the base cement and the cement system containing 1g of barolift, such as thickening time, free water, compressive strength, and porosity. X-ray diffraction (XRD), scanning electron microscope (SEM), and energy dispersive X-ray spectroscopy (EDS) were conducted for analyzing the microstructure of cement powder. The experimental results showed that barolift acted as a retarder and improved the thickening time, slightly increased the free water, enhanced the mechanical properties, reduced the porosity, and aided in scheming new cement slurry to withstand the HPHT conditions. Microstructure analysis showed that barolift particles blocked the capillaries by filling cement spaces and, thus, a denser and stricter cement network was achieved.

Purpose: The airline industry is one of the important sectors in all aspects of human life. The word ‘Aviation’ means the flying vehicles that come under airplanes, helicopters, and unmanned aircraft such as drones, UAVS, etc. This industry is mainly classified into two types, Airlines and Aviation industry. An Airlines business offers air travelling services for people or cargo, whereas the aviation industry is based on the working of defence systems, manufacturing, and training-based things. The modern airline industry is very important because of its globalized nature, helping to connect all continents, countries, and cultures. The aviation industry is a major backbone of every country's annual economy. Every country's international airports are major hubs for overseas trading around the world. It gives direction to a country's international competitiveness and global investments in tourism, IT, and infrastructure. The largest aircraft manufacturing companies in the airline sector are European player Airbus and US-based Boeing. Many airline companies work in national and international sectors, based on annual revenue the leading companies are American airlines, Delta airlines, Southwest airlines, China southern airlines, Ryanair airlines, KLN royal airlines, Turkish airlines, etc. IBS software is a leading provider of new-generation IT products in the logistics, transportation, and travel industry. The ultimate aim of IBS is to offer their clients maximum efficiency, improve revenue, increase safety, analyse growth and reduce total cost. Their service delivery area included the oil & gas sector, airport management, cruise lines, and tour operators. IBS software is a CMM Level 5 certified airline software development company having offices in America, Europe, Japan, the Middle East, Asia, Australia, and Africa. Objective: IBS Software Pvt Ltd, a SaaS -related aviation software development company located in Techno Park, Trivandrum, Kerala is the subject of the company analysis case study. Design/Methodology/Approach: The pertinent data and specifics for this case study on IBS came from product papers that were released in a variety of peer-reviewed journals, conferences, and business websites. Additional details have been given in white papers. Findings/Result: The study of this paper focuses on the company's products and services, Business strategy with their Partners and Alliances, Recruitment and training strategy of IBS Software, Corporate social responsibility, and analysis based on SWOT. Originality Value: The study provides a brief overview of IBS Software Private Limited products & services, In-depth knowledge about flight and staff application, flight repair solutions, customer convocation, License agencies, employee transit, and payload administrations. Type of Paper: Case Study.