Relevant bibliographies by topics / Natural hydrogen exploration and production

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Academic literature on the topic 'Natural hydrogen exploration and production'

Author: Grafiati
Published: 25 May 2024

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Journal articles on the topic "Natural hydrogen exploration and production"

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Frery, Emanuelle, Laurent Langhi, and Jelena Markov. "Natural hydrogen exploration in Australia – state of knowledge and presentation of a case study." APPEA Journal 62, no. 1 (May 13, 2022): 223–34. http://dx.doi.org/10.1071/aj21171.

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Hydrogen will play a major role in Australia’s transition to a net zero emissions energy future. The hydrogen industry and technology are scaling up with hydrogen produced via two pathways, thermochemical and electrochemical, that involve the use of fossil fuel feedstock or the use of an electrical current to split water into hydrogen and oxygen. Exploration for and production of natural hydrogen is one of the most promising ways to get large quantities of green hydrogen cheaper than the ‘blue’ hydrogen produced from methane. Some predictions from this growing industry even estimate that the production of natural hydrogen can quickly become economically viable. We propose to review the state of knowledge of natural hydrogen exploration and production in the world and focus on the exploration of the Australian natural seeps in the frame of the incredible exploration rush we are currently experiencing. Surface emanations often referred to as ‘fairy circles’ are often associated with high hydrogen soil-gas measurement and have been described in numerous countries. In the frame of our research, we recently showed that similar hyrdrogen-emitting structures are present in Australia. New regional scale soil-gas measurements reveal persistent hydrogen concentration along the Darling Fault, in the Perth Basin and on the Yilgarn Craton. Those geological settings promote processes such as deep serpentinisation of ultramafic rocks as potential hydrogen sources that are of massive potential economic value. We review the results of different techniques to explore and quantify the presence of natural hydrogen leakage.
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Wang, Lu, Zhijun Jin, Xiao Chen, Yutong Su, and Xiaowei Huang. "The Origin and Occurrence of Natural Hydrogen." Energies 16, no. 5 (March 2, 2023): 2400. http://dx.doi.org/10.3390/en16052400.

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Hydrogen is an attractive, clean, sustainable energy source primarily produced via industry. At present, most reviews on hydrogen mainly focus on the preparation and storage of hydrogen, while the development and utilization of natural hydrogen will greatly reduce its cost. Natural hydrogen has been discovered in many geological environments. Therefore, based on extensive literature research, in this study, the distribution and sources of natural hydrogen were systematically sorted, and the identification method and occurrence state of natural hydrogen were examined and summarized. The results of this research show that hydrogen has been discovered in oceanic spreading centers, transform faults, passive margins, convergent margins, and intraplate settings. The primary sources of the hydrogen include alterations in Fe(II)-containing rocks, the radiolysis of water, degassed magma, and the reaction of water- and silica-containing rocks during the mechanical fracturing. Hydrogen can appear in free gas, it can be adsorbed and trapped in inclusions. Currently, natural hydrogen exploration is in its infancy. This systematic review helps to understand the origin, distribution, and occurrence pattern of natural hydrogen. In addition, it facilitates the exploration and development of natural hydrogen deposits, thus enabling the production of low-cost hydrogen.
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Joseph, Aimikhe, Victor, and Eyankware, Emmanuel Oghenegare. "Recent Advances in White Hydrogen Exploration and Production: A Mini Review." Journal of Energy Research and Reviews 13, no. 4 (April 24, 2023): 64–79. http://dx.doi.org/10.9734/jenrr/2023/v13i4272.

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The quest for natural or white hydrogen exploration and production emanates from the growing interest in clean, carbon-free hydrogen energy. Countries all over the world are beginning to formulate legislation to promote hydrogen production as a way of combating global warming occasioned by climate change. Currently, all avenues for producing hydrogen are either very expensive or environmentally unsustainable. White hydrogen in commercial accumulations might produce cheaper and more environmentally sustainable hydrogen energy, thus providing a viable alternative to other forms of renewable energy. Despite its potential to become the cheapest hydrogen source, published literature on its occurrence, sources, accumulation, generation processes, and recovery methods are scarce. Consequently, little is known regarding white hydrogen sources, accumulation, and extraction. This study reviewed the various sources and forms in which white hydrogen can exist in nature. The various processes by which white hydrogen is produced and extracted have also been presented. This work aimed to offer new perspectives and direction for future research on white hydrogen exploration and production. Furthermore, the current challenges of white hydrogen exploration and production, and its future outlook, were also presented.
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Baxter, Clare, Frank La Pedalina, Andrew McMahon, and Toon Hoong Lim. "Early exploration modelling of natural hydrogen systems through the use of existing open source data." Australian Energy Producers Journal 64, no. 2 (May 16, 2024): S320—S324. http://dx.doi.org/10.1071/ep23210.

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Natural hydrogen’s viability as a sustainable energy source will be enhanced through comprehensive geological modelling. This paper integrates existing open-source data to delve into the geological aspects of natural hydrogen exploration and proposes possible workflows. Geological and geophysical modelling entails characterising subsurface formations conducive to natural hydrogen generation and trapping. Utilising geological surveys, field observation, geophysical seismic and gravity data, alongside existing well logs, this analysis looks to identify regions with favourable geological conditions for the generation, migration and structures for accumulation of natural hydrogen. Furthermore, understanding the subsurface geology aids in the development of safe and efficient extraction techniques. By incorporating geological modelling into the evaluation of natural hydrogen, this paper provides a comprehensive overview of its potential as a sustainable energy solution. Leveraging existing open-source data alongside geological insights ensures a robust foundation for decision-making in exploration, production, storage, and utilisation strategies. This integrated approach empowers stakeholders to make informed choices in shaping a greener, more sustainable energy landscape.
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Gondal, Irfan Ahmad. "Offshore renewable energy resources and their potential in a green hydrogen supply chain through power-to-gas." Sustainable Energy & Fuels 3, no. 6 (2019): 1468–89. http://dx.doi.org/10.1039/c8se00544c.

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Offshore renewable energies are proposed to generate green hydrogen through PEM electrolysis. Power-to-gas process can be used to store hydrogen gas in synergy with existing oil/gas exploration companies. Offshore CCS is thereafter used to assist in the production of synthetic natural gas entirely offshore.
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Boreham, Christopher J., Dianne S. Edwards, Krystian Czado, Nadege Rollet, Liuqi Wang, Simon van der Wielen, David Champion, Richard Blewett, Andrew Feitz, and Paul A. Henson. "Hydrogen in Australian natural gas: occurrences, sources and resources." APPEA Journal 61, no. 1 (2021): 163. http://dx.doi.org/10.1071/aj20044.

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Natural or native molecular hydrogen (H2) can be a major component in natural gas, and yet its role in the global energy sector’s usage as a clean energy carrier is not normally considered. Here, we update the scarce reporting of hydrogen in Australian natural gas with new compositional and isotopic analyses of H2 undertaken at Geoscience Australia. The dataset involves ~1000 natural gas samples from 470 wells in both sedimentary and non-sedimentary basins with reservoir rocks ranging in age from the Neoarchean to Cenozoic. Pathways to H2 formation can involve either organic matter intermediates and its association with biogenic natural gas or chemical synthesis and its presence in abiogenic natural gas. The latter reaction pathway generally leads to H2-rich (>10mol% H2) gas in non-sedimentary rocks. Abiogenic H2 petroleum systems are described within concepts of source–migration–reservoir–seal but exploration approaches are different to biogenic natural gas. Rates of abiogenic H2 generation are governed by the availability of specific rock types and different mineral catalysts, and through chemical reactions and radiolysis of accessible water. Hydrogen can be differently trapped compared to hydrocarbon gases; for example, pore space can be created in fractured basement during abiogenic reactions, and clay minerals and evaporites can act as effective adsorbents, traps and seals. Underground storage of H2 within evaporites (specifically halite) and in depleted petroleum reservoirs will also have a role to play in the commercial exploitation of H2. Estimated H2 production rates mainly from water radiolysis in mafic–ultramafic and granitic rocks and serpentinisation of ultramafic–mafic rocks gives a H2 inferred resource potential between ~1.6 and ~58MMm3 year−1 for onshore Australia down to a depth of 1km. The prediction and subsequent identification of subsurface H2 that can be exploited remains enigmatic and awaits robust exploration guidelines and targeted drilling for proof of concept.
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Deronzier, Jean-François, and Hélène Giouse. "Vaux-en-Bugey (Ain, France): the first gas field produced in France, providing learning lessons for natural hydrogen in the sub-surface?" BSGF - Earth Sciences Bulletin 191 (2020): 7. http://dx.doi.org/10.1051/bsgf/2020005.

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The former Vaux-en-Bugey field, first French methane production from early 20th century, is revisited as a case study to address the present generation and accumulation theories for gases like hydrogen and helium. The volume of the initial gas in place is estimated to be 22 million m3. Based on a composition of 5% of hydrogen and 0.096% of helium, the volumes of these gases in the field were respectively around 1.1 million m3 for hydrogen and 24 000 m3 for helium. The different hypotheses of hydrogen sources are reviewed: serpentinization, hydro-oxidation of siderite, water radiolysis, bio-fermentation, mechanical generation, degassing from depth trough faults, steel corrosion. For helium generation, the different sources of radioactive minerals and intermediate accumulations are examined. The most probable scenario is the hydrogen production by water radiolysis and helium production by radioactive decay in or near the basement, migrating trough deep faults, stored and concentrating in an aquifer with thermogenic methane, then flushed by methane into the gas field, during Jura thrusting. New measurements with portable gas detector, incomplete but including hydrogen, on a former exploration well with accessible flux of gas, give the opportunity to comment gas saturation evolution more than a century after the 1906 discovery. The decreasing of hydrogen content since the discovery of the field is probably due to Sulphate-Reducing Bacteria activity.
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Boschee, Pam. "Comments: The New “Gold Rush” Hunts for Subsurface Hydrogen." Journal of Petroleum Technology 75, no. 11 (November 1, 2023): 10–11. http://dx.doi.org/10.2118/1123-0010-jpt.

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_ A gold strike was announced in late October. But in this case the gold was naturally occurring hydrogen in a former coal basin. Known as “white” or “gold” hydrogen, the reported discovery of naturally formed underground hydrogen was made in northeastern France’s Lorraine coal basin, a region between France and Germany. The last coal mine was shut down 20 years ago. Researchers at the French National Centre of Scientific Research (CNRS) were testing a probe designed to analyze gases dissolved in the water of deep underground rock formations, looking for methane, when they detected hydrogen concentrations at depths of 1100 m (14%) and 1250 m (20%). Their calculations estimated the deposits’ potential as between 6 and 250 million metric tons of hydrogen. This wasn’t their first discovery of underground hydrogen in the area. Philippe de Donato and Jacques Pironon made a similar finding “by chance” as part of the Regalor research project in collaboration with Française de l’Energie (FDE), an independent multienergy company, the University of Lorraine, and CNRS. FDE announced the discovery in a press release in May, saying the measurements of hydrogen were made in its previously drilled Folschviller wellsite in the carboniferous aquifer of the Lorraine basin. Launched in 2018, the project’s aim was to confirm an assessment carried out in 2012 by France’s IFPEN petroleum and new energies institute. After analyzing a sample of the soil under the basin, the institute concluded that it contained 370 billion m3 of methane, which represents 8 years of gas consumption in France. De Donato and Pironon said, “The work carried out within the framework of the Regalor project has made it possible to demonstrate that the fluids within the carboniferous formations of the Lorraine mining basin are very significantly enriched in hydrogen, with a measured concentration of 15% at 1093 m depth and estimated at 98% at 3000 m depth.” FDE said in May that it applied for an exclusive mining exploration permit for the exploration of natural hydrogen in the basin. The permit covers an area of 2254 km² in the Grand Est region. The company said a site for a pilot will be identified based on the results obtained and then built to initiate local production and recovery of natural hydrogen in the Grand Est Region. In its October investor update, FDE said measurements will be performed in three of its existing wells by the end of the year to determine the extent of the hydrogen deposit. Reservoirs have also been discovered in the US, Canada, Finland, the Philippines, Australia, Brazil, Oman, Turkey, and Mali. In Mali, the Bourakebougou water well, Bougou-1, was drilled in 1987 in the Taoudeni Basin (https://doi.org/10.1016/j.ijhydene.2018.08.193), a large sedimentary system present mainly in Algeria, Mauritania, and Mali. The well was cemented after a gas explosion occurred during drilling operations at a measured depth of 112 m. Unplugged in 2011 for use as a pilot well for local hydrogen production, gas was reported comprising 98% hydrogen, 1% nitrogen, and 1% methane. Hydrogen was then produced as an energy resource to supply local electricity through a company named Petroma, renamed Hydroma. From 2017 to 2019, the company drilled 24 wells. Among the new breed of gold prospectors are several startup companies including Natural Hydrogen Energy, Koloma, Helios Aragon, Gold Hydrogen, HyTerra, and H2Au. Helios Aragon owns exploration permits in northern Spain’s Aragon region and will begin drilling the Monzon-2 appraisal well in 2024 at a cost of $12 million. Estimates for the well are 1.1 million tons of hydrogen, and the company claims the Monzon field holds 5 to 10 million tons within its permits and more than 100 million tons in the region. Natural Hydrogen Energy and HyTerra claim the “first wildcat well targeting natural hydrogen in Nebraska,” the Hoarty well at Project Geneva. HyTerra also holds leases in the Nemaha Ridge in Kansas. The cost advantages of subsurface hydrogen are frequently cited by the early prospectors. For example, the wells in Mali have the potential to generate hydrogen gas at a cost of 50 cents/kg (https://doi.org/10.1016/j.ijhydene.2018.08.193), which is only one-tenth the cost of producing hydrogen via electrolysis using solar, wind, geothermal, or other renewable energy sources. If commercialization and economies of scale pan out, this may become the gold standard for hydrogen energy. For Further Reading The Curious Case of Geologic Hydrogen: Assessing its Potential as a Near-Term Clean Energy Source (https://doi.org/10.1016/j.joule.2022.01.005) by E.M. Yedinak, US Department of Energy, Advanced Research Projects Agency-Energy. The Occurrence and Geoscience of Natural Hydrogen: A Comprehensive Review (https://doi.org/10.1016/j.earscirev.2020.103140) by V. Zgonnik, Natural Hydrogen Energy LLC.
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Carrillo Ramirez, Alejandra, Felipe Gonzalez Penagos, German Rodriguez, and Isabelle Moretti. "Natural H2 Emissions in Colombian Ophiolites: First Findings." Geosciences 13, no. 12 (November 22, 2023): 358. http://dx.doi.org/10.3390/geosciences13120358.

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The exploration of natural H2 or white hydrogen has started in various geological settings. Ophiolitic nappes are already recognized as one of the promising contexts. In South America, the only data available so far concerns the Archean iron-rich rocks of the Mina Gerais in Brazil or the subduction context of Bolivia. In Colombia, despite government efforts to promote white hydrogen, data remain limited. This article introduces the initial dataset obtained through soil gas sampling within the Cauca-Patia Valley and Western Cordillera, where the underlying geology comprises accreted oceanic lithosphere. In this valley, promising areas with H2 potential were identified using remote sensing tools, in particular vegetation anomalies. The Atmospherically Resistant Vegetation Index (ARVI) appears to be well adapted for this context and the field data collection confirmed the presence of H2 in the soil in all pre-selected structures. The valley undergoes extensive cultivation, mainly for sugar cane production. While H2 emissions lead to alterations in vegetation, unlike reports from other countries, they do not result in its complete disappearance. Soil gas measurements along the thrusts bordering the Cauca Valley also show high H2 content in the fault zones. In the valley, the presence of sedimentary cover above the ophiolites which are presumably the H2 generating rocks, which addresses the possible presence of reservoirs and seals to define potential plays. Drawing parallels with the Malian case, it could be that the intrusive element could serve as seals.
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Kernen, Rachelle, Kathryn J. Amos, Ingrid Anell, Sian Evans, and Leticia Rodriguez-Blanco. "The role of salt basins in the race to net zero: a focus on Australian basins and key research topics." Australian Energy Producers Journal 64, no. 2 (May 16, 2024): S402—S406. http://dx.doi.org/10.1071/ep23213.

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Globally, many salt basins host highly productive fossil fuel resources and provide excellent opportunities for developing economically viable clean energy systems such as (1) energy storage in salt caverns, including hydrogen, helium, natural gas, and other economic gases; (2) permanent sequestration of carbon dioxide; (3) development of geothermal energy; (4) critical mineral exploration and extraction, and (5) natural hydrogen production. Despite the high potential to deploy financially viable clean energy solutions related to the formation and evolution of salt basins, our current knowledge regarding critical aspects of salt basin characterisation in Australia is limited. New research is necessary to develop these sustainable energy systems and achieve net zero emissions; therefore, it is critical to re-evaluate the geology of salt basins. Key research areas to enable these opportunities relate to the precipitation, deposition, and deformation of salt basins. This paper reviews the potential for a range of energy systems within salt basins, outlines emerging research topics, and demonstrates the value of Australian salt basin outcrop analogues for improved subsurface interpretation globally.
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Dissertations / Theses on the topic "Natural hydrogen exploration and production"

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Maiga, Omar. "Caractérisation géologique et géophysique 3D d’un système de réservoirs d’hydrogène naturel : exemple du champ de Bourakèbougou, Mali." Electronic Thesis or Diss., Sorbonne université, 2023. https://accesdistant.sorbonne-universite.fr/login?url=https://theses-intra.sorbonne-universite.fr/2023SORUS647.pdf.

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Dans la course pour trouver des moyens de production d'hydrogène propre et bon marché, les puits d'hydrogène naturel de Bourakèbougou offrent une solution prometteuse. Non seulement l'un d'entre eux a pu être exploité avec succès pour produire de l'électricité pour le village local, mais ses vingt-quatre puits actuels offrent également une occasion unique aux géo-scientifiques de déterminer les caractéristiques des réservoirs d'hydrogène naturel, la nature des roches couvertures et les différents processus qui interviennent dans son accumulation, migration et piégeage dans les roches. Ce travail de recherche présente les études de carottage, diagraphie, géophysique et géochimie qui ont été réalisées pour mieux caractériser la nature des réservoirs d’H2 de Bourakèbougou. L’étude de la géologie régionale et de l’ensemble de la zone sur la base de l’interprétation des données de forages et des données bibliographiques a dans un premier temps été réalisée. Cela a permis de fournir une nouvelle carte géologique de la zone ainsi qu’une coupe Nord-Sud de l’ensemble du bassin. L’analyse des faciès ainsi que les données de forages ont permis de montrer qu’il existait une corrélation entre les puits stratigraphiques F1 et F2 forés en 2011 à 100 km au nord de Bourakèbougou et les puits dans la zone d’étude située plus au sud. Une structure antiforme a également été identifiée autour de Bourakèbougou. L’ensemble de ces données ont permis de valider et de fournir un modèle sédimentaire cohérent de l’ensemble de la zone. Afin d’améliorer le cadre géochronologique entre les différents événements de la zone et caractériser la succession chronologique entre les sédiments et les intrusions, des datations U/Pb ont été réalisées sur les carbonates sur Bougou-6, le puits le plus profond, et sur le puits F2. Les âges obtenus sur certains carbonates ont été largement influencés par l’intrusion de méga-sills de dolérites entre 150 et 210 Ma. Ceci est confirmé par la datation de veines issues des carbonates du réservoir principal de Bougou-6 et du puits F2. Les veines datées, notamment celle dans le réservoir principal contenant de l’H2 (Bougou-6) a donné un âge d’environ 210 Ma, ce qui correspond à la période de magmatisme dit de la Central Atlantic Magmatic Province (CAMP). Seule la datation d’un carbonate situé à 890m a donné un âge manifestement synchrone du dépôt (620 ±100 Ma). Cet âge a permis de confirmer l’âge néoprotérozoïque des sédiments et d’établir un lien avec l’événement glaciaire néoprotérozoïque survenu entre 635-710 Ma (Sturtien + Marinoen). Les analyses de carottes, imageries de puits, diagraphie, rock Eval et calcimétrie ont permis de mettre en évidence que les carbonates supérieurs dans lesquels le maximum d’H2 est accumulé correspondent majoritairement à des carbonates dolomitiques de type cap carbonates, et que l’ensemble des accumulation d’H2 se trouvaient dans des cavités karstiques (thermo-karst). Différents faciès classiques du Néoprotérozoïque ont été identifiés le long de la série, notamment des stromatolithes, des microbialites, et des diamictites. Les roches situées au-dessus du réservoir principal qui font office de couverture, principalement une dolérite, ont été caractérisées afin de savoir quel rôle elles jouaient dans le piégeage de l’H2. Non seulement les dolérites jouent un rôle important dans le piégeage par leur épaisseur cumulée, mais, plus en profondeur, la présence d’aquifères pouvait également atténuer la migration de l’H2 en le ralentissant dans sa migration vers la surface. Les analyses diagraphiques couplées aux données de production ont permis de mettre en évidence que le système hydrogène est un système dynamique qui se recharge de manière spontanée pendant la production, contrairement aux systèmes de réservoir de pétrole et de gaz. Enfin, l’analyse des données géophysiques a permis d’apporter une compréhension sur la structure globale de la zone et la signature géophysique de la phase gaz
In the race to find clean and inexpensive ways to produce hydrogen, the natural hydrogen wells of Bourakèbougou offer a promising solution. Not only has one of them been successfully exploited to generate electricity for the local village, but its current twenty-four wells also provide a unique opportunity for geoscientists to determine the key characteristics of natural hydrogen reservoirs, the nature of the cap rocks, and the various processes involved in its accumulation, migration, and trapping in the rocks. This scientific research presents core, logging, geophysical, and geochemical studies that have been conducted to better characterize the nature of Bourakèbougou's H2 reservoirs. The study of regional geology and the entire area based on drilling data interpretation and bibliographic information was initially carried out. This resulted in a new geological map of the area and a North-South cross-section of the entire basin. Facies analysis and drilling data showed a correlation between stratigraphic wells F1 and F2 drilled in 2011, 100 km north of Bourakèbougou, and the wells in the study area located further to the south. An antiform structure was also identified around Bourakèbougou. All of these data helped validate and provide a coherent sedimentary model for the entire area. To improve the geochronological framework between different events in the area and to characterize the chronological sequence between sediments and intrusions, U/Pb dating was performed on carbonates from Bougou-6, the deepest well, and well F2. The ages obtained for some carbonates were largely influenced by the intrusion of mega-sills of dolerites between 150 and 210 million years ago (Ma). This was confirmed through dating veins derived from the carbonates of the main Bougou-6 reservoir and well F2. The dated veins, especially the one in the main reservoir containing H2, provided an age of approximately 210 Ma, corresponding to the period of magmatism known as the Central Atlantic Magmatic Province (CAMP). Only the dating of a carbonate located at 890m yielded an age that was clearly synchronous with the deposition (620 ± 100 Ma). This age confirmed the Neoproterozoic age of the sediments and established a connection with the Neoproterozoic glaciation event that occurred between 635-710 Ma (Sturtian + Marinoan). Core analyses, well imaging, logging, Rock Eval, and calcimetry revealed that the upper carbonates in which the highest amount of H2 is accumulated mainly consist of dolomitic cap carbonates, and all H2 accumulations are found in karstic cavities (thermokarst). Different Neoproterozoic facies were identified along the sequence, including stromatolites, microbialites, sandstones, and diamictites. The rocks located above the main reservoir, primarily dolerite, were characterized to understand their role in trapping H2. It was found that not only do the dolerites play a significant role in trapping due to their cumulative thickness, but the presence of aquifers can also attenuate H2 migration by slowing it down in its migration towards the surface. The diagraphic analyses, coupled with production data, have revealed that the hydrogen system is a dynamic system that is spontaneously recharged in H2-rich gas at the production timescale, unlike oil and gas reservoir systems. Finally, the analysis of geophysical data provided an understanding of the overall structure of the area and the gas phase geophysical signature
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McGlocklin, Kristin Hew Eden Mario R. "Economic analysis of various reforming techniques and fuel sources for hydrogen production." Auburn, Ala., 2006. http://repo.lib.auburn.edu/2006%20Fall/Theses/MCGLOCKLIN_KRISTIN_35.pdf.

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Appressi, Lorenzo. "Biogas and bio-hydrogen: production and uses. A review." Master's thesis, Alma Mater Studiorum - Università di Bologna, 2015. http://amslaurea.unibo.it/9071/.

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The first part of this essay aims at investigating the already available and promising technologies for the biogas and bio-hydrogen production from anaerobic digestion of different organic substrates. One strives to show all the peculiarities of this complicate process, such as continuity, number of stages, moisture, biomass preservation and rate of feeding. The main outcome of this part is the awareness of the huge amount of reactor configurations, each of which suitable for a few types of substrate and circumstance. Among the most remarkable results, one may consider first of all the wet continuous stirred tank reactors (CSTR), right to face the high waste production rate in urbanised and industrialised areas. Then, there is the up-flow anaerobic sludge blanket reactor (UASB), aimed at the biomass preservation in case of highly heterogeneous feedstock, which can also be treated in a wise co-digestion scheme. On the other hand, smaller and scattered rural realities can be served by either wet low-rate digesters for homogeneous agricultural by-products (e.g. fixed-dome) or the cheap dry batch reactors for lignocellulose waste and energy crops (e.g. hybrid batch-UASB). The biological and technical aspects raised during the first chapters are later supported with bibliographic research on the important and multifarious large-scale applications the products of the anaerobic digestion may have. After the upgrading techniques, particular care was devoted to their importance as biofuels, highlighting a further and more flexible solution consisting in the reforming to syngas. Then, one shows the electricity generation and the associated heat conversion, stressing on the high potential of fuel cells (FC) as electricity converters. Last but not least, both the use as vehicle fuel and the injection into the gas pipes are considered as promising applications. The consideration of the still important issues of the bio-hydrogen management (e.g. storage and delivery) may lead to the conclusion that it would be far more challenging to implement than bio-methane, which can potentially “inherit” the assets of the similar fossil natural gas. Thanks to the gathered knowledge, one devotes a chapter to the energetic and financial study of a hybrid power system supplied by biogas and made of different pieces of equipment (natural gas thermocatalitic unit, molten carbonate fuel cell and combined-cycle gas turbine structure). A parallel analysis on a bio-methane-fed CCGT system is carried out in order to compare the two solutions. Both studies show that the apparent inconvenience of the hybrid system actually emphasises the importance of extending the computations to a broader reality, i.e. the upstream processes for the biofuel production and the environmental/social drawbacks due to fossil-derived emissions. Thanks to this “boundary widening”, one can realise the hidden benefits of the hybrid over the CCGT system.
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Kumar, Abhishek. "Does India offer attractive investment opportunities for exploration and production of natural gas." Thesis, University of Dundee, 2009. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.510621.

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Tarun, Cynthia. "Techno-Economic Study of CO2 Capture from Natural Gas Based Hydrogen Plants." Thesis, University of Waterloo, 2006. http://hdl.handle.net/10012/2837.

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As reserves of conventional crude oil are depleted, there is a growing need to develop unconventional oils such as heavy oil and bitumen from oil sands. In terms of recoverable oil, Canadian oil sands are considered to be the second largest oil reserves in the world. However, the upgrading of bitumen from oil sands to synthetic crude oil (SCO) requires nearly ten times more hydrogen (H2) than the conventional crude oils. The current H2 demand for oil sands operations is met mostly by steam reforming of natural gas. With the future expansion of oil sands operations, the demand of H2 for oil sand operations is likely to quadruple in the next decade. As natural gas reforming involves significant carbon dioxide (CO2) emissions, this sector is likely to be one of the largest emitters of CO2 in Canada.

In the current H2 plants, CO2 emissions originate from two sources, the combustion flue gases from the steam reformer furnace and the off-gas from the process (steam reforming and water-gas shift) reactions. The objective of this study is to develop a process that captures CO2 at minimum energy penalty in typical H2 plants.

The approach is to look at the best operating conditions when considering the H2 and steam production, CO2 production and external fuel requirements. The simulation in this study incorporates the kinetics of the steam methane reforming (SMR) and the water gas shift (WGS) reactions. It also includes the integration of CO2 capture technologies to typical H2 plants using pressure swing adsorption (PSA) to purify the H2 product. These typical H2 plants are the world standard of producing H2 and are then considered as the base case for this study. The base case is modified to account for the implementation of CO2 capture technologies. Two capture schemes are tested in this study. The first process scheme is the integration of a monoethanolamine (MEA) CO2 scrubbing process. The other scheme is the introduction of a cardo polyimide hollow fibre membrane capture process. Both schemes are designed to capture 80% of the CO2 from the H2 process at a purity of 98%.

The simulation results show that the H2 plant with the integration of CO2 capture has to be operated at the lowest steam to carbon (S/C) ratio, highest inlet temperature of the SMR and lowest inlet temperatures for the WGS converters to attain lowest energy penalty. H2 plant with membrane separation technology requires higher electricity requirement. However, it produces better quality of steam than the H2 plant with MEA-CO2 capture process which is used to supply the electricity requirement of the process. Fuel (highvale coal) is burned to supply the additional electricity requirement. The membrane based H2 plant requires higher additional electricity requirement for most of the operating conditions tested. However, it requires comparable energy penalty than the H2 plant with MEA-CO2 capture process when operated at the lowest energy operating conditions at 80% CO2 recovery.

This thesis also investigates the sensitivity of the energy penalty as function of the percent CO2 recovery. The break-even point is determined at a certain amount of CO2 recovery where the amount of energy produced is equal to the amount of energy required. This point, where no additional energy is required, is approximately 73% CO2 recovery for the MEA based capture plant and 57% CO2 recovery for the membrane based capture plant.

The amount of CO2 emissions at various CO2 recoveries using the best operating conditions is also presented. The results show that MEA plant has comparable CO2 emissions to that of the membrane plant at 80% CO2 recovery. MEA plant is more attractive than membrane plant at lower CO2 recoveries.
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VASUDEVAN, ROHAN ADITHYA. "SWOT-PESTEL Study of Constraints to Decarbonization of the Natural Gas System in the EU Techno-economic analysis of hydrogen production in Portugal : Techno-economic analysis of hydrogen production in Portugal." Thesis, KTH, Skolan för industriell teknik och management (ITM), 2021. http://urn.kb.se/resolve?urn=urn:nbn:se:kth:diva-292186.

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The exigent need to address climate change and its adverse effects is felt all around the world. As pioneers in tackling carbon emissions, the European Union continue to be head and shoulders above other continents by implementing policies and keeping a tab on its carbon dependence and emissions. However, being one of the largest importers of Natural Gas in the world, the EU remains dependent on a fossil fuel to meet its demands.  The aim of the research is to investigate the barriers and constraints in the EU policies and framework that affects the natural gas decarbonization and to investigate the levelized cost of hydrogen production (LCOH) that would be used to decarbonize the natural gas sector. Thus a comprehensive study, based on existing academic and scientific literature, EU policies, framework and regulations pertinent to Natural gas and a techno economic analysis of possible substitution of natural gas with Hydrogen, is performed. The motivation behind choosing hydrogen is based on various research studies that indicate the importance and ability to replace to natural gas. In addition, Portugal provides a great environment for cheap green hydrogen production and thus chosen as the main region of evaluation.  The study evaluates the current framework based on a SWOT ((Strength, Weakness, and Opportunities & Weakness) analysis, which includes a PESTEL (Political, Economic, Social, Technological, Environmental & Legal) macroeconomic factor assessment and an expert elicitation. The levelized cost of hydrogen is calculated for blue (SMR - Steam Methane Reforming with natural gas as the feedstock) and green hydrogen (Electrolyzer with electricity from grid, solar and wind sources). The costs were specific to Portuguese conditions and for the years 2020, 2030 and 2050 based on availability of data and the alignment with the National Energy and Climate Plan (NECP) and the climate action framework 2050. The sizes of Electrolyzers are based on the current Market capacities while SMR is capped at 300MW. The thesis only considers production of hydrogen. Transmission, distribution and storage of hydrogen are beyond the scope of the analysis.  Results show that the barriers are mainly related to costs competitiveness, amendments in rules/regulations, provisions of incentives, and constraints in the creation of market demand for low carbon gases. Ensuring energy security and supply while being economically feasible demands immediate amendments to the regulations and policies such as incentivizing supply, creating a demand for low carbon gases and taxation on carbon.  Considering the LCOH, the cheapest production costs continue to be dominated by blue hydrogen (1.33 € per kg of H2) in comparison to green hydrogen (4.27 and 3.68 € per kg of H2) from grid electricity and solar power respectively. The sensitivity analysis shows the importance of investments costs and the efficiency in case of electrolyzers and the carbon tax in the case of SMR. With improvements in electrolyzer technologies and increased carbon tax, the uptake of green hydrogen would be easier, ensuring a fair yet competitive gas market.
Det starka behovet av att ta itu med klimatförändringarna och deras negativa effekter är omfattande världen över. Den europeiska unionen utgör en pionjär när det gäller att såväl hantera sina koldioxidberoende och utsläpp som att implementera reglerande miljöpolitik, och framstår därmed som överlägsen andra stater och organisationer i detta hänseende. Unionen är emellertid fortfarande mycket beroende av fossilt bränsle för att uppfylla sina energibehov, och kvarstår därför som en av världens största importörer av naturgas.  Syftet med denna forskningsavhandling är att undersöka befintliga hinder och restriktioner i EU: s politiska ramverk som medför konsekvenser avkolningen av naturgas, samt att undersöka de utjämnande kostnaderna för väteproduktion (LCOH) som kan användas för att avkolna naturgassektorn. Därmed utförs en omfattande studie baserad på befintlig akademisk och vetenskaplig litteratur, EU: s politiska ramverk och stadgar som är relevanta för naturgasindustrin. Dessutom genomförs en teknisk-ekonomisk analys av eventuella ersättningar av naturgas med väte. Valet av väte som forskningsobjekt motiveras olika forskningsstudier som indikerar vikten och förmågan att ersätta till naturgas. Till sist berör studien Portugal. som tillhandahåller en lämplig miljö för billig och grön vätgasproduktion. Av denna anledning är Portugal utvalt som den viktigaste utvärderingsregionen.  Studien utvärderar det nuvarande ramverket baserat på en SWOT-analys ((Strength, Weakness, and Opportunities & Weakness), som inkluderar en PESTEL (Political, Economical, Social, Technological, Environmental och Legal) makroekonomisk faktoranalys och elicitering. Den utjömnade vätekostnaden beräknades i blått (SMR - Ångmetanreformering med naturgas som råvara) och grönt väte (elektrolyser med el från elnät, sol och vindkällor). Kostnaderna var specifika för de portugisiska förhållandena under åren 2020, 2030 och 2050 baserat på tillgänglighet av data samt anpassningen till den nationella energi- och klimatplanen (NECP) och klimatåtgärdsramen 2050. Storleken på elektrolyserar baseras på den nuvarande marknadskapaciteten medan SMR är begränsad till 300 MW. Avhandlingen tar endast hänsyn till produktionen av vätgas. Transmission, distribution och lagring av väte ligger utanför analysens räckvidd.  Resultaten visar att hindren är främst relaterade till kostnadskonkurrens, förändringar i stadgar och bestämmelser, incitament och begränsningar i formerandet av efterfrågan på koldioxidsnåla gaser på marknaden. Att säkerställa energiförsörjning och tillgång på ett ekonomiskt hållbart sätt kräver omedelbara ändringar av reglerna och politiken, såsom att stimulera utbudet, att skapa en efterfrågan på koldioxidsnåla gaser och genom att beskatta kol.  När det gäller LCOH dominerar blåväte beträffande produktionskostnaderna (1,33 € per kg H2) jämfört med grönt väte (4,27 respektive 3,68 € per kg H2) från elnät respektive solenergi. Osäkerhetsanalysen visar vikten av investeringskostnader och effektiviteten vid elektrolysörer och koldioxidskatten för SMR. Med förbättringar av elektrolys-tekniken och ökad koldioxidskatt skulle upptagningen av grön vätgas vara enklare och säkerställa en rättvis men konkurrenskraftig gasmarknad.
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Streich, Daniel. "Stepping into Catalysis : Kinetic and Mechanistic Investigations of Photo- and Electrocatalytic Hydrogen Production with Natural and Synthetic Molecular Catalysts." Doctoral thesis, Uppsala universitet, Fysikalisk kemi, 2013. http://urn.kb.se/resolve?urn=urn:nbn:se:uu:diva-197946.

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In light of its rapidly growing energy demand, human society has an urgent need to become much more strongly reliant on renewable and sustainable energy carriers. Molecular hydrogen made from water with solar energy could provide an ideal case. The development of inexpensive, robust and rare element free catalysts is crucial for this technology to succeed. Enzymes in nature can give us ideas about what such catalysts could look like, but for the directed adjustment of any natural or synthetic catalyst to the requirements of large scale catalysis, its capabilities and limitations need to be understood on the level of individual reaction steps. This thesis deals with kinetic and mechanistic investigations of photo- and electrocatalytic hydrogen production with natural and synthetic molecular catalysts. Photochemical hydrogen production can be achieved with both E. coli Hyd-2 [NiFe] hydrogenase and a synthetic dinuclear [FeFe] hydrogenase active site model by ruthenium polypyridyl photosensitization. The overall quantum yields are on the order of several percent. Transient UV-Vis absorption experiments reveal that these yields are strongly controlled by the competition of charge recombination reactions with catalysis. With the hydrogenase major electron losses occur at the stage of enzyme reduction by the reduced photosensitizer. In contrast, catalyst reduction is very efficient in case of the synthetic dinuclear active site model. Here, losses presumably occur at the stage of reduced catalyst intermediates. Moreover, the synthetic catalyst is prone to structural changes induced by competing ligands such as secondary amines or DMF, which lead to catalytically active, potentially mononuclear, species. Investigations of electrocatalytic hydrogen production with a mononuclear catalyst by cyclic voltammetry provide detailed kinetic and mechanistic information on the catalyst itself. By extension of existing theory, it is possible to distinguish between alternative catalytic pathways and to extract rate constants for individual steps of catalysis. The equilibrium constant for catalyst protonation can be determined, and limits can be set on both the protonation and deprotonation rate constant. Hydrogen bond formation likely involves two catalyst molecules, and even the second order rate constant characterizing hydrogen bond formation and/or release can be determined.
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Fauguerolles, Colin. "Etude expérimentale de la production d'H₂ associée à la serpentinisation des péridotites au niveau des dorsales océaniques lentes : quantification, état rédox, mécanismes réactionnels." Thesis, Orléans, 2016. http://www.theses.fr/2016ORLE2058/document.

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Afin de mieux comprendre la serpentinisation des roches mantelliques au niveau des dorsales océaniques lentes, diverses séries d’expériences ont été réalisées à 50 MPa et 250, 300 et 350 ℃ pour quantifier l’H₂ produit et clarifier les liens entre la production d’ H₂, les phases minéralogiques produites et les propriétés rédox dues à la présence d’ H₂. Les résultats, qui constituent un effort cohérent de prise en compte des paramètres et conditions rédox lors de la serpentinisation, sont les suivants : – Une nouvelle méthode expérimentale de mesure in situ de la \fH a été mise au point à 250 et 300 ℃, 50 MPa. Les deux variables exprimant la concentration d’H2 dans le fluide, \molalHydAq et \fH, ont été reliées quantitativement. Ces résultats permettent le calcul de la \fO dans les systèmes hydrothermaux océaniques à partir de la concentration en hydrogène dissout. La production d’ H₂ commence précocement, augmente rapidement et est continue au cours de la serpentinisation. – Les expériences d’interaction harzburgite-eau de mer montrent que la serpentinisation est une dissolution irréversible de l’olivine et de l’orthopyroxene et qu’elle se décompose en une succession d’étapes impliquant des assemblages de phases hors d’équilibre et métastables. – Les mécanismes de la serpentinisation et les assemblages de phases produits (en particulier les oxydes de fer) dépendent de la \fH laquelle est étroitement contrôlée par les régimes de circulation des fluides dans la croûte océanique. – La modélisation thermodynamique des fluides hydrothermaux riches en H₂ souligne le besoin de connaître précisément \yHydAq , le coefficient d’activité de \hydAq
To better understand serpentinization of mantle rocks at slow-spreading ridges, several series of experiments have been conducted at 50 MPa and 250, 300 et 350 ℃ to quantify the H₂ production associated with the serpentinization process, and to clarify the relations between the H₂ generation, the nature of product mineral phases and the redox properties of H₂ bearing hydrothermal systems. The main results of this work, which represents a significant effort toward the consideration of redox parameters and processes during serpentinisation, are the following: – A new experimental method of in situ monitoring of the \fH has been set up at 250 and 300 ℃, 50 MPa. The two variables expressing the H₂ production, \molalHydAq; aq and \fH , have been related quantitatively. Results enable the \fO of hydrothermal oceanic systems to be computed from the dissolved hydrogen concentration. H₂ production starts early, increases rapidly and is continuous in our serpentinization experiments. – Harzburgite-seawater interaction experiments show that serpentinisation is an irreversible dissolution reaction of olivine and orthopyroxene and that it consists of a sequence of discrete steps involving metastable and disequilibrium phase assemblages. – Serpentinisation mechanisms and phase assemblages (especially Fe oxides) depend on \fH, the latter being closely controlled by processes of fluid circulation in the oceanic crust. – Thermodynamic modelling of H₂ rich hydrothermal fluids stresses the need to know precisely \yHydAq, the activity coefficient of \hydAq
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Lomax, Franklin D. "Investigation of steam reformation of natural gas for the very small scale production of hydrogen fuel for light duty vehicles in appliance-type refueling systems." Master's thesis, This resource online, 1997. http://scholar.lib.vt.edu/theses/available/etd-09052009-040323/.

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Machado, Taís Espíndola. "Decomposição catalítica do metano sobre catalisador Cu-Ni-Al : taxa da reação e regeneração do catalisador." reponame:Biblioteca Digital de Teses e Dissertações da UFRGS, 2007. http://hdl.handle.net/10183/10051.

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O hidrogênio é considerado uma fonte ideal de energia, pois sua combustão não gera contaminantes, apenas água. Dentre os processos disponíveis para produção de hidrogênio, destaca-se a decomposição catalítica do metano, pois, ao contrário do que ocorre na reforma a vapor e na oxidação parcial, nesta rota não há produção de CO. O objetivo deste trabalho é o estudo cinético e a determinação da taxa da reação de decomposição do metano sobre catalisador tipo óxido misto (Cu-Ni-Al) para obtenção de hidrogênio de alta pureza. O catalisador foi separado em quatro faixas de granulometria a fim de se determinar a influência da difusão interna à partícula na velocidade da reação, e o critério de Mears foi utilizado para avaliar o efeito da difusão externa. Os resultados obtidos mostram que, nas condições estudadas, os efeitos difusivos não influenciam significativamente a velocidade da reação. A seguir, a reação foi realizada sob diferentes temperaturas (500 a 600°C) e concentrações de metano (0,5 a 1,2 mol m-3), para determinação da equação da taxa. Observou-se que a reação é de primeira ordem, com uma energia de ativação de 50655 J mol-1. Além do hidrogênio, a reação forma carbono que se deposita na superfície do catalisador causando sua desativação. Os efeitos da regeneração do catalisador por oxidação deste carbono também foram investigados. Repetidos ciclos de reaçãoregeneração foram executados, sendo a regeneração realizada por oxidação do carbono com ar sintético ou por oxidação e redução. A oxidação foi conduzida a diferentes temperaturas (500 a 600°C) e intervalos de duração (20 a 75 min), com a reação ocorrendo em condições severas (600°C e 1,2 mol m-3 de metano). A melhor condição de regeneração, ou seja, aquela que permite um maior número de ciclos com baixa perda de atividade, foi determinada. Observou-se, também, que o carbono depositado apresenta a forma de nanotubos, os quais têm se tornado um dos campos mais ativos da nanociência e da nanotecnologia, devido a suas propriedades excepcionais. Os nanotubos de carbono formados durante a reação foram analisados, quanto a sua estrutura, por Microscopia Eletrônica de Varredura (MEV).
Hydrogen is considered the ideal source of energy, because its combustion doesn't generate pollutants, just water. The catalytic decomposition of methane stands out among the available processes for hydrogen production because, unlike steam reform and partial oxidation, in this route there is not production of CO. The objective of this work is the kinetic study and the reaction rate determination of methane catalytic decomposition over Cu-Ni-Al catalyst for pure hydrogen production. In order to determinate the limiting step, reaction was conducted using four catalyst particle size ranges and the Mears criterion was applied. The external diffusion effects and diffusion in porous catalysts step do not influence significantly the reaction rate in the studied conditions. The reaction was carried out in a thermobalance with different temperatures (500 to 600°C) and methane concentrations (0.5 to 1.2 mol m-3) to determining the reaction rate. It was observed that the reaction is of first order, with activation energy of 50655 J mol-1. The reaction also forms carbon, which is deposited on the catalyst surface causing deactivation. The carbon oxidation for catalyst regeneration was also investigated. Repeated reaction-regeneration cycles were carried out, being the regeneration composed by oxidation or by oxidation and reduction. The oxidation was carried out at different temperatures (500 to 600°C) and times (20 to 75min), with the reaction happening in severe conditions (600°C and methane concentration of 1.2 mol m-3). The best regeneration condition, that is, the condition that allows a larger number of cycles with low activity loss, it was determined. It was also observed that the deposited carbon is in the nanotubes form, which has exceptional properties. The structure of carbon nanotubes formed during the reaction was analyzed by Scanning Electron Microscopy (SEM).
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Books on the topic "Natural hydrogen exploration and production"

1

Riazi, M. R., ed. Exploration and Production of Petroleum and Natural Gas. 100 Barr Harbor Drive, PO Box C700, West Conshohocken, PA 19428-2959: ASTM International, 2016. http://dx.doi.org/10.1520/mnl73-eb.

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Max, Michael D., and Arthur H. Johnson. Exploration and Production of Oceanic Natural Gas Hydrate. Cham: Springer International Publishing, 2016. http://dx.doi.org/10.1007/978-3-319-43385-1.

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Max, Michael D., and Arthur H. Johnson. Exploration and Production of Oceanic Natural Gas Hydrate. Cham: Springer International Publishing, 2019. http://dx.doi.org/10.1007/978-3-030-00401-9.

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Riazi, M. R. Exploration and production of petroleum and natural gas. West Conshohocken, PA: ASTM International, 2016.

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Carlson, Marvin. Oil in Nebraska: 50 years of production, 100 years of exploration, 500 million years of history. Lincoln, Neb: Nebraska Geological Survey, Conservation and Survey Division, Institute of Agriculture and Natural Resources, University of Nebraska--Lincoln, 1989.

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Jifu, Li, Li Youqong, and Wang Ping, eds. Detailed exploration and development of highly faulted oilfields. Beijing, China: Petroleum Industry Press, 1997.

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Onuoha, K. Mosto. Oil and gas exploration and production in Nigeria: Recent developments and challenges ahead. Ibadan, Nigeria: The Postgraduate School, University of Ibadan, 2004.

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R, Plater Jason, Foster Associates (Washington, D.C.), and United States. Minerals Management Service. Gulf of Mexico OCS Region, eds. Economic effects of coastal Alabama and Destin Dome offshore natural gas exploration, development, and production. New Orleans: U.S. Dept. of the Interior, Minerals Management Service, Gulf of Mexico OCS Region, 2000.

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Guernsey, A. T. Profitability study crude oil and natural gas exploration, development, and production activities in the USA, 1959-1988. Santa Fe, New Mexico: Shell Oil Co., 1990.

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International Union for Conservation of Nature and Natural Resources. and Oil Industry International Exploration and Production Forum., eds. Oil and gas exploration and production in mangrove areas: Guidelines for environmental protection. Gland, Switzerland: IUCN, 1993.

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Book chapters on the topic "Natural hydrogen exploration and production"

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Zhang, Jianliang, Kejiang Li, Zhengjian Liu, and Tianjun Yang. "Hydrogen Production and Storage." In Primary Exploration of Hydrogen Metallurgy, 37–115. Singapore: Springer Nature Singapore, 2024. http://dx.doi.org/10.1007/978-981-99-6827-5_2.

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Amaro, Helena M., M. GlóRia Esquível, Teresa S. Pinto, and F. Xavier Malcata. "Hydrogen Production by Microalgae." In Natural and Artificial Photosynthesis, 231–41. Hoboken, NJ, USA: John Wiley & Sons Inc., 2013. http://dx.doi.org/10.1002/9781118659892.ch8.

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Eroglu, Ela, Matthew Timmins, and Steven M. Smith. "Green Hydrogen: Algal Biohydrogen Production." In Natural and Artificial Photosynthesis, 267–84. Hoboken, NJ, USA: John Wiley & Sons Inc., 2013. http://dx.doi.org/10.1002/9781118659892.ch10.

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Max, Michael D., and Arthur H. Johnson. "Exploration for Deepwater Natural Gas Hydrate." In Exploration and Production of Oceanic Natural Gas Hydrate, 75–135. Cham: Springer International Publishing, 2016. http://dx.doi.org/10.1007/978-3-319-43385-1_3.

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Max, Michael D., and Arthur H. Johnson. "Exploration for Deepwater Natural Gas Hydrate." In Exploration and Production of Oceanic Natural Gas Hydrate, 95–147. Cham: Springer International Publishing, 2018. http://dx.doi.org/10.1007/978-3-030-00401-9_3.

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De Falco, Marcello. "Membrane Integration in Natural Gas Steam Reforming." In Membrane Reactors for Hydrogen Production Processes, 103–22. London: Springer London, 2011. http://dx.doi.org/10.1007/978-0-85729-151-6_5.

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Kumar, Kanhaiya, and Debabrata Das. "CO2Sequestration and Hydrogen Production Using Cyanobacteria and Green Algae." In Natural and Artificial Photosynthesis, 173–215. Hoboken, NJ, USA: John Wiley & Sons Inc., 2013. http://dx.doi.org/10.1002/9781118659892.ch6.

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Bagirov, E., and I. Lerche. "Natural Hazards in Hydrocarbon Exploration and Production Assessments." In Impact of Natural Hazards on Oil and Gas Extraction, 327–33. Boston, MA: Springer US, 1999. http://dx.doi.org/10.1007/978-1-4757-3019-7_12.

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Craven, J. D., and L. A. Frank. "Atomic hydrogen production rates for comet P/Halley from observations with Dynamics Explorer 1." In Exploration of Halley’s Comet, 351–56. Berlin, Heidelberg: Springer Berlin Heidelberg, 1988. http://dx.doi.org/10.1007/978-3-642-82971-0_63.

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Max, Michael D., and Arthur H. Johnson. "Energy Overview: Prospects for Natural Gas." In Exploration and Production of Oceanic Natural Gas Hydrate, 1–38. Cham: Springer International Publishing, 2016. http://dx.doi.org/10.1007/978-3-319-43385-1_1.

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Conference papers on the topic "Natural hydrogen exploration and production"

1

Fidler, Brandy R., Kerry L. Sublette, Gary E. Jenneman, and Greg A. Bala. "A Novel Approach to Hydrogen Sulfide Removal From Natural Gas." In SPE/EPA/DOE Exploration and Production Environmental Conference. Society of Petroleum Engineers, 2003. http://dx.doi.org/10.2118/81203-ms.

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Alexander, Elinor. "Natural hydrogen exploration in South Australia." In PESA Symposium Qld 2022. PESA, 2022. http://dx.doi.org/10.36404/putz2691.

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South Australia has taken the lead nationally in enabling exploration licences for natural hydrogen. On 11 February 2021 the Petroleum and Geothermal Energy Regulations 2013 were amended to declare hydrogen, hydrogen compounds and by-products from hydrogen production regulated substances under the Petroleum and Geothermal Energy Act 2000 (PGE Act). Companies are now able to apply to explore for natural hydrogen via a Petroleum Exploration Licence (PEL) and the transmission of hydrogen or compounds of hydrogen are now permissible under the transmission pipeline licencing provisions of the PGE Act. The maximum area of a PEL is 10,000 square kilometres so they provide a large acreage position for explorers. PEL applicants need to provide evidence of their technical and financial capacity as well as a 5-year work program which could include field sampling, geophysical surveys (e.g., aeromagnetics, gravity, seismic and MT) and exploration drilling to evaluate the prospectivity of the licence for natural hydrogen. Since February 2021, seven companies have lodged 35 applications for petroleum exploration licences (PELs), targeting natural hydrogen. The first of these licences (PEL 687) over Kangaroo Island and southern Yorke Peninsula was granted to Gold Hydrogen Pty Ltd on 22 July 2021. As well as issuing exploration licences, a key role of the South Australian Department for Energy and Mining is to provide easy access to comprehensive geoscientific data submitted by mineral and petroleum explorers and departmental geoscientists since the State was founded in 1836. Access to old 1920s and 1930s reports, together with modern geophysical and well data has underpinned the current interest in hydrogen exploration. Why the interest? 50-80% hydrogen content was measured in 1931 by the Mines Department in gas samples from wells on Kangaroo Island, Yorke Peninsula and the Otway Basin, potential evidence that the natural formation of hydrogen has occurred. Iron-rich cratons and uranium-rich basement (also a target for geothermal energy explorers) occur in the Archaean-Mesoproterozoic Gawler Craton, Curnamona and Musgrave provinces which are in places fractured and seismically active with deep-seated faults. Sedimentary cover ranges from Neoproterozoic-Recent in age, with thick clastic, carbonate and coal measure successions in hydrocarbon prospective basins and, in places, occurrences of mafic intrusives and extrusives, iron stones, salt and anhydrite which could also be potential sources of natural hydrogen.
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Leppin, Dennis. "Natural Gas Production: Performance of Commercial Technology for Removing Small Amounts of Hydrogen Sulfide." In SPE/EPA Exploration and Production Environmental Conference. Society of Petroleum Engineers, 1995. http://dx.doi.org/10.2118/29743-ms.

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Zhao, Hongwen, Ernest A. Jones, Rajput Seemant Singh, Hasnol Hady B. Ismail, and Seng WahTan. "The Hydrogen System in the Subsurface: Implications for Natural Hydrogen Exploration." In ADIPEC. SPE, 2023. http://dx.doi.org/10.2118/216710-ms.

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Abstract In the context of global efforts to achieve carbon neutrality, Hydrogen (H2) has emerged as a key solution for reducing greenhouse gases emission. However, current methods of hydrogen production, such as thermochemical and electrochemical processes like electrolysis, methane reforming and pyrolysis, are generally expensive and suffer from issues including intensive carbon dioxide emission and high electricity consumption etc. (Ishaq et al. 2022; Younas et al. 2022). In fact, hydrogen gas can naturally occur in the subsurface which has been manifested by numerous hydrogen seepages found across the world (cf. Zgonnik 2020 and the references therein). Notably, a significant discovery of natural hydrogen was made accidently during drilling a water well (Bougou-1) in Mali in 1987. Subsequent exploration in the vicinity of Bougou-1 confirmed the existence of an active hydrogen system in the area (Prinzhofer et al. 2018), highlighting the possibility of commercial hydrogen accumulation in the subsurface. Moreover, there is a growing consensus that natural hydrogen could be an important alternative for hydrogen production (Zgonnik 2020). In recent years, extensive exploration activities and scientific research focusing on natural hydrogen occurrences, generation mechanisms, and accumulation processes have been conducted, particularly, in Africa (Moretti et al. 2022; Prinzhofer et al. 2018), Australia (Boreham et al. 2021; Frery et al. 2021; Leila eta al. 2022; Rezaee, 2021), Europe (Combaudon et al. 2022; Larin et al. 2015; Lefeuvre et al. 2022; Leila et al. 2021), Brazil (Moretti et al. 2021; Prinzhofer et al. 2019), and the USA (Guélard et al. 2017; Zgonnik et al. 2015). Geological investigations indicate that natural hydrogen is dominantly found on Precambrian cratons, ophiolite belts and mid-oceanic ridges (Rigollet and Prinzhofer, 2022). It occurs as gas leakages on the surface or is associated with other gases in the conventional and unconventional gas plays (Milkov 2022).
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Holmes, Lance, Sandra Menpes, and Matt Densley. "Natural Hydrogen and Helium Gas Exploration in the Amadeus Basin." In Central Australian Basins Symposium IV. Petroleum Exploration Society of Australia (PESA), 2022. http://dx.doi.org/10.36404/ykii5583.

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As the world transitions to a low carbon future and global helium consumption grows, the Amadeus Basin is emerging as a prime location for high helium and natural hydrogen gas exploration. With a regionally extensive evaporite seal, and significant hydrogen and helium identified in sub-evaporite gases, the Amadeus Basin has potential to be one of the world’s premier provinces for naturally occurring hydrogen and helium production. Gas compositions from the Mt Kitty 1 well indicate >11% hydrogen and 9% helium (very high concentrations by global standards), with 6% helium also encountered in the Magee 1 well.
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Crawshaw, Michael, William Brundick, Michael Juncker, Kristina Barbuto, Alyn Jenkins, and Sooi Kim Lim. "A Hybrid H2S Removal Solution. Using Liquid vs. Fixed Bed H2S Scavengers in Harmony." In Middle East Oil, Gas and Geosciences Show. SPE, 2023. http://dx.doi.org/10.2118/213604-ms.

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Hydrogen Sulfide (H2S) is an organic compound created naturally during the decaying process. In crude oil and natural gas H2S is generated when Sulfur is removed from petroleum products. This phenomenon occurs at various stages during exploration, production and refining. In addition to the naturally occurring H2S, sulfate reducing bacteria or SRB produce Hydrogen Sulfide (H2S) souring the reservoir production. SRB’s are living organisms that require a specific set of circumstances to grow; they need organic carbon, a sulfur source, water and the correct temperature to produce H2S. Some facilities may not have a desulfurization plan especially when the reservoir was initially identified as a ‘sweet well’. In this case desulfurization treatment was not considered in their operations and maintenance strategies. However, over recent years the enquiries for desulfurization on brown field operations have increased indicating that ‘sweet wells’ may or have turned sour, possibly due to introduction of SRB from the surface via water injection.
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Savarese, Matteo, Jérémy Bompas, Ward De Paepe, and Alessandro Parente. "Towards Fast Prediction of Flame Stability and Emissions of mGT Combustion Chambers: a Chemical Reactor Network Approach." In ASME Turbo Expo 2022: Turbomachinery Technical Conference and Exposition. American Society of Mechanical Engineers, 2022. http://dx.doi.org/10.1115/gt2022-81963.

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Abstract Hydrogen as energy carrier, in combination with dry, low-NOx micro gas turbines (mGTs), is receiving increasing attention, since it can represent an attractive solution for a low-carbon, highly efficient and decentralized energy restitution system. However, accommodating hydrogen-enriched fuel blends in already existing combustion technologies is not an easy task, due to the increased reactivity of this fuel and the higher associated NOx emission. In this framework, reliable numerical models are needed to assist the industry towards the re-design of existing combustion assets. In particular, predicting thermal efficiency and pollutant emissions is of crucial importance for assessing the performances of a given system, since energy production facilities will have to cope with more stringent regulations. Alternative, physics-based modeling tools, such as Chemical Reactor Networks (CRNs), can represent an appealing solution for fast and reliable predictions of overall combustion efficiency and pollutants emissions. This tool allows to represent complex reactive flow fields as a series of idealized reactor models, thus drastically reducing the computational cost of the simulations. For this reason, detailed kinetic schemes can be employed. Detailed chemistry is crucial for reliable pollutants predictions, especially for NOx and CO, since the formation of those chemical species follows complex chemical pathways. The use of CRNs is quite frequent in literature, especially for performing parametric studies for gas turbines applications. The design of an equivalent CRN for a given combustor is based on the manual observation of the main flow-field features, which can be obtained from experiments or CFD data. The aim of this paper is to construct a highly simplified CRN of a typical mGT, Turbec T100 combustor, in order to perform design exploration studies. The effect of the main operating parameters, such as equivalence ratio, air inlet temperature and fuel composition was studied. Moreover, part load conditions were also simulated. Results highlighted that hydrogen addition does not systematically leads to increased pollutants emissions, since due to its higher reactivity, it offers the possibility to operate in leaner conditions, with respect to natural gas. The obtained results aim at providing useful guidelines for further experimental or detailed numerical design explorations for identified interesting conditions.
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Zhao, H., E. Jones, R. S. Singh, H. H. Ismail, and S. W. Tan. "Conceptual Models of Hydrogen System: Implications for Natural Hydrogen Exploration." In EAGE Conference on the Future of Energy - Role of Geoscience in the Energy Transition. European Association of Geoscientists & Engineers, 2023. http://dx.doi.org/10.3997/2214-4609.202372036.

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Pandey, Prateek. "Billions of Barrels at Risk in Southeast Asia Due to Sour Gas." In Offshore Technology Conference Asia. OTC, 2022. http://dx.doi.org/10.4043/31335-ms.

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Abstract Southeast Asia is one of the leading regions globally in terms of planned gas developments in the next decade. We estimate sour gas contamination in Southeast Asian gas discoveries is one of the major challenges delaying over 10 billion barrels of oil equivalent gas resources from coming online. These developments are planned in Malaysia, Indonesia, and Vietnam, requiring around $20 billion of investments, and could potentially make a significant contribution to regional production post-2030. But the fields contain high levels of sour gas, which makes development challenging and costly. Sour gas refers to natural gas that contains significant amounts of acidic gases such as hydrogen sulfide and carbon dioxide (CO2). Some industry majors are moving forward with exploration and development - albeit at a slow pace. Off Malaysia, work on Petronas’ Kasawari, Shell's Rosmari-Marjoram and PTTEP's Lang Lebah fields have been lined up, while Indonesia has witnessed similar slow progress on similar projects operated by IOCs and the government is also hoping the potential of its Natuna D-Alpha field will attract investors. However, as domestic gas demand in the countries increases and output drops, efforts must be made to overcome the complex geology and associated challenges. In fact, globally SE Asia & NW Australia are one of the largest regions with concentrations of sour gas. The paper intends to highlight Southeast Asia's role in planned gas developments globally and the significance of these developments in regional production. We deep dive into the planned developments risked by the sour gas contamination which makes up over 40% of the gas resources planned for development in Southeast Asia by 2030.
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Fidler, Brandy Raye, Kerry Lyn Sublette, Gary Edward Jenneman, and Gregory Alan Bala. "Bioreactors for Natural-Gas Desulfurization." In SPE/EPA/DOE Exploration and Production Environmental Conference. Society of Petroleum Engineers, 2005. http://dx.doi.org/10.2118/94420-stu.

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Reports on the topic "Natural hydrogen exploration and production"

1

Fletcher, J., and V. Callaghan. Distributed Hydrogen Production from Natural Gas: Independent Review. Office of Scientific and Technical Information (OSTI), October 2006. http://dx.doi.org/10.2172/893444.

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Spath, P. L., and M. K. Mann. Life Cycle Assessment of Hydrogen Production via Natural Gas Steam Reforming. Office of Scientific and Technical Information (OSTI), September 2000. http://dx.doi.org/10.2172/764485.

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Spath, P. L., and W. A. Amos. Assessment of Natural Gas Splitting with a Concentrating Solar Reactor for Hydrogen Production. Office of Scientific and Technical Information (OSTI), April 2002. http://dx.doi.org/10.2172/15000326.

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4

Amy Childers. Reducing Onshore Natural Gas and Oil Exploration and Production Impacts Using a Broad-Based Stakeholder Approach. Office of Scientific and Technical Information (OSTI), March 2011. http://dx.doi.org/10.2172/1034767.

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Steve Holditch and Emrys Jones. Characterizing Natural Gas Hydrates in the Deep Water Gulf of Mexico: Applications for Safe Exploration and Production Activities. Office of Scientific and Technical Information (OSTI), March 2003. http://dx.doi.org/10.2172/890985.

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Overbey, W. K. Jr, T. K. Reeves, S. P. Salamy, C. D. Locke, H. R. Johnson, R. Brunk, and L. Hawkins. A novel geotechnical/geostatistical approach for exploration and production of natural gas from multiple geologic strata, Phase 1. Office of Scientific and Technical Information (OSTI), May 1991. http://dx.doi.org/10.2172/5219085.

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Steve Holditch and Emrys Jones. CHARACTERIZING NATURAL GAS HYDRATES IN THE DEEP WATER GULF OF MEXICO: APPLICATIONS FOR SAFE EXPLORATION AND PRODUCTION ACTIVITIES. Office of Scientific and Technical Information (OSTI), January 2003. http://dx.doi.org/10.2172/823399.

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Steve Holditch and Emrys Jones. CHARACTERIZING NATURAL GAS HYDRATES IN THE DEEP WATER GULF OF MEXICO: APPLICATIONS FOR SAFE EXPLORATION AND PRODUCTION ACTIVITIES. Office of Scientific and Technical Information (OSTI), January 2003. http://dx.doi.org/10.2172/823400.

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Overbey, W. K. Jr, T. K. Reeves, S. P. Salamy, C. D. Locke, H. R. Johnson, R. Brunk, and L. Hawkins. A novel geotechnical/geostatistical approach for exploration and production of natural gas from multiple geologic strata, Phase 1. Office of Scientific and Technical Information (OSTI), May 1991. http://dx.doi.org/10.2172/5308630.

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Bent, Jimmy. Characterizing Natural Gas Hydrates in the Deep Water Gulf of Mexico: Applications for Safe Exploration and Production Activities. Office of Scientific and Technical Information (OSTI), May 2014. http://dx.doi.org/10.2172/1158898.

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