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Journal articles on the topic "Norse Discovery and exploration"
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Liu, Qian, Xuan Feng, Cai Liu, Minghe Zhang, You Tian, and Hesheng Hou. "Metallic mineral exploration by using ambient noise tomography in Ashele copper mine, Xinjiang, China." GEOPHYSICS 87, no. 3 (March 14, 2022): B221—B231. http://dx.doi.org/10.1190/geo2020-0923.1.
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Rapid advances in the seismic exploration method have allowed its application in metallic mineral exploration. However, 2D seismic profiles are often insufficient to describe the shape and areal extent of ore-bearing rock masses away from survey lines. Although more complete, collecting 3D seismic data is expensive, time consuming, and may require considerable investment in surface access. The combination of ambient noise tomography and 2D seismic reflection exploration methods can produce acceptable results relatively quickly and at a low cost. The enormous Ashele copper deposit in northwest China is a typical deposit formed by volcanic eruption. It is rich in resources and possesses good prospecting potential in its deeper and peripheral areas. We performed ambient noise tomography to investigate a near-surface 3D S-wave velocity ([Formula: see text]) structure above a depth of 0.7 km in the Ashele mining area (approximately 8 × 12 km) using 25 days of continuous ambient noise data. From the combined interpretation of the 3D [Formula: see text] structure and the existing 2D seismic reflection profile, we infer that there may be ore-bearing rock masses in the western and northern sides of the research area. We report the discovery of an ancient volcano at a depth of 500 m on the western side of this region. The banded velocity anomalies and the existence of the ancient volcano signify the formation process of a bimodal volcanic rock association. It has been proven that the combination of ambient noise tomography and 2D seismic reflection exploration methods can produce important results in metallic mineral exploration. Therefore, ambient noise tomography can be used as an economical, convenient, and efficient method for future explorations, complementing the 2D seismic reflection exploration method.
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Hao, Xue, Lin Ren, Na Li, and Zhi Cheng Huang. "Data Mining and Knowledge Discovery Based on Denoising Algorithms in Geology Exploration." Applied Mechanics and Materials 310 (February 2013): 640–43. http://dx.doi.org/10.4028/www.scientific.net/amm.310.640.
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There are mass data in geology exploration, but it is vital to find useful information or knowledge from these data. This paper is concerned with the analysis of the seismic data by the multi-channel wiener filter algorithm and the wavelet denoising method using neighboring coefficients. Known the velocity of reflection event, utilizes the resemblance of reflection signals in each seismic trace, the multi-channel wiener filter algorithm is effective in enhance reflection events and suppress the random noise. But the wavelet denoising methods don’t need any assuming conditions. The computed simulations of these two kinds of algorithms are provided to prove the availability.
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deAndrés-Galiana, Enrique J., Juan Luis Fernández-Martínez, Lucas Fernández-Brillet, Ana Cernea, and Andrzej Kloczkowski. "Addressing Noise and Estimating Uncertainty in Biomedical Data through the Exploration of Chemical Space." International Journal of Molecular Sciences 23, no. 21 (October 26, 2022): 12975. http://dx.doi.org/10.3390/ijms232112975.
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Noise is a basic ingredient in data, since observed data are always contaminated by unwanted deviations, i.e., noise, which, in the case of overdetermined systems (with more data than model parameters), cause the corresponding linear system of equations to have an imperfect solution. In addition, in the case of highly underdetermined parameterization, noise can be absorbed by the model, generating spurious solutions. This is a very undesirable situation that might lead to incorrect conclusions. We presented mathematical formalism based on the inverse problem theory combined with artificial intelligence methodologies to perform an enhanced sampling of noisy biomedical data to improve the finding of meaningful solutions. Random sampling methods fail for high-dimensional biomedical problems. Sampling methods such as smart model parameterizations, forward surrogates, and parallel computing are better suited for such problems. We applied these methods to several important biomedical problems, such as phenotype prediction and a problem related to predicting the effects of protein mutations, i.e., if a given single residue mutation is neutral or deleterious, causing a disease. We also applied these methods to de novo drug discovery and drug repositioning (repurposing) through the enhanced exploration of huge chemical space. The purpose of these novel methods that address the problem of noise and uncertainty in biomedical data is to find new therapeutic solutions, perform drug repurposing, and accelerate and optimize drug discovery, thus reestablishing homeostasis. Finding the right target, the right compound, and the right patient are the three bottlenecks to running successful clinical trials from the correct analysis of preclinical models. Artificial intelligence can provide a solution to these problems, considering that the character of the data restricts the quality of the prediction, as in any modeling procedure in data analysis. The use of simple and plain methodologies is crucial to tackling these important and challenging problems, particularly drug repositioning/repurposing in rare diseases.
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JPT staff, _. "E&P Notes (March 2021)." Journal of Petroleum Technology 73, no. 03 (March 1, 2021): 14–17. http://dx.doi.org/10.2118/0321-0014-jpt.
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KrisEnergy Pumps Cambodia’s First Crude in 17 Years A Cambodian concession has commenced production after years of delays in a venture between Singapore’s KrisEnergy and the government. The crude comes from oil fields in Block A, comprising 3083 km2 of the Khmer basin in the oil-rich Gulf of Thailand, off the southwestern coast of Sihanoukville. The concession will progress in phases once new wells are commissioned and completed. Kelvin Tang, chief executive of KrisEnergy’s Cambodian operations, called the 29 December event “an important strategic milestone” for the company, while Prime Minister Hun Sen hailed the first extraction as “a new achievement for Cambodia’s economy” and “a huge gift for our nation.” Ironbark Australian Exploration Well Declared Dry; Co-Owner Stocks Plummet BP has come up dry at its Ironbark-1 exploration well, the anticipated multi-trillion-scf prospect off the west Australian Pilbara coast. The disappointing prospect was once seen as a potential gas supplier to the emptying North West Shelf (NWS) LNG plant, where BP is a co-owner, within 5 to 10 years. After 2 months of drilling to a total depth of 5618 m, “no significant hydrocarbon shows were encountered in any of the target sands,” according to co-owner New Zealand Oil and Gas (NZOG). Petrorecôncavo Buys Petrobras’ Onshore Bahian Stake for $30 Million Brazilian operator Petrobras on 23 December signed a contract with independent producer Petrorecôncavo to sell its entire stake in 12 onshore E&P fields, the Remanso Cluster, in the state of Bahia. The sale value for the fields was $30 million; $4 million was paid on signing, $21 million at the closing of the transaction, and $5 million will be paid 1 year after that. The Remanso Cluster comprises the onshore fields of Brejinho, Canabrava, Cassarongongo, Fazenda Belém, Gomo, Mata de São João, Norte Fazenda Caruaçu, Remanso, Rio dos Ovos, Rio Subaúma, São Pedro, and Sesmaria. Zion Spuds the Israeli Megiddo-Jezreel #2 Well On 6 January, Zion Oil and Gas officially spudded the MegiddoJezreel #2 on its 99,000acre MegiddoJezreel license area in Israel. “With unique operating conditions in the COVID19 environment, our crews have performed an amazing task,” Zion CEO Robert Dunn said. “Mobilizing a rig into a new country during a pandemic and rigging up is the most challenging part of the drilling operation,” Zion’s vice president of operations, Monty Kness, added. Exxon Declares a Dud at Second Guyana Well Exxon Mobil said on 15 January that its exploration well in the prolific Stabroek Block off Guyana’s coast did not find oil in its target area. Exxon, which operates the Stabroek Block in a consortium with Hess and China’s CNOOC, has made 18 discoveries in the area in 5 years, totaling more than 8 billion BOE, for a combined potential for producing up to 750,000 B/D of crude. The Hassa1 exploration well was the giant’s second setback to its drilling campaign in recent months. Heirs Holdings Buys 45% of Shell Nigeria’s OML 17 Field Shell Nigeria announced on 15 January it had completed a $533 million sale of its stakes in an onshore OML 17 oil field in Nigeria to African strategic investor Heirs Holdings, Nigeria’s largest publicly listed conglomerate. The deal is one of the largest oil and gas financings in Africa in more than a decade, with a financing component of $1.1 billion provided by a consortium of global and regional banks and investors. Heirs Holdings, in partnership with Transcorp, one of the largest power producers in Nigeria with 2000 MW of installed capacity, purchased 45% stake in the field. It acquired the stakes of Shell, Total, and Eni to further its expansion into the oil and gas industry. Apex Discovers Oil in Egypt’s Western Desert Privately held independent E&P firm Apex International Energy, backed in part by UK energy investment firm Blue Water Energy, on 18 January announced a discovery in the Southeast Meleiha Concession (SEM) in the western desert of Egypt. The discovery was made at the SEMZ-11X well located 10 km west of Zarif field, the nearest producing field. The well was drilled to a total depth of 5,700 ft and encountered 65 ft of oil pay in the Cretaceous sandstones of the Bahariya and Abu Roash G formations. Testing of the Bahariya resulted in a peak rate of 2,100 B/D with no water. Additional uphole pay exists in the Bahariya and Abu Roash G formations that can be added to the production stream in the future. Kosmos Announces Oil at Winterfell Well Dallas-based E&P independent Kosmos Energy announced on 19 January an oil discovery in deepwater US Gulf of Mexico. The Winterfell discovery well, the product of infrastructure-led exploration (ILX), was drilled to a total depth of approximately 23,000 ft and is located in approximately 5,300 ft of water. This subsalt Upper Miocene prospect in off-shore Louisiana encountered approximately 85 ft of net oil pay in two intervals. ILX exploration, which has featured prominently in upstream operators’ portfolios in recent years of relatively low oil prices, is exploration around producing hubs that can be hooked up to those facilities easily and cheaply. The development sidesteps the need for costly and time-consuming individual hub construction. Equinor Gets Permit To Drill North Sea Wildcat Well The Norwegian Petroleum Directorate has granted Equinor a drilling permit for wildcat well 31/11-1 S in the North Sea offshore Norway, 62 km south of the Troll field. The drilling program is the first exploration well to be drilled in production license 785 S, awarded on 6 February 2015 (APA 2014). Operator Equinor and Total E&P Norge are 50/50 partners in the license, which consists of parts of Blocks 26/2 and 31/11. Petrobras, ExxonMobil Hit Hydrocarbons at Urissanê Well, Offshore Brazil Brazilian state-owned Petrobras announced on 29 January it had discovered hydrocarbons in a well located in the Campos Basin presalt off Brazil’s coast of Campos dos Gotyacaze in the State of Rio de Janeiro. Well 1-BRSA-1377-RJS (informally called Urissanê) is located in Block C-M-411, at a depth of 2950 m approximately 200 km offshore. Petrobras, which operates the block in a 50/50 partnership with Exxon Mobil, said it would analyze the well data to better target exploratory activities and assess the potential of the discovery. BP Offloads 20% Share of Oman’s Block 61 To PTTEP Marking another significant step in its divestment program, BP will sell a 20% participating interest in Oman’s 3950 km2 Block 61 in central Oman to Thailand’s national PTT Exploration and Production (PTTEP) for $2.59 billion. BP will remain operator of the block, holding a 40% interest. The sale comprises $2.45 billion payable on completion and $140 million payable contingent on preagreed conditions. After the sale, BP will hold 40% interest in Block 61, while OQ holds 30%, PTTEP 20%, and Petronas 10%. Block 61 contains the largest tight gas development in the Middle East.
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Stefatos, Aristofanis, Alexander Vereshagin, Jonny Hesthammer, Trond Kristian Kalstø, Susanne Sperrevik, and Adrian Robson. "CSEM-driven exploration over the Nordland Ridge." Interpretation 2, no. 3 (August 1, 2014): SH79—SH95. http://dx.doi.org/10.1190/int-2013-0160.1.
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Exploration efforts in the Nordland Ridge over the past two decades have resulted in the Norne, Urd, Alve, Falk, and Linerle discoveries. Besides these discoveries, several wells have failed expectations. Exploration efforts in this area are challenging because of the large variation in the rock properties of potential Triassic to early Jurassic traps that could be filled with viscous (heavy) oil. Application of controlled-source electromagnetic (CSEM) technology to derive the electrical resistivity distribution of the subsurface was thought by some oil companies to be the key that could unlock the exploration potential in the area. However, two dry wells in 2006 (6608/11-5 “Valkyrie”) and 2011 (6608/11-7s “Phoenix”) drew negative attention to CSEM within the exploration community because CSEM data were available in both cases prior to drilling. The wells targeted Jurassic Åre sands very close to the existing Linerle discovery with heavy oil in reservoir-quality Åre sandstones. The first well encountered less than 5 m of hydrocarbon traces in the Åre sands, while the second well was dry with a poorer-than-expected reservoir at target depth. This work examines the quality and reliability of the most recently acquired 3D CSEM survey. Previous interpretations are discussed in light of the 3D data and the latest drilling results. The CSEM-derived distribution of resistivity in the subsurface is in good agreement with all well log data proving that CSEM provides reliable information that can be used for interpretation and decision making. A strong and localized resistivity anomaly remains untested, although the last two wells drilled very close to it. Two interpretations were evaluated to explain the measured resistivity. The first inferred the presence of a localized sabkha evaporite in the late Carnian, while the second suggested the presence of a hydrocarbon-filled reservoir in erosional products near the base Cretaceous unconformity.
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JPT staff, _. "E&P Notes (September 2022)." Journal of Petroleum Technology 74, no. 09 (September 1, 2022): 15–19. http://dx.doi.org/10.2118/0922-0015-jpt.
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Tullow Swings and Misses off Guyana Tullow Oil has come away empty with its Beebei-Potaro exploration well, drilled in the Kanuku license, offshore Guyana. According to the company, the well encountered good quality reservoir in the primary and secondary targets but both targets were water-bearing. Noble jackup Regina Allen drilled the well to a total depth of 4325 m in 71 m of water. The well has been plugged and abandoned. Tullow will integrate the well results into its regional subsurface models and work with its joint venture partners before deciding on next steps. Repsol is the operator of the Kanuku license with a 37.5% working interest. Tullow holds 37.5% with TOQAP—a joint venture between TotalEnergies and Qatar Petroleum—holding 25%. Tullow previously said it would limit capital exposure in Guyana. The company holds a 60% interest in the Orinduik block, its other licensed area in Guyana, with partners including TotalEnergies and Eco Atlantic Oil & Gas. Oxy Brings Horn Mountain West Online in GOM Occidental has successfully turned the taps on its Horn Mountain West subsea field in the Mississippi Canyon area of the Gulf of Mexico (GOM). The field is in about 5,400 ft of water. The $250-million project comprises a pair of wells tied back to the existing Horn Mountain spar in Block 126 via a 3½-mile dual flowline. According to Oxy, the project came in on budget and 3 months ahead of schedule. It is expected to eventually add approximately 30,000 BOPD. Horn Mountain initially came on stream in late 2002. Hess Strikes Miocene-Aged Oil at Huron in GOM Hess made an oil discovery with a well at its Huron prospect in the Green Canyon area of the deepwater GOM. The well, drilled in Block 69 to a target depth of 28,900 ft by Transocean drillship Deepwater Asgard, struck high-quality, oil-bearing Miocene-aged reservoirs and established the existence of a working petroleum system. An up-dip sidetrack to the initial probe is planned. Gregory Hill, Hess’ chief operating officer, told investors in July that … “as a result of what we’re seeing at Huron we see additional prospectivity in that northern Green Canyon area, and we have a very competitive leasehold position there.” The company had stated previously that its position in the northern Green Canyon area has a high potential for multiple, high-return hub-class Miocene opportunities. Hess operates Huron with a 40% interest. Partners Chevron and Shell each hold 30% stakes. Hess struck a deal with both Chevron and Shell to farm into the prospect in February 2022. The Huron well marks Hess’ return to exploration drilling in the deepwater GOM for the first time in around 2 years. Wintershall Dea Turns the Taps at Nova Wintershall Dea started production from the Nova oil field in the Norwegian North Sea. The field comprises two subsea templates, one with three oil producers and one with three water injectors, tied back to the Gjøa platform. The expected recoverable gross reserves from the field are estimated at 90 million BOE, of which the majority will be oil. The operator said the completion of Nova emphasizes its strength as one of the largest subsea operators on the Norwegian Continental Shelf. “With the startup of the major project Nova, Wintershall Dea is now operating three subsea production fields in Norway,” said Hugo Dijkgraaf, member of the executive board and chief technology officer. The Dvalin field and the partner-operated Njord Future project, in which Wintershall Dea holds a 50% share, are planned to come on stream later this year. The company also operates recent discoveries like Dvalin North, planned for PDO hand-in (Plan for Development and Operations) by the end of 2022, and several other discoveries which could be developed in the future. Wintershall Dea is a partner in the Aker BP-operated Storjo discovery in the Norwegian Sea. Wintershall Dea operates the Nova field with a 45% stake, of which it plans to transfer 6% to OKEA in Q4 this year; Sval Energi holds 45%, Pandion Energy Norge, 10%. Eni Touts Potential 3.5-Tcf Gas Find With First Offshore Abu Dhabi Well Eni believes it has discovered an additional 1.0 to 1.5 Tcf of raw gas in place, in a deeper zone, in its first exploration well drilled in Offshore Block 2 Abu Dhabi. The discovery follows an initial finding in a shallower zone of the same well, aggregating to a total gas in place of up to 3.5 Tcf. The Italian operator said gas-bearing reservoirs were tested with excellent flow rates and fast-track development options are currently under evaluation. Eni, operator, holds a 70% stake in Block 2; PTTEP holds the remaining 30%. Eni has been present in Abu Dhabi since 2018. It operates three exploration concessions and participates with ADNOC in three offshore development and production concessions: Lower Zakum (5%), Umm Shaif and Nasr (10%), and Ghasha (25%). Petrobras Makes Gas Discovery in Colombia Petrobras confirmed the discovery of natural gas accumulation in the Uchuva-1 exploratory well drilled in the deep waters 32 km off the coast of Colombia. The discovery is about 76 km from the city of Santa Marta in a water depth of approximately 830 m. The well was drilled in the Tayrona block, with operator Petrobras (44.44%) in partnership with Ecopetrol, who holds the remaining stake. The consortium will continue its activities in the block to assess the dimensions of the new gas accumulation. CNOOC Successfully Tests Offshore Shale Well China’s CNOOC Ltd. tested commercial flows of oil and gas from an offshore shale exploration well in the South China Sea, marking the first successfully drilled shale oil well offshore China, state media reported in early August. Exploration well Weiye-1, drilled at the southwestern trough of Beibuwan basin, tested daily production of 126 bbl of oil and 1589 m3 of natural gas. CNOOC estimated that the shale oil resources in the entire basin are about 8.8 billion bbl, suggesting good exploration prospects. With the Chinese government stressing added volumes for its domestic energy supply security, national oil companies are making greater efforts to tap shale deposits despite being tougher to drill and more expensive. As of late 2021, China produced only 35,000 B/D of shale oil, mostly in the onshore northern Ordos basin and northwestern Jungar basin. Eni Strikes Oil With Baleine East Well in Côte d’Ivoire Eni has encountered oil with its Baleine East 1X well, the first exploration well in block CI-802 and second discovery on the Baleine structure offshore Côte d’Ivoire. The results have prompted a 25% increase in the oil and gas volumes in place, which are now estimated at 2.5 billion bbl of oil and 3.3 Tcf of associated gas. The well was drilled in the block operated by Eni (90%), together with its partner Petroci Holding (10%), using the drillship Saipem 12000. The final depth reached was 3165 m measured depth, in a water depth of about 1150 m. Baleine East 1X is located about 5 km east of the Baleine 1X discovery well in the adjacent block CI-101 and represents the first commercial discovery in the CI-802 block, confirming the extension of the Baleine field. The well confirmed the presence of a continuous oil column of about 48 m in reservoir rocks with good properties. From the vertical borehole, a horizontal drain of 850 m in length was subsequently drilled into the reservoir to perform a production test that confirmed potential production of at least 12,000 BOPD from the Baleine East 1X well. A third well will be drilled to ensure the accelerated startup of production and confirmation of first oil in the first half of 2023. In addition to blocks CI-101 and CI-802, Eni owns interests in five other blocks in the Ivorian deep water: CI-205, CI-501, CI-504, CI-401, and CI-801, all with the same partner, Petroci Holding. Neptune Energy Kicks Off Ofelia Exploration Well Neptune Energy began drilling operations on the Ofelia exploration well in the Norwegian sector of the North Sea. The well, 35/6-3 S, is being drilled by the Odfjell Drilling-operated semisubmersible Deepsea Yantai. The prospect is located 13 km north of the Gjøa field within the Neptune-operated PL929 License. If commercial, Ofelia could be tied back to the Neptune-operated Gjøa platform and produce at less than half the average carbon intensity of Norwegian Continental Shelf fields, according to the company. Neptune said it could potentially be developed in parallel with Hamlet (PL153). Ofelia is positioned in one of Neptune’s core areas and close to existing infrastructure. The reservoir target is the Lower Cretaceous Agat Formation and is expected to be reached at a depth of approximately 2570 m. The drilling program comprises a main bore (35/6-3 S) with an optional sidetrack (35/6-3 A) based on the outcome of the exploration well. Neptune Energy operates Ofelia with a 40% working interest. Partners are Wintershall Dea (20%), Aker BP (10%), Pandion Energy (20%), and DNO (10%). Partners Continue Successful Drilling in Algerian Desert Eni and partner Sonatrach revealed a further discovery in the Zemlet el Arbi concession, located in the Berkine North Basin in the Algerian desert. The Rhourde Oulad Djemaa Ouest-1 (RODW-1) exploration well, in the Sif Fatima II research perimeter, is the third well in the exploration drilling campaign. It led to a discovery of oil and associated gas in the Triassic sandstones of the Tagi reservoir. During its production test, the well produced 1,300 BOPD and about 2 MMcf/D of associated gas. The RODW-1 discovery comes after the significant discovery of HDLE-1, announced in March 2022, and the successful second appraisal well HDLS-1 in the adjacent Sif Fatima II. Because of their proximity to existing BRN/ROD facilities, the development of these discoveries will be fast-tracked. The Zemlet el Arbi concession is operated by a joint venture between Eni (49%) and Sonatrach (51%). The discovery is part of the new exploration campaign which will include the drilling of five wells in the Berkine North Basin.
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JPT staff, _. "E&P Notes (May 2021)." Journal of Petroleum Technology 73, no. 05 (May 1, 2021): 14–17. http://dx.doi.org/10.2118/0521-0014-jpt.
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Dugong Reserve Estimate Tightens on New Well Results Neptune Energy redefined the estimated reserves at its Dugong discovery in the Norwegian sector of the North Sea to between 40–108 million BOE based on the results of appraisal well 34/4-16 S. Prior to this appraisal, the operator believed the prospect could hold as much as 120 million BOE. The main objective of the well was achieved by establishing the oil/water contact. Neptune Energy said the new range will be subject to further detailed analysis and review, and a drillstem test on the well is planned at a later stage. The appraisal well was drilled using the Odjfell-operated semisubmersible Deepsea Yantai in about 330 m of water. The Dugong discovery will either be linked to nearby infrastructure or developed as a standalone development. Dugong is located 158 km west of Florø, Norway, and is close to the existing production facilities of the Snorre and Statfjord fields. The Dugong license partners are Neptune Energy (operator and 45%), Petrolia NOCO (20%), Idemitsu Petroleum Norge (20%), and Concedo (15%). Oselvar P&A Work Underway Decommissioning of the DNO Norge-operated Oselvar field has kicked off with the operator contracting semisubmersible Borgland Dolphin for plug-and-abandonment work. Oselvar is in the southern part of the Norwegian sector in the North Sea, 20 km southwest of the Ula field. The water depth is 70 m. Oselvar was discovered in 1991, and the plan for development and operation was approved in 2009. The field was developed via a trio of subsea wells tied to Ula. Production started in 2012 and ended in 2018. The Borgland Dolphin was moved to the field on 20 March. The rig recently went through a series of upgrades including the installation of new shale shakers, new standpipe manifold, an upgraded drilling control system, and an upgraded helideck. Decommissioning must be completed by the end of 2022. Equinor Green Lights FPSO for Brazil’s BM-C-33 Development Equinor, together with license partners Repsol Sinopec Brasil and Petrobras, have approved an FPSO-based development concept for BM-C-33, a gas/condensate field located in the Campos Basin pre-salt in Brazil. Subsea wells will be tied back to the FPSO located at the field. Gas and oil/condensate will be processed at the floater to sales specifications and exported. Crude will be offloaded by shuttle tankers and shipped to the international market after ship-to-ship transfer. A newbuild hull has been selected to accommodate the field’s planned 30-year lifetime. “BM-C-33 holds substantial volumes of gas,” said Veronica Coelho, Equinor’s country manager in Brazil. “A completion of the ongoing liberalization of the natural gas market in Brazil in line with the current plan, is key for the further development of the project. BM-C-33 is an asset that can generate value for the society, both through the creation of direct and indirect jobs, ripple effects, and through a gas supply that can induce industrial growth, as has happened in other countries.” Gas export capacity is planned for 16 million cubic meters per day with average exports expected to be 14 million cubic meters per day. Daily oil processing capacity is of 20,000 cubic meters per day. The gas-export solution is based on an integrated offshore gas pipe-line from the FPSO to a new dedicated onshore gas-receiving facility inside the Petrobras TECAB site at Cabiúnas, before connecting to the domestic gas-transmission network. Lundin Makes Small Discovery Near Edvard Grieg Lundin Energy Norway encountered a 10-m oil column with its wildcat well 16/4-13 S about 15 km south of the Edvard Grieg field in the central part of the North Sea. The operator added that about 7 m of the encountered column was of moderate to poor reservoir quality. The oil/water contact was encountered 1950 m below the sea surface. The entire reservoir, including the water zone, comprises conglomeratic sandstones in a thickness of about 380 m. Preliminary estimates place the size of the discovery between 0.5 and 1.4 million cubic meters of recoverable oil equivalent. The licensees will assess the discovery regarding a possible tie-in to the Solveig field. The well was drilled by Seadrill semisubmersible West Bollsta and will be permanently plugged and abandoned. The rig will now move to drill the 16/4-BA-1H production well on the Solveig field. Wintershall Gets Permit for Bergknapp Appraisal The Norwegian Petroleum Directorate granted Wintershall Dea Norge a drilling permit for well 6406/3-10 A to spud a follow-up probe to a discovery made in April 2020. The Bergknapp appraisal will be drilled from the Odjfell semisubmersible Deepsea Aberdeen once the rig has concluded the drilling of wildcat well 6507/4-2 S for Wintershall in production license 211. The Bergknapp appraisal will be drilled about 8 km west of the Maria field in the Norwegian Sea. The discovery well 6406/3-10 intersected an oil column of at least 60 m in the Garn formation and an oil column of at least 120 m in the Tilje formation. Preliminary estimates of the Bergknapp discovery indicate it could hold between 26–97 million BOE. The find is in production license 836 S where Wintershall is the operator and holds a 40% stake. The other licensees are DNO Norge (30%) and Spirit Energy Norway AS (30%). The area in this license comprises parts of Blocks 6406/2 and 6406/3. Guyana Says Liza Hits First-Phase Capacity Guyana’s President Irfaan Ali announced that the first phase of the Liza offshore crude project had achieved its intended full-production capacity of around 130,000 B/D. Ali told virtual attendees at the Guyana Basin Summit that he expected an additional 10 exploration and appraisal wells to be drilled off Guyana this year. He said the second phase of the Liza project, operated by ExxonMobil, would begin in 2022. The consortium led by Exxon, which includes partners Hess and CNOOC Ltd., has made 18 discoveries containing more than 8 billion bbl of recoverable oil and gas in Guyana’s Stabroek block. Equinor and Partners in Barents Bounty Equinor and partners Vår Energi and Petoro have struck oil in exploration well 7220/7-4 in production license 532 in the Barents Sea. Recoverable resources are so far estimated at between 31–50 million BOE. The well was drilled about 10 km southwest from the well 7220/8-1 on the Johan Castberg field. “Succeeding in the Barents Sea requires perseverance and a long-term perspective,” says Nick Ashton, Equinor’s senior vice president for exploration in Norway. “This discovery strengthens our belief in the opportunities that exist, not least around the Castberg, Wisting, Snøhvit, and Goliat areas.” The well, drilled by semisubmersible Transocean Enabler, struck 109 m of oil in the Stø and Nordmela formations. The top reservoir was encountered at a vertical depth of 1788 m below sea level. The expected gas cap was not encountered in the well. The well was not formation tested, but extensive data acquisition and sampling took place. Equinor said further development of the discovery toward the planned infrastructure for the Johan Castberg field will be considered at a later stage. Exploration well 7220/7-4 is the first of four planned exploration wells for Equinor in the Barents Sea this year. Eni Strikes Light Oil at Cuica Eni has made a new light-oil discovery in Block 15/06 at its Cuica prospect in the deep waters offshore Angola. The prospect is located inside the Cabaça Development Area and close to the Armada Olombendo FPSO (East Hub). Eni estimates Cuica could hold between 200 and 250 million bbl of oil in place. The Cuica-1 NFW was drilled as a deviated well by Seadrill-operated drillship Sonagol Libongos in 500 m of water and reached a total vertical depth of 4100 m, encountering an 80-m total column of reservoir of light oil (38 °API) in sandstones of Miocene age with good petrophysical properties. The discovery well is going to be sidetracked up-dip to be placed in an optimal position as a producer well. According to Eni, data collection from the well indicates an expected production capacity of around 10,000 BOPD. Cuica is the second significant oil discovery inside the existing Cabaça Development Area. The well location, intentionally placed close to East Hub’s subsea network, will allow a fast-track tie-in of the exploration well and relevant production. Eni expects the well could be on line within 6 months. Following the discoveries of Kalimba, Afoxé, Ndungu, Agidigbo, Agogo and appraisals achieved between 2018 and 2020, Cuica represents the first commercial discovery in Block 15/06 after the relaunch of the exploration campaign post-2020 COVID-19 pandemic. The discovery confirms the exploration potential of the block. A 3-year extension of the exploration period of Block 15/06 was recently granted until November 2023. The Block 15/06 joint venture comprises Eni (operator, 36.8421%), Sonangol P&P (36.8421%), and SSI Fifteen Ltd. (26.3158%). No Injuries Reported in West Mira Incident An equipment failure onboard Northern Ocean semisubmersible West Mira resulted in production equipment descending to the seabed. The rig owner said no one was injured and the well at the location was secured “with three barriers in place.” The unit was in the process of lowering the equipment on the Wintershall-operated Nova field. “While lowering a x-mas tree from West Mira, the winch wire snapped when the tree was five meters below the sea surface. The x-mas tree sunk to the seafloor 368 meters below water level. Eight people were working in the area of the rig where the incident occurred in safe distance from moving equipment,” said Wintershall. The rig manager, Seadrill Europe Management AS, and Wintershall are conducting investigations into the incident and have agreed to a plan to secure the production equipment. “A remote operated vehicle (ROV) was sent to the seafloor to assess the situation,” added the oil company. “The ROV survey showed no risk of discharge of well fluids or hydrocarbons and the x-mas tree has been localized on the template.”
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JPT staff, _. "E&P Notes (November 2022)." Journal of Petroleum Technology 74, no. 11 (November 1, 2022): 14–16. http://dx.doi.org/10.2118/1122-0014-jpt.
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Guyana Prepares for Offshore Licensing Round The Guyanese government is preparing to launch its first bidding round for offshore exploration and production of hydrocarbon blocks. New fiscal terms and conditions are being finalized which the country hopes will allow it to gain the maximum economic benefits. The 2022 bidding round, which according to the nation’s Department of Public Information, is expected to be officially launched soon and will be opened for several months to give interested companies sufficient time to prepare their competitive packages and bid to win the available acreages offshore. With the upcoming bidding round the government expects Guyana’s offshore areas to emerge as a potential super basin with over 11 billion BOE discovered to date. The process seeks to ensure the country gets a fairer share of revenues from oil and gas resources through improved fiscal arrangements, as well as safeguard the safety of people and the environment by following international best practices in offshore development. The new round also aims to be competitive with other global energy projects and assure investors of stability, predictability, and security of any investment. The government seeks to balance its developmental agenda with its climate change goals. Ault Drills Successful Smackover Well in Mississippi Ault Energy completed drilling the Harry O’Neal 20-9 No. 1 in Holmes County, Mississippi, and logged productive oil results across multiple pay zones in the Smackover formation. Completion work has begun on the well, and it is expected to be on stream soon. Ault was formed by parent BitNile this past summer to make strategic oil and gas acquisitions. The company obtained participation rights with for the O’Neal No. 1 well and future oil wells when it invested $12 million in Ecoark Holdings in June. Ault Energy exercised its participation right and acquired a 40% working interest in the well, which is the first project in an expected long-term partnership between Ecoark and Ault parent companies White River and BitNile, respectively, with the intention to drill approximately 100 oil wells over 5 years. White River’s next drilling project is expected to be a 14,000-ft-deep vertical oil well in the Wilcox, Austin Chalk, and Tuscaloosa Marine Shale formations in the Coochie oil field in Concordia Parish, Louisiana. White River also plans to drill three consecutive deep vertical drilling projects at approximately 13,000 ft in the Rodessa and Hosston sand formations on the Pisgah Field Lease in Rankin County, Mississippi. Hess Brings Another Llano Well On Stream Hess brought its Llano-6 well in the Gulf of Mexico (GOM) on stream. The new well, like the other Llano wells, is tied back to Shell’s Auger facility. Hess is planning increased activity in the Llano area based on the success of Llano-6, quality of the reservoir, and adjacent high-value prospects. Hess holds a 50% interest in the long-producing Llano field, located about 150 miles off the Louisiana coast in the Garden Banks area in an estimated 2,600 ft of water. Shell, the operator, holds a 27.5% interest, and ExxonMobil has the remaining 22.5%. The field was discovered in 1997 and achieved first oil in 2004. Recent seismic reprocessing and analysis confirmed additional development opportunities in the field. Hess expects more high-value opportunities at Llano with wells planned for 2023 and 2024 and is finalizing plans for a year-long drilling campaign starting in early 2023 that will focus on tieback and hub-class opportunities in the GOM. Mubadala Discovers Gas Field Off Malaysia Mubadala Energy and its partners have announced a new gas discovery offshore Malaysia via the Cengkih-1 exploration well in Block SK 320. The exploration well was drilled to a total depth of 1680 m and encountered a 110-m gas column in the Miocene Cycle IV/V pinnacle carbonate reservoirs. The Cengkih-1 well is located nearly 220 km off the Bintulu coast in Sarawak. The discovery is near the Pegaga gas field, also located within Block SK 320. Mubadala Energy and its partners began production from the Pegaga field in March 2022. The Pegaga field has been developed with an integrated central processing platform built to handle throughput of 550 MMcf/D of gas plus condensate. A new pipeline transports gas from the platform into an existing offshore gas network and subsequently to the onshore Petronas LNG Complex. Mubadala Energy is the operator of Block SK 320 with a 55% stake. Partners Petronas and Sarawak Shell hold 25% and 20%, respectively. Petrobras Progresses Sale of Potiguar Basin Assets Petrobras entered the binding phase of the sale of 40% of its stake in the BM-POT-17 exploratory concessions, in which the Pitu well discovery assessment plan is being developed (Blocks POT-M-853 and POT-M-855), and the POT-M-762_R15 concession (Block POT-M-762), located in deep waters in the Potiguar Basin—Equatorial Margin–off the coast of Rio Grande do Norte. Petrobras currently holds a 100% stake in these concessions and will continue as operator of the partnership after the sale. Petrobras said the search for partnership in these assets is aligned with its portfolio management strategy and the improvement of the company’s capital allocation, aiming to maximize value. POT-M-853 and POT-M-855 are exploratory blocks acquired in the 7th Bidding Round of the National Petroleum Agency (ANP) in 2006. Petrobras is conducting the discovery assessment plan for the Pitu well, with a firm commitment to drill an exploratory well (Pitu Oeste) scheduled for 2023. POT-M-762 is an exploratory block acquired in the 15th ANP Bidding Round in 2018. Petrobras plans to drill the Anhangá well between 2023 and 2024. TotalEnergies Sews Up PSA on Oman’s Block 11 TotalEnergies, along with its partners, has signed an Exploration and Production Sharing Agreement (EPSA) with the Ministry of Energy and Minerals (MEM) of the Sultanate of Oman for onshore Block 11. The first stage of the EPSA activities will see seismic acquisition in late 2022, with a first exploration well planned to be drilled in 2023. TotalEnergies will hold a 22.5% interest in the block, OQ 10% and Shell with 67.5% will be the operator. Block 11 contains undeveloped discoveries and exploration potential. “Our recent activities in Oman are a demonstration of TotalEnergies’ strategy of transformation into a multi-energy company,” said Laurent Vivier, senior vice president Middle East and North Africa, exploration and production, at TotalEnergies. “Today’s entry into the Block 11 gives us the opportunity to unlock additional potential to meet domestic and export gas demand. It strengthens our strategic relationship with the Sultanate of Oman, as illustrated last December by our entry into the neighboring Block 10 gas concession and the start of construction last July of 17-MW peak solar photovoltaic systems providing power to a desalination plant.” In 2021, TotalEnergies’ production in Oman was 39,000 BOE/D. The operator produces oil in Block 6 (4%), as well as LNG through its participation in the Oman LNG (5.54%)/Qalhat LNG (2.04% via Oman LNG) liquefaction complex with an overall capacity of 10.5 mtpa. In 2021 TotalEnergies signed a concession agreement to develop natural gas resources on the onshore Block 10 (26,55%), with first gas expected in 2023. TotalEnergies also operates exploration Block 12 (80%). India Lets New Contracts Related to Small Discovered Fields, CBM The Indian government has signed contracts for 31 discovered small fields under the third round of bidding, and for four coalbed methane (CBM) blocks under the fifth round of bidding with 14 domestic companies. These blocks have been awarded. Among these blocks, the Oil and Natural Gas Corporation (ONGC) has signed six contracts for discovered small fields, with three each for fields in the Arabian Sea and Bay of Bengal. These include four contract areas as sole bidder and two contract areas in partnership with Indian Oil Corporation Ltd. The ONGC has also signed two contracts for CBM fields situated in Jharkhand and Madhya Pradesh. Cairn Oil & Gas has signed pacts for eight fields. The third round for discovered small fields was launched by the government in June 2021 where 75 fields were offered under 31 contract areas. The CBM bidding round was launched in September 2021, which concluded at the end of May 2022 with 15 blocks under offer.
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Chari, Tara, and Lior Pachter. "The specious art of single-cell genomics." PLOS Computational Biology 19, no. 8 (August 17, 2023): e1011288. http://dx.doi.org/10.1371/journal.pcbi.1011288.
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Dimensionality reduction is standard practice for filtering noise and identifying relevant features in large-scale data analyses. In biology, single-cell genomics studies typically begin with reduction to 2 or 3 dimensions to produce “all-in-one” visuals of the data that are amenable to the human eye, and these are subsequently used for qualitative and quantitative exploratory analysis. However, there is little theoretical support for this practice, and we show that extreme dimension reduction, from hundreds or thousands of dimensions to 2, inevitably induces significant distortion of high-dimensional datasets. We therefore examine the practical implications of low-dimensional embedding of single-cell data and find that extensive distortions and inconsistent practices make such embeddings counter-productive for exploratory, biological analyses. In lieu of this, we discuss alternative approaches for conducting targeted embedding and feature exploration to enable hypothesis-driven biological discovery.
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Knowles, K., D. S. Pillay, S. Amodeo, A. J. Baker, K. Basu, D. Crichton, F. de Gasperin, et al. "MERGHERS pilot: MeerKAT discovery of diffuse emission in nine massive Sunyaev–Zel’dovich-selected galaxy clusters from ACT." Monthly Notices of the Royal Astronomical Society 504, no. 2 (April 5, 2021): 1749–58. http://dx.doi.org/10.1093/mnras/stab939.
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ABSTRACT The MeerKAT Exploration of Relics, Giant Halos, and Extragalactic Radio Sources (MERGHERS) survey is a planned project to study a large statistical sample of galaxy clusters with the MeerKAT observatory. Here we present the results of a 16-h pilot project, observed in response to the 2019 MeerKAT Shared Risk proposal call, to test the feasibility of using MeerKAT for a large cluster study using short (0.2–2.1 h) integration times. The pilot focuses on 1.28-GHz observations of 13 massive, low-to-intermediate redshift (0.22 < z < 0.65) clusters from the Sunyaev–Zel’dovich-selected Atacama Cosmology Telescope (ACT) DR5 catalogue that show multiwavelength indications of dynamical disturbance. With a 70 per cent detection rate (9/13 clusters), this pilot study validates our proposed MERGHERS observing strategy and provides twelve detections of diffuse emission, eleven of them new, indicating the strength of MeerKAT for such types of studies. The detections (signal-to-noise ratio ≳ 6) are summarized as follows: two systems host both relic(s) and a giant radio halo, five systems host radio haloes, and two have candidate radio haloes. Power values, k-corrected to 1.4 GHz, assuming a fiducial spectral index of α = −1.3 ± 0.4, are consistent with known radio halo and relic scaling relations.
Dissertations / Theses on the topic "Norse Discovery and exploration"
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Haase, Kenneth W. "Invention and exploration in discovery." Thesis, Massachusetts Institute of Technology, 1990. http://hdl.handle.net/1721.1/14257.
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Thesis (Ph. D.)--Massachusetts Institute of Technology, Dept. of Electrical Engineering and Computer Science, 1990.Includes bibliographical references (leaves 159-161).
by Kenneth William Haase Jr.
Ph.D.
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Riembau, Marc. "Exploration of the higgs sector after its discovery." Doctoral thesis, Universitat Autònoma de Barcelona, 2018. http://hdl.handle.net/10803/663947.
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El descobriment del bosó de Higgs és la culminació d’una recerca que ha
durat 40 anys, i completa un marc teòric sota el qual gairebé totes del
dades obtingudes de col·lisionadors de partícules poden ser explicades consistentment.
Simultàniament, i paradoxalment, l’aparent con rmació d’una
separacó d’escales entre l’electrofeble i la que suposadament estabilitza la
masa del bosó de Higgs posa el relleu el problema de la jerarquia. En la
recerca d’una descripció del món que simpli qui els patrons i simetries del
Model Estàndard, l’exploració de l’escala dels TeVs i en particular l’estudi
del bosó de Higgs tindran un paper central. En aquesta tesi presentem les
possibilitats que el LHC i futurs col·lisionadors proveiran, amb énfasi en la
determinació de l’auto-acoblament del bosó de Higgs. També considerarem
l’estudi de la producció de bosons electrofebles com a eina per entendre les
interaccions dels bosons de Golstone que formen part del doblet de Higgs,
mostrant la seva rellevància al combinar-ho amb les dades del pol de la Z
i altres cerques al LHC. Finalment, ens centrem en com el moment dipolar
elèctric de l’electró posa fortes restriccions en models on el bosó de Higgs
és descrit com un estat compost.The discovery of the Higgs boson culminates a 40-year long hunt and completes a theoretical framework under which almost all collider data can be consistently explained. At the same time, paradoxically, the con rmation of an apparent mass gap above the electroweak scale exacerbates the problem of the electroweak hierarchy. In the search of a description of the world that simpli es the patterns and symmetries of the Standard Model, the exploration of the TeV scale and in particular the study of the Higgs boson will play a central role. In this thesis we explore the possibilities that the LHC and future colliders will bring, with particular emphasis on the determination of the Higgs self-coupling. We also consider the pair production of electroweak bosons as a probe of the Goldstone interactions in the Higgs doublet, and show its relevance as a way to improve the Z pole measurements and its interplay with other LHC searches. Finally, we focus on how the electron’s electric dipole moment can set strong constraints on models where the Higgs arises as a composite state.
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Savovic, Jelena. "Exploration of dynamic combinatorial chemistry in enzyme-inhibitor discovery." Thesis, University of Bath, 2003. https://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.760840.
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Ross, Karen C. "“Awake:” An Animated Exploration of Self-Discovery Through Mindfulness." The Ohio State University, 2016. http://rave.ohiolink.edu/etdc/view?acc_num=osu1471826821.
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Hedden, Chet. "A guided exploration model of problem-solving discovery learning /." Thesis, Connect to this title online; UW restricted, 1998. http://hdl.handle.net/1773/7683.
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Wu, Fei. "Knowledge discovery in time-series databases." Versailles-St Quentin en Yvelines, 2001. http://www.theses.fr/2001VERS0023.
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@Aborde trois problématiques dans le contexte de la base de données temporelles. Ils sont le problème de regroupement, la similarité et l'extraction des stratégies. Il reste encore des problèmes pour les travaux futurs. Par exemple, comment réaliser le regroupement graduel pour d'autres algorithmes. Il sera intéressant de grouper des séquences en se basant sur notre nouveau modèle. Mais les questions posées sont le choix d'un algorithme, ou il faut un nouvel algorithme carrément ? Pour construire une stratégie, ce sera aussi possible de pré-définir nos actions. Puis trouver les relations entre les actions et les indicateurs correspondants afin de générer des stratégies. . .
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St, Onge Joseph. "The Geography of Exploration: A Study in the Process of Physical Exploration and Geographical Discovery." DigitalCommons@USU, 2000. https://digitalcommons.usu.edu/etd/6581.
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Exploration has been a common literary topic throughout the history of humans. However, much of this historical tradition bas possessed a fairly narrow Ill focus, emphasizing the drama and heroics of an individual explorer or concentrating on a description of a particular exploration. There has been little attempt at understanding the process of exploration and placing this important process in context with the historic and geographic phenomena that both affect and are affected by it. In this thesis, the author has broken the process of exploration down into a theoretical structure that is presented in a holistic model. This model has then been applied to the history of 15th century Portuguese exploration to test its applicability and usefulness.
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Burlington, Michael Scott. "Search & exploration, efficient planar search for automated robotic discovery." Thesis, National Library of Canada = Bibliothèque nationale du Canada, 2000. http://www.collectionscanada.ca/obj/s4/f2/dsk1/tape3/PQDD_0031/MQ64328.pdf.
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Burlington, Scott M. Sc. "Search & exploration : efficient planar search for automated robotic discovery." Thesis, McGill University, 1999. http://digitool.Library.McGill.CA:80/R/?func=dbin-jump-full&object_id=30352.
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An agent is placed in an unknown environment and charged with the task of locating a lost object. What can the agent use as an efficient technique to find the object?We propose a new algorithm for planar search. The algorithm stems from theoretical work on search games, in particular provably optimal search techniques on restricted domains. This thesis addresses the problem of efficiency in robotic search: having a mobile robot find a target object in an unknown environment with obstacles in an efficient manner. As a side-effect, the robot explores the environment.
Based on previous results, a formal description of the problem is presented along with an algorithm to solve it. This algorithm has good worst-case performance, in terms of its competitive ratio. We show experimental data validating the feasibility of our approach and typical results. Quantitative results are demonstrated showing the advantage of modified spiral search versus traditional approaches.
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Huffman, Ashley. "Discovery of Movement: An Exploration of Physical Activity through Architecture." University of Cincinnati / OhioLINK, 2017. http://rave.ohiolink.edu/etdc/view?acc_num=ucin149130367713521.
Full textBooks on the topic "Norse Discovery and exploration"
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Hopkins, Andrea. Vikings: The Norse discovery of America. New York: PowerKids Press, 2002.
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Finn, Hødnebø, and Jónas Kristjánsson, eds. The Viking discovery of America. [Oslo, Norway]: J.M. Stenersens, 1991.
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Magnus, Magnusson, and Hermann Pálsson 1921-, eds. The Vinland sagas: The Norse discovery of America. London: Penguin Books, 2003.
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Friedrich, Orval. The great ice sheet & early Vikings in mid-America. Elma, Iowa (Rt. 1, Box 64, Elma 50628): O.D.Friedrich, 1993.
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Viking Society for Northern Research, ed. The verses in Eric the Red's saga: And again, Norse visits to America. London: Viking Society for Northern Research, 2011.
Find full textBook chapters on the topic "Norse Discovery and exploration"
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Nürnberger, Andreas. "Exploration: Overview." In Bisociative Knowledge Discovery, 285–86. Berlin, Heidelberg: Springer Berlin Heidelberg, 2012. http://dx.doi.org/10.1007/978-3-642-31830-6_19.
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Hsu, Chang Samuel, and Paul R. Robinson. "Exploration for Discovery." In Petroleum Science and Technology, 83–95. Cham: Springer International Publishing, 2019. http://dx.doi.org/10.1007/978-3-030-16275-7_6.
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Glyndwr, Williams. "Exploration and Discovery." In Handbook for History Teachers, 1037–40. London: Routledge, 2021. http://dx.doi.org/10.4324/9781032163840-182.
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Gibson, Michael R. "Exploration and Discovery." In Handbook for History Teachers, 451–58. London: Routledge, 2021. http://dx.doi.org/10.4324/9781032163840-57.
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Vedder, Heinrich. "Discovery and Exploration." In South West Africa in Early Times, 3–40. London: Routledge, 2022. http://dx.doi.org/10.4324/9780429025426-2.
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Mihelčić, Matej, and Tomislav Šmuc. "InterSet: Interactive Redescription Set Exploration." In Discovery Science, 35–50. Cham: Springer International Publishing, 2016. http://dx.doi.org/10.1007/978-3-319-46307-0_3.
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Leemans, Sander J. J. "Process Discovery and Exploration." In Business Process Management Workshops, 582–85. Cham: Springer International Publishing, 2015. http://dx.doi.org/10.1007/978-3-319-15895-2_52.
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Hochheiser, Harry, and Ben Shneiderman. "Interactive Exploration of Time Series Data." In Discovery Science, 441–46. Berlin, Heidelberg: Springer Berlin Heidelberg, 2001. http://dx.doi.org/10.1007/3-540-45650-3_38.
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Hoffman, Jeffrey A. "Exploration and Discovery in Space." In Leadership and Discovery, 121–41. New York: Palgrave Macmillan US, 2009. http://dx.doi.org/10.1057/9780230101630_8.
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Haun, Stefan, Tatiana Gossen, Andreas Nürnberger, Tobias Kötter, Kilian Thiel, and Michael R. Berthold. "On the Integration of Graph Exploration and Data Analysis: The Creative Exploration Toolkit." In Bisociative Knowledge Discovery, 301–12. Berlin, Heidelberg: Springer Berlin Heidelberg, 2012. http://dx.doi.org/10.1007/978-3-642-31830-6_21.
Full textConference papers on the topic "Norse Discovery and exploration"
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Ahmad, M. "Confirming Reservoir Geometry and Exploration Opportunity through 5D Interpolation PSDM in The Sub-ophiolite Zone, Banggai Sula Basin, Central Sulawesi." In Indonesian Petroleum Association 44th Annual Convention and Exhibition. Indonesian Petroleum Association, 2021. http://dx.doi.org/10.29118/ipa21-g-147.
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In 2020, Pertamina EP made another gas discovery in Banggai-Sula Basin. However, the prediction missed the top of formation by several hundred meters and therefore increased the uncertainty in the actual amount of the discovered gas resources. The previous geological model was based on 3D Pre-Stack Depth Migrated seismic data from 2018. With only one well as data control, plus complex structure and the proximity to the Batui thrust, the velocity has not been modeled correctly. To reduce the uncertainty, a reprocessed seismic data is required to help building an updated geological model. The newly drilled well, WOL-002, provides new velocity information for PSDM reprocessing. It is however located below an ophiolite layer when signals are very weak. To improve the signal to noise ratio, a powerful yet time-consuming 5D Interpolation is employed. This step significantly improves image quality especially below the thrust. Since this project is tightly time constrained, a careful parameterization has been done for improving processing efficiency. As a result, the imaging can be finished ahead of schedule. Reflector’s depth is confirmed using not only velocity data from well W-20 but also from the neighboring field. New interpretation based on the 2020 reprocessing suggests a larger structure in the subsurface compared to the previous model. This newly processed 3D seismic is also used for identifying new prospect closer toward the thrust zones.
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Swanson, Theodore D., and Glen A. Robertson. "Space Exploration and the Greenland Norse; A Comparative Study on the Application of Technology for Exploration." In SPACE, PROPULSION & ENERGY SCIENCES INTERNATIONAL FORUM: SPESIF-2009. AIP, 2009. http://dx.doi.org/10.1063/1.3115547.
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Zudilova-Seinstra, Elena, Jean-Bernard Martens, and Tony Adriaansen. "Interactive data exploration and knowledge discovery." In the International Conference. New York, New York, USA: ACM Press, 2010. http://dx.doi.org/10.1145/1842993.1843099.
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Kellermann, Kenneth I., James M. Cordes, Ronald D. Ekers, Joseph Lazio, and P. Wilkinson. "The Exploration of the Unknown." In Accelerating the Rate of Astronomical Discovery. Trieste, Italy: Sissa Medialab, 2010. http://dx.doi.org/10.22323/1.099.0005.
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Cameron, Delroy, Pablo N. Mendes, Amit P. Sheth, and Victor Chan. "Semantics-empowered text exploration for knowledge discovery." In the 48th Annual Southeast Regional Conference. New York, New York, USA: ACM Press, 2010. http://dx.doi.org/10.1145/1900008.1900029.
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Frieder, Ophir. "Session details: Data exploration and discovery (KM)." In CIKM07: Conference on Information and Knowledge Management. New York, NY, USA: ACM, 2007. http://dx.doi.org/10.1145/3250805.
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Spurlock, Darren. "Space Exploration Systems Integration." In 1st Space Exploration Conference: Continuing the Voyage of Discovery. Reston, Virigina: American Institute of Aeronautics and Astronautics, 2005. http://dx.doi.org/10.2514/6.2005-2541.
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Ardanuy, Philip, Richard Boehne, James Head, Tim Howard, Nick Powell, and Scott Kulinski. "Antarctic Exploration: Proxy for Safe, Sustainable Exploration of the Moon and Mars." In 1st Space Exploration Conference: Continuing the Voyage of Discovery. Reston, Virigina: American Institute of Aeronautics and Astronautics, 2005. http://dx.doi.org/10.2514/6.2005-2506.
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Al-Bulushi, A. A. B., and M. E. S. Elshafie. "Using Stochastic Inversion for STOIIP Estimation of Sub-seismic Exploration Discovery." In Fourth EAGE Exploration Workshop. Netherlands: EAGE Publications BV, 2017. http://dx.doi.org/10.3997/2214-4609.201700219.
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Veas, Eduardo E. "From Search to Discovery with Visual Exploration Tools." In IUI'17: 22nd International Conference on Intelligent User Interfaces. New York, NY, USA: ACM, 2017. http://dx.doi.org/10.1145/3038462.3038872.
Full textReports on the topic "Norse Discovery and exploration"
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Lin, Xiao. Development and exploration of potential routes of discovery of new superconductors. Office of Scientific and Technical Information (OSTI), January 2013. http://dx.doi.org/10.2172/1226557.
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David Ebert, David Ebert. Looking for Lost Sharks: An Exploration of Discovery through the Western Indian Ocean. Experiment, June 2016. http://dx.doi.org/10.18258/7209.
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Frash, Luke, and Bulbul Ahmmed. GeoThermalCloud: A Machine Learning Tool for Discovery, Exploration, and Development of Hidden Geothermal Resources. Office of Scientific and Technical Information (OSTI), September 2023. http://dx.doi.org/10.2172/2007326.
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Lawley, C. J. M., and B A Kjarsgaard. Bottom-up mineral exploration: ore-element upgrading in the upper mantle and tools for its discovery. Natural Resources Canada/ESS/Scientific and Technical Publishing Services, 2020. http://dx.doi.org/10.4095/323674.
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Mukherjee, S., M. Lisa, H. Petersen, M. Stephanov, and P. Sorensen. Proceedings of RIKEN BNL Research Center Workshop: Theory and Modeling for the Beam Energy Scan: From Exploration to Discovery. Office of Scientific and Technical Information (OSTI), March 2015. http://dx.doi.org/10.2172/1188213.
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Wagner, Daniel. The Ocean Exploration Trust 2023 Field Season. Ocean Exploration Trust, April 2024. http://dx.doi.org/10.62878/vud148.
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This annual report marks the fifteenth year anniversary of Ocean Exploration Trust’s (OET) E/V Nautilus exploring poorly known parts of our global ocean in search of new discoveries. Since its first season in 2009, E/V Nautilus has conducted a total of 158 expeditions that explored our ocean throughout the Black Sea, Mediterranean, Atlantic, Caribbean, and Pacific for a total of 1,970 days at sea (~5.5 years). These scientific expeditions included a total of 1,017 successful ROV dives, as well as mapped over 1,053,000 km2 of seafloor. The results of these exploratory expeditions have been summarized in over 300 peer-reviewed scientific publications covering a wide range of scientific disciplines, including marine geology, biology, archaeology, chemistry, technology development, and the social sciences. Throughout its 15-year history, E/V Nautilus has been not only a platform for ocean exploration and discovery, but also an inclusive workspace that has provided pathways for more people, especially those early in their careers, to experience and enter ocean exploration professions. It has also catalyzed numerous technological innovations, multi-disciplinary collaborations, and inspired millions through OET’s extensive outreach initiatives. The 2023 field season was no exception, with E/V Nautilus undertaking 12 multi-disciplinary expeditions that explored some of the most remote and poorly surveyed areas in the Pacific, all of which included numerous activities to share expedition stories with diverse audiences across the globe.
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Vesselinov, Velimir. Cloud Fusion of Big Data and Multi-Physics Models using Machine Learning for Discovery, Exploration and Development of Hidden Geothermal Resources. Office of Scientific and Technical Information (OSTI), April 2021. http://dx.doi.org/10.2172/1781345.
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Frash, Luke, Bulbul Ahmmed, Maruti Mudunuru, and Daniel Tartakovsky. GeoThermalCloud: Cloud Fusion of Big Data and Multi-Physics Models using Machine Learning for Discovery, Exploration, and Development of Hidden Geothermal Resources. Office of Scientific and Technical Information (OSTI), February 2024. http://dx.doi.org/10.2172/2290287.
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Houlé, G., H. L. Gibson, L. Richan, V. Bécu, D. Corrigan, and L. Nadeau. A new nickel discovery in the Prince Albert Hills, Melville Peninsula, Nunavut: implications for Ni-Cu-(PGE) exploration in the Prince Albert Group. Natural Resources Canada/ESS/Scientific and Technical Publishing Services, 2010. http://dx.doi.org/10.4095/287185.
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Houlé, G., H. L. Gibson, L. Richan, V. Bécu, D. Corrigan, and L. Nadeau. A new nickel discovery in the Prince Albert Hills, Melville Peninsula, Nunavut: implications for Ni-Cu-(PGE) exploration in the Prince Albert Group. Natural Resources Canada/ESS/Scientific and Technical Publishing Services, 2012. http://dx.doi.org/10.4095/291526.
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