Academic literature on the topic 'Southern and Atlantic Telegraph Company'

This article discusses how the invention of the telegram revolutionized the communication process in the mid-19th century. On August 15, 1858, Queen Victoria sent a telegram to President Buchanan. It was a joint American and British effort, spearheaded from the American side by an indefatigable financier, Cyrus West Field, and on the British side by a telegraph company. The message of 98 words took sixteen and a half hours to transmit. The cable that carried Victoria’s message was laid in two sections beginning from a rendezvous point in mid-Atlantic. Two converted battleships spliced their cargoes and parted laying cable; the Agamemnon provided by the British government steered east to Ireland, and the American Niagara west to Newfoundland. Before this cable was laid, there was no direct communication between continents. No message could travel faster than the fastest steamships, which required at least 10 days to make the sea voyage between America and Europe. The submarine telegraph cable reduced communication time from days to hours.

ABSTRACT Texaco Brazil S.A. (TBSA), a ChevronTexaco Company, is a far reaching operation consisting of ten company owned bulk plants and one joint venture/company operated bulk plant. Five of these bulk plants are located in the southern half of the Country and are not near any major bodies of water. The other six bulk plants, including the joint venture facility, are located in the northern half of the Country either within the Amazon Basin or on the Atlantic coast: All have waterfront transfer operations. (See Figures 1 and 2) In addition, TBSA transports product, including heavy fuel oil, upon the Amazon River system using third party bulk barges. This paper examines the systematic process being used by TBSA Health, Environment & Safety (HES) personnel to develop and implement an improved emergency response program. The paper concentrates on the six bulk plants with waterfront transfer operations; however the program covers all facilities.

This article explores the intellectual origins of the Anglo-Dutch Caribbean by focusing on the Leiden humanist Johannes de Laet (1581–1649). De Laet, born in the Southern Netherlands, had strong religious and kinship ties to the London merchant community. In the early 1620s, when he became one of the founding directors of the Dutch West India Company, his extensive intelligence network enabled him to develop into the leading chronicler of Dutch ambitions and achievements in the Atlantic world. De Laet's two main publications are contemporary masterpieces, but they are surprisingly underrepresented in current scholarship in Atlantic history, even though they are at the roots of the sugar and slave societies that the English established on Barbados and across the Caribbean from the 1640s onwards. English diplomats and intellectuals recognized the significance of De Laet's ideas. In September 1641, on the eve of the Civil War, Parliament invited the Leiden humanist to Westminster to instruct them in matters of trade and colonisation in the Western hemisphere.

Long before I had the pleasure of making his acquaintance in person, John Hope Franklin's writings were a vital presence in my academic life. His books were some of the earliest sign posts that I encountered when I first ventured into the new and unfamiliar territory of the historian. The Free Negro in North Carolina was critical to the framework of my first research paper in graduate school. The Militant South was required reading in C. Vann Woodward's reading and discussion seminar in Southern history. I turned to Reconstruction: After the Civil War hoping that it would help me put limits to the deepening puzzles of Reconstruction. But perhaps none of these works—important as they are—has influenced the historical imagination as profoundly as what is undoubtedly his most widely read work, From Slavery to Freedom: A History of Negro Americans, first published in 1947. It kept me company over an anxious winter when I prepared for oral exams. I adopted its fifth edition as required reading in the first course that I taught as a graduate student. Known to general and academic readers alike, From Slavery to Freedom does not recount the progressive unfolding of an emancipatory project, even though its title early named what has become a theme central to analysis of the historical experiences of African Americans in the United States. Instead, it locates the emergence of a distinctively brittle racial regime in the United States within the complex contradictions of modern freedom that were set in motion by Atlantic slavery and the slave trade. “It was forces let loose by the Renaissance and the Commercial Revolution,” he writes, “that created the modern institution of slavery and the slave trade” (Franklin 1947, p. 43; 1980, p. 31). There are thus no postwar echoes of NATO triumphalism in Franklin's conception of Atlantic modernity:

Purpose: Global Climate Variability and Change are among environmental challenges with adverse consequences in the world. Their impacts include heightened temperatures, heightened or lowered rainfall and Relative Humidity. Those impacts depend on a place or how sensitive the people are. Examples of variations at the global scale which do influence local climate elements include: North Atlantic Oscillation (NOA), El Niño Southern Oscillation (ENSO), and Madden-Julian Oscillation. Lower Lake Victoria Basin (LLVB), Kenya was suspected to experience such variations differently due to varied altitudes. This study sought to investigate variability of selected climate elements in different altitudes of the LLVB, Kenya. Methodology: Meteorological data were obtained per county i.e. Migori - South Nyanza (SONY) Central Meteorological Station, Kisumu - Kisumu Airport Meteorological Station and Kakamega -Mumias Sugar Company (MSC) Meteorological Station. Data for the three selected climate parameters were collected for twenty years except Relative Humidity from Kisumu Airport which was available for only 12 years (2009-2020). ANOVA, Shapiro Wilk W test, Tukeys Honest Significance Difference (HSD) test, Time Series and Pearson’s Correlation Coefficient were used for analysis. Findings: The findings showed that the elements significantly varied: Temperature F = 120.87, P = 0.0001; rainfall (F = 24.56, P = 0.000 and Relative Humidity (RH) F = 30.37, P = 0.0001. Temperature means correlated with altitudes revealed a negative correlation (r = - 0.896). Extreme events were observed in rainfall. Unique Contribution to Theory, Policy and Practices: Extreme events of rainfall, increasing trends of selected climate parameters were observed in the study area. These were evidence that climate change has already become an aspect of concern in the study area. Impacts of such extreme events should be investigated to help construct mitigative and adaptive strategies which should be implemented early enough to prevent unwanted outcomes, otherwise similar investigations should be conducted to establish situations elsewhere at different altitudes.

O município de Pontal do Paraná está localizado no litoral do estado do Paraná, na região sul do Brasil. Em 1995, foi aí instalado o Porto de Pontal Importação e Exportação LTDA e, em 2013, foi aprovada a licença ambiental para a construção de um complexo portuário neste município. Tal obra se apresenta como um desafio, devido ao potencial que o mesmo apresenta em produzir impactos ambientais e mudanças nos padrões de uso da terra.Essa pesquisa objetiva analisar as mudanças espaciais que podem ocorrer futuramente no uso da terra e na cobertura vegetal em Pontal do Paraná (2032), em virtude da instalação deste complexo. Foram utilizadas rotinas de sistemas de informações geográficas, inseridas no IDRISI TAIGA, da Clark University, dentre elas se destacam a Cadeia de Markov e os Autômatos Celulares para a geração do cenário futuro. O resultado da modelagem preditiva (2032), em função da expansão portuária, foi um aumento nas áreas urbanas, fator que poderia impactar diretamente as áreas de Restingas, de Mangues e da Floresta Ombrófila Densa. O presente trabalho revelou que o uso da modelagem preditiva pode ser uma ferramenta bastante útil para a avaliação e interpretação de cenários futuros. Palavras-chave: Modelagem Preditiva; Ambiente Litorâneo; Dinâmica Espaço-Temporal. ANALYSIS OF SPACE VARIATIONS IN THE MUNICIPALITY OF PONTAL DO PARANÁ (PARANÁ - BRAZIL), BETWEEN 1980 AND 2032 ARISING FROM THE PORT COMPLEX INSTALLATION Abstract The city of Pontal do Paraná is located on the coast of the state of Paraná, in the southern region of Brazil. In 1995, the Port of Pontal Importação e Exportação Company was installed there, and in 2013, the environmental license was approved for the installation of a port complex in this municipality. This Port presents itself as a challenge, due to its potential in producing environmental impacts and changes in land use patterns. This research aims to analyze the spatial changes that may occur in the future of land use and vegetation cover of Pontal do Paraná (2032), due to the installation of this complex. Routines of geographic information systems, inserted in the IDRISI TAIGA, of Clark University, among them, the Markov Chain and the Cellular Automatics were used to generate the future scenario. The result of predictive modeling (2032), caused by the port expansion, was an increase in urban areas, a factor that could directly impact the areas of restingas, mangroves, and the atlantic rainforest. The present study revealed that the use of predictive modeling can be a very useful tool for the evaluation and interpretation of future scenarios. Keywords: Predictive Modeling; Coastal Environment; Spatio-Temporal Dynamics. ANÁLISIS DE LAS VARIACIONES ESPACIALES EN EL MUNICIPIO DE PONTAL DO PARANÁ (PARANÁ - BRASIL), ENTRE LOS AÑOS 1980 Y 2032 RESULTANTE DE LA INSTALACIÓN DEL COMPLEJO PORTUARIO Resumen El municipio de Pontal do Paraná está ubicado en la costa del estado de Paraná, en la región sur de Brasil. En 1995, se instaló el Puerto de Importación y Exportación de Pontal Ltd. y, en 2013, se aprobó el permiso ambiental para la construcción de un complejo portuario en este municipio. Esta obra se presenta como un desafío, debido a la posibilidad de producir impactos ambientales y cambios en los patrones de uso de la tierra. El objetivo de este estudio es analizar los cambios espaciales que puedan ocurrir en el futuro uso de la tierra y la vegetación en el Pontal do Paraná (2032), debido a la instalación de este complejo. Las rutinas se utilizan sistemas de información geográfica, insertado en el IDRISI TAIGA, Clark University, entre ellos se encuentran la Cadena de Markov y Autómatas Celulares para la generación de escenarios futuros. Los resultados de la modelización predictiva (2032), dependiendo de la expansión de lo puerto, fue un aumento en las zonas urbanas, un factor que podría tener un impacto directo sobre las áreas de Restinga, Manglares y Bosque Ombrophilous Denso. El presente estudio demostró que el uso de modelado predictivo puede ser una herramienta muy útil para la evaluación e interpretación de escenarios futuros. Palabras clave: Modelado Predictivo; Costero; Dinámica Espacio-Temporal.

Exploration for diamonds in West Greenland has experienced a major boost within the last decade following the establishment of world-class diamond mines within the nearby Slave Province of the Canadian Arctic. Numerous companies have active programmes of diamond exploration and increasingly larger diamonds have been discovered, notably a 2.392 carat dodecahedral stone recovered by the Canadian exploration company Hudson Resources Inc. in January 2007. The Geological Survey of Denmark and Greenland (GEUS) is currently carrying out several studies aimed at understanding the petrogenesis of diamondiferous kimberlites in Greenland and the physical and chemical properties of their associated mantle source regions (e.g. Hutchison 2005; Nielsen & Jensen 2005). Constraint of the mantle geotherm, i.e. the variation of temperature with depth for a particular mantle volume, is an important initial step in assessing the likelihood of such a volume to grow diamonds and hence the diamond potential of associated deep-sourced magmatic rocks occurring at surface. Cool geotherms are often present within old cratonic blocks such as West Greenland (Garde et al. 2000) and provide a good environment for the formation of diamonds (Haggerty 1986). This study aims to constrain the mantle geotherm for the southern extent of the North Atlantic Craton in Greenland by applying three-phase geothermobarometry calculations using chemical compositions of clinopyroxene, orthopyroxene and garnet from four-phase kimberlite-hosted lherzolite xenoliths. Xenoliths have been sampled from kimberlites from two areas in South-West Greenland: Midternæs and Pyramide- fjeld (Fig. 1). Kimberlites in the Pyramidefjeld area principally occur as sheeted sills hosted in the Pyramidefjeld granite complex of Palaeoproterozoic Ketilidian age. In contrast, Midternæs kimberlites occur as outcrops within a single, extensive and undulating sill hosted within pre-Ketilidian granodioritic gneiss and Ketilidian supracrustal rocks. Pyramidefjeld kimberlites have been shown to be Mesozoic (Andrews & Emeleus 1971), and work is currently being carried out to further constrain the ages of these and the Midternæs kimberlites and also xenoliths using modern methods. No attempt is made herein to provide a correct petrological classification of the rocks hosting the xenoliths; however, the abundance of clinopyroxene reported by Andrews & Emeleus (1971) suggests that further work may more correctly conclude a classification as ‘orangeite’ after Mitchell (1995). Notwithstanding this, the term ‘kimberlite’ is employed throughout in order to be consistent with that adopted by previous authors. The Precambrian Pyramide fjeld granite complex and adjacent Archaean granod ioritic gneisses are host to several kimberlite sheets located at various levels between 400 and 900 m elevation (Fig. 1A; Andrews & Emeleus 1971, 1975). Kimberlites are mainly found as loose blocks in scree; however, these are almost always sourced locally from in situ bodies. Sheets can often be found deep within overhanging clefts, particularly in granitic walls. The kimberlite bodies are gently dipping, typically 20 degrees, and with a range of strikes. The maximum thickness of sills is approximately 2 m but thickness varies significantly over short distances. In many instances, the occurrence of kimberlite is seen to be controlled locally by structures in the country rocks. Field observations of the range of orientations of intrusive bodies do not appear to suggest a particular focal point which could be a likely location for an intrusive centre such as a pipe. This observation is in line with what is seen throughout West Greenland where kimberlite emplacement appears as dykes and sills (Larsen & Rex 1992) rather than the pipes and blows which are common in other world-wide settings. The occurrence of xenoliths amongst Pyramidefjeld kimberlites is highly variable with the most xenolith-rich localities being in the vicinity of Safirsø (Fig. 1A). The majority of xenoliths are dunites with occasional wehrlites and lherzolites (Emeleus & Andrews 1975). Of particular interest from the point of view of thermobarometry is the occurrence of garnet. This is rarely found, even in clinopyroxene-bearing samples, and the two samples chosen for thermobarometry (Fig. 1A) represent the majority of the garnet-bearing xenoliths identified within an estimated total population of 75 xenoliths collected. The Midternæs kimberlites are hosted in Archaean gneisses and Proterozoic supracrustal rocks (Fig. 1B; Andrews & Emeleus 1971, 1975). The style of kimberlite emplacement and occurrence of garnet-bearing xenoliths are closely similar to those of Pyramidefjeld. Contours of elevation between outcrops suggest that the kimberlites form parts of a largely contiguous single body dipping at approximately 30 degrees to the west-south-west. Individual outcrops as in Pyramidefjeld indicate that the body varies in thickness and undulates in response to local structure. The south-western portion of the body which outcrops near the glacier Sioralik Bræ, is considerably thicker than elsewhere (Fig. 2) and in some places is seen to have a true thickness in excess of 4 m. Xenoliths are less abundant on average than in Pyramidefjeld kimberlites, but a similar variety and proportion of rock types and infrequent occurrence of garnet is observed. The kimberlites from both areas were intruded along zones of platy jointing which likely were caused by degassing of the magma and formed just prior to the kimberlite intrusion. In contrast to some kimberlites in other cratons, very few xenoliths of local, lower crustal rock types have been recognised in the kimberlites from Pyramidefjeld and Mid ternæs. The intrusions are therefore believed to have been of a non-explosive nature, perhaps because of host-rock rheol - ogy or due to emplacement at relatively deep crustal levels. Here we report on calculations of equilibrium pressure and temperature using compositions of three-phase assemblages of garnet, orthopyroxene and clinopyroxene from Midternæs and Pyramidefjeld mantle xenoliths.

Eni Starts Area 1 Production off Mexico via MODEC FPSO MODEC said first oil has flowed through FPSO MIAMTE MV34 operating in the Offshore Area 1 block in the Bay of Campeche off Mexico. The contractor was appointed by Eni Mexico for the supply, charter, and operation of the FPSO in the Eni-operated Offshore Area 1 block in 2018. The charter contract will run for an initial 15 years, with options for extension every year thereafter up to 5 additional years. Moored in a water depth of approximately 32 m some 10 km off Mexico’s coast, the FPSO is capable of handling 90,000 B/D of oil, 75 MMcf/D of gas, and 120,000 B/D of water injection with a storage capacity of 700,000 bbl of oil. The FPSO boasts a disconnectable tower yoke mooring system, a first-of-its-kind design in the industry. The system was developed to moor the FPSO in shallow water, while also allowing the unit to disconnect its mooring and depart the area to avoid winter storms and hurricanes in the Gulf of Mexico. The mooring system was developed by MODEC subsidiary SOFEC Inc. The mooring jacket was fabricated in Altamira, Mexico. Eni Starts Production from Ndungu EP Development Italy’s Eni has started production from the Ndungu Early Production (EP) development in Block 15/06 of the Angolan deep offshore, via the Ngoma FPSO. With an expected production rate in the range of 20,000 B/D, the project will sustain the plateau of the Ngoma, a 100,000-B/D, zero-discharge, and zero-process-flaring FPSO, upgraded in 2021 to minimize emissions. A further exploration and delineation campaign will be performed in Q2 2022 to assess the full potential of the overall assets of Ndungu. Ndungu EP is the third startup achieved by Eni Angola in Block 15/06 in the past 7 months, after Cuica Early Production and the Cabaca North Development Project. Block 15/06 is operated by Eni Angola with a 36.84% share. Sonangol Pesquisa e Produção (36.84%) and SSI Fifteen Ltd. (26.32%) comprise the rest of the joint venture. Aramco Discovers Natural Gas in Four Regions Saudi Aramco has discovered natural gas fields in four regions of the kingdom, the Saudi Press Agency (SPA) reported, citing Energy Minister Prince Abdulaziz bin Salman. The fields were found in the Empty Quarter desert located in the central area of the kingdom, near its northern border and in the eastern region, he said, according to SPA. Saudi Arabia wants to increase gas production and boost the share of natural gas in its energy mix to meet growing electricity consumption and to make more crude available for export. The minister said an unspecified number of fields were discovered and he mentioned five by name: Shadoon, in the central region; Shehab and Shurfa, in the Empty Quarter in the southeastern region; Umm Khansar, near the northern border with Iraq; and Samna in the eastern region. Two of the gas fields, Samna and Umm Khansar, were said to be “nonconventional” and possibly shale finds. Lukoil Completes Area 4 Deal in Mexico Russian producer Lukoil has completed a deal to become a lead stakeholder in an Area 4 shallow-water asset adjacent to Tabasco and Campeche in Mexico. Under the deal, Lukoil has acquired a 50% stake in the asset from US independent Fieldwood Energy, which filed for US bankruptcy protection in August 2020, for $685 million. The original deal was priced at $435 million; the additional $250 million is related to expenditures Fieldwood incurred since 1 January 2021. Fieldwood committed to invest $477 million to increase oil production from the Ichalkil and Pokoch fields from the current level of 25,000 B/D to a plateau level of 115,000 B/D. Situated in water depths between 35 and 45 m, the fields’ recoverable hydrocarbon reserves amount to 564 million BOE, more than 80% of which is crude oil. Production started in Q4 2021; current average oil production has exceeded 25,000 B/D. The approved work program includes drilling three development wells (two on Ichalkil and one on Pokoch), upgrading three production platforms, and performing seismic reprocessing and petrophysical studies. The remaining 50% stake in Area 4 is held by operator PetroBal, a subsidiary of Mexico’s GrupoBal. Petrobras Sells Polo Norte Capixaba Field Cluster In line with its strategy to concentrate resources on deepwater and ultradeepwater assets, Brazil’s Petrobras has sold 100% of its interest in Norte Capixaba cluster to Seacrest Exploração e Produção de Petróleo Ltda for $544 million, including a $66-million contingent payment. The cluster comprises four producing fields—Cancã, Fazenda Alegre, Fazenda São Rafael, and Fazenda Santa Luzia—and produced 6,470 BOE/D in 2021. The deal also includes the Norte Capixaba Terminal (TNC) and all production facilities. NewMed Targets Morocco Market Entry Israel-based NewMed Energy, formerly Delek Drilling, has identified Morocco as “a country with enormous geological and commercial potential,” in particular the Moroccan coastal areas in the Mediterranean and North Atlantic. The announcement comes a day after the Moroccan Minister of Industry and Trade, Ryad Mezzour, and his Israeli counterpart, Orna Barbivai, signed an MOU aimed at promoting investments and exchanges between the two countries in the digital design, food, automotive, aviation, textile, water technologies and renewable energies, medical equipment, and the pharmaceutical industries. In September 2021, the Israeli oil and gas exploration company obtained from the Moroccan ministry the exploration and study rights of the Dakhla Atlantic Block, which has an area of about 109000 km2. ExxonMobil Sells Nigerian Assets to Seplat ExxonMobil has agreed to sell its shallow-water assets in Nigeria to Seplat Energy for $1.28 billion plus a contingent consideration of $300 million. Seplat said it is acquiring a 40% operating stake in four oil leases to nearly triple its annual net production to 146,000 BOE/D. The deal also includes the Qua Iboe export terminal and a 51% interest in the Bonny River Terminal and natural gas liquids recovery plants at EAP and Oso. It does not include any of ExxonMobil’s deepwater fields in Nigeria. TotalEnergies Discovers Large Oil Field off Namibia TotalEnergies has made a significant discovery of light oil with associated gas on the Venus prospect, located in block 2913B in the Orange Basin, offshore southern Namibia. The Venus 1-X well encountered approximately 84 m of net oil pay in a good-quality Lower Cretaceous reservoir. The find’s potential reserves are estimated at 2 billion bbl of oil. “This discovery offshore Namibia and the very promising initial results prove the potential of this play in the Orange Basin, on which TotalEnergies owns an important position both in Namibia and South Africa,” said Kevin McLachlan, senior vice president exploration at TotalEnergies. “A comprehensive coring and logging program has been completed. This will enable the preparation of appraisal operations designed to assess the commerciality of this discovery.” Block 2913B covers approximately 8215 km2 in deep offshore Namibia. TotalEnergies is the operator with a 40% working interest, alongside QatarEnergy (30%), Impact Oil and Gas (20%), and NAMCOR (10%). CNPC Scoops Ishpingo Drilling Contract The first drilling contract at the Ishpingo oil field near Ecuador’s Yasuni National Park has been awarded to China National Petroleum Corp. (CNPC), Energy Minister Juan Carlos Bermeo told Reuters. Following the approval of a new hydrocarbon law and legislation, Ecuador plans to move forward with auctions and competitive processes for securing foreign and domestic capital for oil and gas exploration, production, transportation, and refining projects. The first drilling campaign to start after an environmental license was granted for the sensitive area will involve 40 wells over the next 18 months. It will focus on the field’s allowed zone without touching an area protected by a court ruling that has prevented extending drilling. Ishpingo is the latest part of the ITT-43 oil field in Ecuador’s Amazonia region to start drilling after Tambococha and Tiputini. It is expected to produce heavy oil to be added to the nation’s output of flagship Napo crude, Bermeo said. BP Brings Hershel Expansion Project On Line in US GOM BP has successfully started production from the Herschel Expansion project in the Gulf of Mexico—the first of four major projects scheduled to be delivered globally in 2022. Phase 1 comprises development of a new subsea production system and the first of up to three wells tied to the Na Kika platform in the Mississippi Canyon area. At its peak, this first well is expected to increase platform annual gross production by an estimated 10,600 BOE/D. The BP-operated well was drilled to a depth of approximately 19,000 ft and is located southeast of the Na Kika platform, approximately 140 miles off the coast of New Orleans. The project provides infrastructure for future well tie-in opportunities. BP and Shell each hold a 50% working interest in the development. Petrobras Kicks off Gulf of Mexico Asset Sales Petrobras has begun an asset sale program in the Gulf of Mexico, in line with the company’s strategy of debt reduction and pivot toward Brazilian deepwater production. The package for sale includes the company’s 20% stake in MP Gulf of Mexico (MPGoM) which holds ownership stakes in 15 fields in partnership with Murphy Oil. In addition to partnership-operated fields, MPGoM owns nonoperated interests in Occidental’s Lucius, Kosmos’ Kodiak, Shell’s Habanero, and Chevron’s St. Malo fields. During the first half of 2021, Petrobras’ share of production was 11,300 BOE/D. ExxonMobil Liza Phase 2 Underway off Guyana ExxonMobil started production of Liza Phase 2, Guyana’s second offshore oil development on the Stabroek Block; total production capacity is now more than 340,000 B/D in the 7 years since the country’s first discovery. Production at the Liza Unity FPSO is expected to reach its target of 220,000 bbl of oil later this year. The Stabroek Block’s recoverable resource base is estimated at more than 10 billion BOE. The current resource has the potential to support up to 10 projects. ExxonMobil anticipates that four FPSOs with a capacity of more than 800,000 B/D will be in operation on the block by year-end 2025. Payara, the third project in the block, is expected to produce approximately 220,000 BOPD using the Prosperity FPSO vessel, currently under construction. The field development plan and application for environmental authorization for the Yellowtail project, the fourth project in the block, have been submitted for government and regulatory approvals. The Liza Unity arrived in Guyana in October 2021. It is moored in water depth of about 1650 m and will store around 2 million bbl of crude. ExxonMobil affiliate Esso Exploration and Production Guyana Ltd. is the operator and holds 45% interest. Hess Guyana Exploration Ltd. holds 30% interest and CNOOC Petroleum Guyana Ltd. holds 25%. Dragon Finds Oil in Gulf of Suez UAE’s Dragon Oil has discovered oil in the Gulf of Suez, according to a statement from the Egyptian Minister of Petroleum and Mineral Resources. The field contains potential reserves of around 100 million bbl inside the northeastern region of Ramadan. That estimate makes it one of the largest oil finds in the region over the past 2 decades. Development plans were not reported but reserve numbers could expand, the ministry said. The oil field is the first discovery by Dragon Oil since it acquired 100% of BP’s Gulf of Suez Petroleum assets in 2019. Dragon Oil, wholly owned by Emirates National Oil Co., holds 100% interest in East Zeit Bay off the southern Gulf of Suez region. The 93-km2 block lies in shallow waters of 10 to 40 m.

Sonadrill Lands Contract for Drillship Seadrill confirmed a new contract has been secured by Sonadrill Holding, Seadrill’s 50:50 joint venture with an affiliate of Sonangol for the drillship West Gemini. Sonadrill has secured a 10‑well contract with options for up to eight additional wells in Angola for an unknown operator. Total contract value for the firm portion of the deal is expected to be around $161 million, with further revenue potential from a performance bonus. The rig is expected to begin the work in the fourth quarter of this year with a firm term of about 18 months, in direct continuation of the West Gemini’s existing contract. The West Gemini is the third drillship to be bareboat chartered into Sonadrill, along with two Sonangol‑owned units, the Sonangol Quenguela and Sonangol Libongos. Seadrill will manage and operate the units on behalf of Sonadrill. Together, the three units position the Seadrill joint venture as an active rig operator in Angola, furthering the goal of building an ultradeepwater franchise in the Golden Triangle and driving efficiencies from rig clustering in the region. Petrobras Receives TotalEnergies, Shell Payments for Atapu TotalEnergies and Shell have formalized payments to Petrobras for separate, minority stakes in the pre‑salt Atapu field in the Santos Basin. TotalEnergies paid $4.7 billion reais ($940 million) while Shell paid closer to $1.1 billion. The Atapu block was acquired by the consortium comprising Petrobras (52.5%), Shell (25%), and TotalEnergies (22.5%) in the Second Bidding Round for the Transfer of Rights auction held 17 December 2021. The payments are compensation for monies spent thus far by Petrobras, which was granted contractual rights to produce 550 million BOE from Atapu in 2010. The partners will now work together to produce additional volumes from the field. Production at Atapu started in June 2020 via the P-70 FPSO. The unit is in about 2000 m of water and has the capacity to produce 150,000 BOED. CNOOC Brings New Bohai Sea Discoveries On Stream CNOOC Limited has kicked off production from its Luda 5‑2 oil field North Phase I project and Kenli 6‑1 oil field 4‑1 Block development project. Luda 5‑2 is in the Liaodong Bay of Bohai Sea, with average water depth of about 32 m and utilizes a thermal recovery wellhead platform and production platform tied into the Suizhong 36‑1 oil field. A total of 28 development wells are planned, including 26 production wells and two water‑source wells. The project is expected to reach its peak production of 8,200 B/D of oil in 2024. Kenli 6‑1 is in the south of Bohai Sea, with average water depth of about 17 m. The resource is being developed by a wellhead platform in addition to fully utilizing the existing processing facilities of the Bozhong 34‑9 oil field. A total of 12 development wells are planned, including seven production wells and five water‑injection wells. The field is expected to reach its peak production of 4,000 B/D of oil later this year. CNOOC Limited is operator and sole owner of the Luda 5‑2 oil field North and the Kenli 6‑1 oil field 4‑1 Block. Stabroek Block Bounty Off Guyana Gets Bigger The partners in the prolific Stabroek Block have again increased the gross discovered recoverable resource estimate for the area offshore Guyana. The owners now believe they have discovered reserves of at least 11 billion BOE, up from the previous estimate of more than 10 billion BOE. The updated resource estimate includes three new discoveries on the block at Barreleye, Lukanani, and Patwa in addition to the Fangtooth and Lau Lau discoveries announced earlier this year. The Barreleye‑1 well encountered approximately 70 m of hydrocarbon‑bearing sandstone reservoirs of which 16 m is high‑quality oil‑bearing. The well was drilled in 1170 m of water and is located 32 km southeast of the Liza field. The Lukanani‑1 well encountered 35 m of hydrocarbon‑bearing sandstone reservoirs of which approximately 23 m is high‑quality oil‑ bearing. The well was drilled in water depth of 1240 m and is in the southeastern part of the block, approximately 3 km west of the Pluma discovery. The Patwa‑1 well encountered 33 m of hydrocarbon‑bearing sandstone reservoirs. The well was drilled in 1925 m of water and is located approximately 5 km northwest of the Cataback‑1 discovery. “These new discoveries further demonstrate the extraordinary resource density of the Stabroek Block and will underpin our queue of future development opportunities,” said John Hess, chief executive of Hess and a partner in Stabroek. The co‑venturers have sanctioned four developments to date on Stabroek with both Liza and Liza Phase 2 on stream. The third planned development at Payara is ahead of schedule and is now expected to come on line in late 2023; it will utilize the Prosperity FPSO with a production capacity of 220,000 BOPD. The fourth development, Yellowtail, is expected to come on line in 2025, utilizing the ONE GUYANA FPSO with a production capacity of 250,000 BOPD of oil. At least six FPSOs with a production capacity of more than 1 million gross BOPD are expected to be on line on the Stabroek Block in 2027, with the potential for up to ten FPSOs to develop gross discovered recoverable resources. The Stabroek Block is 6.6 million acres. ExxonMobil affiliate Esso Exploration and Production Guyana Limited is operator and holds 45% interest; Hess Guyana Exploration holds 30% interest; and CNOOC Petroleum Guyana Limited holds 25%. ConocoPhillips Gets Ekofisk License Extension Norway’s Ministry of Petroleum and Energy (MPE) has extended production licenses in the Greater Ekofisk Area from 2028 to 2048 with ConocoPhillips as operator. The company said the license extension provides long‑term operations and resource management aligned with the company’s long‑term perspective on the Norwegian continental shelf. Fields on the shelf are required to operate with a valid production license where the operator and licensees enter into an agreement with the authorities, including relevant field activities. The authorities may require commitments, leading to increased oil recovery. The existing production licenses 018, 018 B, and 275 in the Greater Ekofisk Area were set to expire on 31 December 2028; however, the MPE approved an extension through 2048. The new terms provide a potential for extending Ekofisk’s lifetime to nearly 80 years. The license partners are ConocoPhillips (operator, 35.11%), TotalEnergies EP Norge (39.896%), Vår Energi (12.388%), Equinor (7.604%), and Petoro (5%). BHP’s Wasabi Disappoints in US GOM Australian operator BHP encountered noncommercial hydrocarbons with its Wasabi‑2 well in the US Gulf of Mexico. BHP said the well in Green Canyon Block 124 was plugged and abandoned following the disappointing results. “This completes the Wasabi exploration program, with results under evaluation to determine next steps,” the company said. The well was targeting oil in an early Miocene reservoir. Transocean drillship Deepwater Invictus spudded the well in 764 m of water in November 2021. The previous Wasabi‑1 well had a mechanical problem and was plugged and abandoned 4 days earlier, prior to reaching its prospective targets. BHP operates Wasabi with a 75% interest. Lukoil Says Titonskaya Holds 150 Million BOE Russia’s Lukoil believes it has discovered around 150 million BOE following analysis of the two wells it drilled at the Titonskaya structure on the Caspian Sea shelf. Work is now underway to refine the seismic models of productive deposits and study deep samples of formation fluids. The results of the assessment will be submitted to the State Reserves Commission of the Russian Federation. The structure is in the central part of the Caspian Sea, not far from the Khazri field. Lukoil drilled the first well at the Titonskaya structure in 2020 and announced the new discovery in April 2021. According to that assessment, the probable geological resources of the Titonskaya are 130.4 million tons. In 2021, drilling of the second prospecting and appraisal well began to identify oil and gas deposits in the terrigenous‑carbonate deposits of the Jurassic‑ Cretaceous age. The well was drilled using the Neptune jackup drilling rig. The new find at Titonskaya will likely be tied into Khazri infrastructure. Petrobras’ Roncador IOR Project Comes On Line Petrobras has successfully started production from the first two wells of the improved oil recovery (IOR) project at the Roncador field in the Campos Basin offshore Brazil. The two wells are the first of a series of IOR wells to reach production. Startup is almost 5 months ahead of schedule and at half of the planned cost, according to partner Equinor. The wells will add a combined 20,000 BOED to Roncador, bringing daily production to around 150,000 bbl and reducing the carbon intensity (emissions per barrel produced) of the field. Through this first IOR project, the partnership will drill 18 wells that are expected to provide additional recoverable resources of 160 million bbl. Improvements in well design and the partners’ combined technological experience are the main drivers behind the 50% cost reduction across the first six wells, including the two in production. Roncador is Brazil’s fifth‑largest producing asset and has been in production since 1999. Petrobras operates the field and holds a 75% stake. In 2018, Equinor entered the project as a strategic partner with the remaining 25% interest. In addition to the planned 18 IOR wells, the partnership believes it can further improve recovery and aims to increase recoverable resources by a total of 1 billion BOE. The field has more than 10 billion BOE in place under a license lasting until 2052. The strategic alliance agreement also includes an energy‑efficiency and CO2‑emissions‑reduction program for Roncador. Gazania-1 To Spud Off South Africa Africa Energy will move ahead with its planned Gazania‑1 wildcat well offshore South Africa after securing partner Eco Atlantic’s $20 million in capital requirements for its portion of the probe. The well will be drilled in Block 2B. Island Drilling semisubmersible Island Innovator has been contracted for the work and is expected to mobilize from its current location in the North Sea for the 45‑day trip to South Africa. The Block 2B joint venture plans to spud the well by October with drilling expected to last 30 days, including a full set of logs if the well is successful. The block has significant contingent and prospective resources in relatively shallow water and contains the A‑J1 discovery that flowed light sweet crude oil to surface. Gazania‑1 will target two large prospects 7 km updip from A‑J1 in the same region as the recent Venus and Graff discoveries. Block 2B is located offshore South Africa in the Orange Basin where both TotalEnergies and Shell recently announced significant oil and gas discoveries offshore Namibia. The block covers 3062 km2 approximately 25 km off the west coast of South Africa near the border with Namibia in water depths ranging from 50 m to 200 m. The Southern Oil Exploration Corp. (Soekor) discovered and tested oil on Block 2B in 1988 with the A‑J1 borehole, which intersected thick reservoir sandstones between 2985 m and 3350 m. The well flowed 191 B/D of 36 °API oil from a 10‑m sandstone interval at around 3250 m. Africa Energy has a 27.5% interest in Block 2B offshore South Africa. The block is operated by a subsidiary of Eco Atlantic which holds a 50% interest. A subsidiary of Panoro Energy holds a 12.5% stake, and Crown Energy AB indirectly holds the remaining 10%. Brazil Grants New Exploration Blocks Brazil’s National Agency of Petroleum, Natural Gas, and Biofuels (ANP) has granted 59 exploratory blocks of oil and natural gas to 13 companies, including Shell, TotalEnergies, and 3R Petroleum. The awards were part of a permanent bid offer round held in Rio de Janiero in April. The auction totaled 422.4 million reais in signature bonuses with leases granted in six Brazilian states: Rio Grande do Norte, Alagoas, Bahia, Espírito Santo, Santa Catarina, and Paraná. The awards will result in investments of 406.3 million reais in the exploratory phase of the contracts. Shell Brazil (70%) was granted six blocks in the Santos Basin in a consortium with the Colombian Ecopetrol (30%). The blocks leases were SM‑1599, SM‑1601, SM‑1713, SM‑1817, SM‑1908, and SM‑1910. TotalEnergies won two areas in the same basin while Brazilian company 3R Petroleum received six areas in the Potiguar Basin. Petro‑Victory was also awarded 19 new blocks in Potiguar, increasing its holdings in Brazil to 38 blocks (37 in Potiguar). The new blocks are nearby Petro‑Victory infrastructure at the Andorinha, Alto Alegre, and Trapia oil fields. Eni Finds More Oil in Egypt’s Western Desert Eni struck new oil and gas reserves with a trio of discoveries in the Meleiha concessions of Egypt’s Western Desert. The finds have already been tied into existing infrastructure in the region and have added around 8,500 BOED to overall production from the area. The operator drilled the Nada E Deep 1X well, which encountered 60 m of net hydrocarbon pay in the Cretaceous‑Jurassic Alam El Bueib and Khatatba formations Meleiha SE Deep 1X well, which found 30 m of net hydrocarbon pay in the Cretaceous‑Jurassic sands of the Matruh Khatatba formations, and the Emry Deep 21 well, which encountered 35 m of net hydrocarbon pay in the massive cretaceous sandstones of Alam El Bueib. The results, added to the discoveries of 2021 for a total of eight exploration wells, give Eni a 75% success rate in the region. The company added that additional exploration activities in the concession are ongoing with “promising indications.” With these discoveries, Eni, through AGIBA, a joint venture between Eni and EGPC, continues to pursue its near‑field strategy in the mature basin of the Western Desert, aimed at maximizing production by containing development costs and minimizing time to market. Eni is planning a new high‑resolution 3D seismic survey in the Meleiha concession this year to investigate the gas potential of the area. Eni is currently the leading producer in Egypt with an equity production of around 360,000 BOED.

Humans have altered marine ecosystems over very long-time scales and historical data is often needed to understand the true magnitude of human impacts. The Southwest Atlantic Ocean has a long history of large-scale removal of marine vertebrates due to whaling, sealing, and fishing in the past three centuries. Historical catch records are crucial in assessing the conservation status of these historically over-exploited populations and setting suitable recovery goals. However, several gaps in the history of exploitation of many populations limit our ability to judge recoveries success. This study examines the history of the Spanish fishing company, the Real Compañía Marítima (Royal Maritime Company), and reconstructs its catches of marine mammals in Patagonia and on the north coast of the Río de la Plata. The analysis of a wide range of historical sources reveals that, between the years 1790 and 1804, the Company extracted less than 100 southern right whales Eubalaena australis, some 200,000 South American fur seals Arctocephalus australis and South American sea lions Otaria flavescens, and a few southern elephant seals Mirounga leonina. Although the Company’s whale catch is negligible compared to that of other nations in the same whaling grounds, the amount of fur seals and sea lions removed from the ecosystem deserves attention. This historical survey provides us with the first estimate of the catches made by the Real Compañía Marítima. However, these figures only represent a small part of the extractive activities that took place in the region and further research is encouraged to assess the true dimension of human impacts on Southwest Atlantic ecosystems. The incorporation of retrospective data into ecological studies can be laborious and may have inherent biases, but it also provides valuable information for comprehending modern ecosystems and formulating appropriate conservation plans.

This chapter describes the economic, cultural, and demographic supports for the rise of flea markets during the interwar period. I introduce the duality of secondhand consumer motivations, as well as the contradictions of a perennial avant-garde adoration of used materials. The reframing of novelty to include the not-new was connected to, on one hand, transnational art movements tinged with political radicalism, such as Surrealism and Dada, and on the other, nostalgic sentimentalism forged by conservative patriotism, like that of automitive mogul-turned-collecter Henry Ford. While the growth of flea markets did rely on a broadening consumer market for secondhand goods, the forms and locations of the outdoor venues demonstrated the independent determination and entrepreneurialism of marginalized classes, especially immigrants and black southern migrants; xenophobia and antisemitism helped establish the locations and format of many urban flea markets. As chain grocery stores like the Great Atlantic & Pacific Tea Company (the A & P) replaced direct-to-consumer food distribution via farmer’s markets in the country and city-sanctioned public markets in urban areas, secondhand commodities filled in the gap, sustaining preexisting open-air venures.

Disease, we have argued, influenced patterns of colonization, especially in West Africa, the Americas, and Australia (Chapter 2). In turn, imperial transport routes facilitated the spread of certain diseases, such as bubonic plague. This chapter expands our discussion of environmentally related diseases by focusing on trypanosomiasis, carried by tsetse fly, in East and Central Africa. Unlike plague, this disease of humans and livestock was endemic and restricted to particular ecological zones in Africa. But as in the case of plague, the changing incidence of trypanosomiasis was at least in part related to imperialism and colonial intrusion in Africa. Coastal East Africa presented some of the same barriers to colonization as West Africa. Portugal maintained a foothold in South-East Africa for centuries, and its agents expanded briefly onto the Zimbabwean plateau in the seventeenth century, but could not command the interior. Had these early incursions been more successful, southern Africa may have been colonized from the north, rather than by the Dutch and British from the south. Parts of East Africa were a source of slaves and ivory in the eighteenth and early nineteenth centuries. The trading routes, commanded by Arab and Swahili African networks, as well as Afro-Portuguese further south, were linked with the Middle East and the Indian Ocean. In the early decades of the nineteenth century, slave-holding expanded within enclaves of East Africa, such as the clove plantations of Zanzibar. When Britain attempted to abolish the slave trade in the early nineteenth century, and policed the West African coast, East and Central African sources briefly became more important for the Atlantic slave trade. African slaves from these areas were taken to Latin America and the Spanish Caribbean. Britain did not have the same intensity of contact with East Africa as with West and southern Africa until the late nineteenth century. There was no major natural resource that commanded a market in Europe and British traders had limited involvement in these slave markets. But between the 1880s and 1910s, most of East and Central Africa was taken under colonial rule, sometimes initially as protectorates: by Britain in Kenya and Uganda; Germany in Tanzania; Rhodes’s British South Africa Company in Zimbabwe, Zambia, and Malawi; and by King Leopold of Belgium in the Congo.