Academic literature on the topic 'East Indians – Guyana'

[First paragraph]Transients to Settlers: The Experience of Indians in Jamaica 1845-J950. VERENE SHEPHERD. Leeds, U.K.: Peepal Tree Books, 1993. 281 pp. (Paper £12.95)Survivors of Another Crossing: A History of East Indians in Trinidad, 1880-1946. MARIANNE D. SOARES RAMESAR. St. Augustine, Trinidad and Tobago: U.W.I. School of Continuing Education, 1994. xiii + 190 pp. (Paper n.p.)Les Indes Antillaises: Presence et situation des communautes indiennes en milieu caribeen. ROGER TOUMSON (ed.). Paris: L'Harmattan, 1994. 264 pp. (Paper 140.00 FF)Nation and Migration: The Politics of Space in the South Asian Diaspora. PETER VAN DER VEER (ed.). Philadelphia: University of Pennsylvania Press, 1995. vi + 256 pp. (Cloth US$ 39.95, Paper US$ 17.95)In the decade since 1988, Caribbean nations with Indian communities have commemorated the 150th anniversary of the arrival of East Indians to the West Indies. These celebrations are part of local revitalization movements of Indian culture and identity stretching from the French departement of Guadeloupe in the Windward Islands to Trinidad and Guyana in the south. Political changes have mirrored the cultural revival in the region. While the debate so often in the past centered on the legitimacy of East Indian claims to local nationality in these societies where African or Creole cultures dominate, in the 1990s leaders of Indian descent were elected heads of government in the two Caribbean nations with the most populous East Indian communities: Cheddi Jagan as President of Guyana in October 1992 (after a 28-year hiatus) and Basdeo Panday as Prime Minister of Trinidad in November 1995. Both men have long been associated with their respective countries' struggles for economic, political, and social equality. Outside the region during the summer of 1997, fiftieth-anniversary celebrations marking the independence of India and Pakistan from Britain confirmed that Indo chic — or "Indofrenzy" as anthropologist Arjun Appadurai calls it (Sengupta 1997:13) - has captured the American imagination with the new popularity of literature, art, and film emanating from India and its diaspora.

This essay will act as an analysis of the Indo-Afro racial politics of two west Indian countries: Trinidad and Tobago, and Guyana. I will give the circumstances that led to the migration of large numbers of East Indians as indentured servants to Trinidad and Guyana, specifically. I will also explain how these conditions led to a distinct form of government and society. Through tables of electoral data in Trinidad, the racial voting patterns will be observed, and I will elaborate on how political parties do or do not pander to their respective racial communities. Finally, I will conclude by addressing how the racial divide in these two large Caribbean nations impact Caribbean regionalism on a larger scale.

<p>In addition to being remembered in what became known as the “Jonestown Massacre,” where more than 900 members of an American cult died in a mass suicide-murder under the direction of their leader in 1978, Guyana continues to receive global and local attention for the prevalence in suicide. The 2014 WHO report named Guyana as the country with the highest suicide rate per capita globally with recent suicide statistics showing 272 reports over a thirty-month period. <br />Recently, the incidence of murder suicide has gained a lot of media attention, and seems to be linked to “crimes of passion” or intimate partner conflict, with men very often being the perpetrators. Particularly, East Indian men and young men are more prone to commit suicide, Through the analysis of both police and media reports and other literature, this study uses mixed methodologies in analyzing the number of murder -suicide over the last five years, characteristics of the perpetrators inclusive of ethnicity, relationships between killers and victims and the method used in the deaths in Guyana. The study paves the way for more in-depth analysis of the phenomenon. Finally, the paper concludes with a presentation of its findings and possible recommendations.</p>

The population of the French Departments of the Americas (FDA) is highly influenced by the intense migratory flows with mainland France and surrounding countries of the Caribbean and Latin America, some of which have high incidence rates of tuberculosis (Haiti: 230/100,000; Guyana: 111/100,000; and Suriname: 145/100,000) and drug resistance. Since the development of drug resistance to conventional antituberculous drugs has a major impact on the treatment success of tuberculosis, we therefore decided to review carefullyMycobacterium tuberculosisdrug resistance and associated genotypic lineages in the FDA over a seventeen-year period (January 1995–December 2011). A total of 1239 cases were studied, including 153 drug-resistant and 26 multidrug-resistant- (MDR-) TB cases, representing 12.3% and 2.1% of the TB cases in our study setting. A significantly higher proportion ofM. tuberculosisisolates among relapse cases showed drug resistance to isoniazid (22.5%,P=0.002), rifampicin (20.0%,P<0.001), or both (MDR-TB, 17.5%;P<0.001). Determination of spoligotyping based phylogenetic clades showed that among the five major lineages observed—T family (30.1%); Latin-American and Mediterranean (LAM, 23.7%); Haarlem (H, 22.2%); East-African Indian (EAI, 7.2%); and X family (6.5%)—two lineages, X and LAM, were overrepresented in drug-resistant and MDR-TB cases, respectively. Finally, 19 predominant spoligotypes were identified for the 1239 isolates ofM. tuberculosisin our study among which 4 were significantly associated with drug resistance corresponding to SIT20/LAM1, SIT64/LAM6, SIT45/H1, and SIT46/undefined lineage.

-Lennox Honychurch, Robert L. Paquette ,The lesser Antilles in the age of European expansion. Gainesville: University Press of Florida, 1996. xii + 383 pp., Stanley L. Engerman (eds)-Kevin A. Yelvington, Gert Oostindie, Ethnicity in the Caribbean: Essays in honor of Harry Hoetink. London: Macmillan Caribbean, 1996. xvi + 239 pp.-Aisha Khan, David Dabydeen ,Across the dark waters: Ethnicity and Indian identity in the Caribbean. London: Macmillan Caribbean, 1996. xi + 222 pp., Brinsley Samaroo (eds)-Tracey Skelton, Ralph R. Premdas, Ethnic conflict and development: The case of Guyana. Brookfield VT: Ashgate, 1995. xi + 205 pp.-Rosemarijn Hoefte, Basdeo Mangru, A history of East Indian resistance on the Guyana sugar estates, 1869-1948. Lewiston NY: The Edwin Mellen Press, 1996. xiv + 370 pp.-Rosemarijn Hoefte, Clem Seecharan, 'Tiger in the stars': The anatomy of Indian achievement in British Guiana 1919-29. London: Macmillan, 1997. xxviii + 401 pp.-Brian Stoddart, Frank Birbalsingh, The rise of Westindian cricket: From colony to nation. St. John's, Antigua: Hansib Publishing (Caribbean), 1996. 274 pp.-Donald R. Hill, Peter van Koningsbruggen, Trinidad Carnival: A quest for national identity. London: Macmillan Caribbean, 1997. ix + 293 pp.-Peter van Koningsbruggen, John Cowley, Carnival, Canboulay and Calypso: Traditions in the making. Cambridge: Cambridge University Press, 1996. xv + 293 pp.-Olwyn M. Blouet, George Gmelch ,The Parish behind God's back : The changing culture of rural Barbados. Ann Arbor: University of Michigan Press, 1997. xii + 240 pp., Sharon Bohn Gmelch (eds)-George Gmelch, Mary Chamberlain, Narratives of exile and return. London: Macmillan, 1997. xii + 236 pp.-Michèle Baj Strobel, Christiane Bougerol, Une ethnographie des conflits aux Antilles: Jalousie, commérages, sorcellerie. Paris: Presses Universitaires de France, 1997. 161 pp.-Abdollah Dashti, Randy Martin, Socialist ensembles: Theater and state in Cuba and Nicaragua. Minneapolis: University of Minnesota Press, 1994. xii + 261 pp.-Winthrop R. Wright, Jay Kinsbruner, Not of pure blood: The free people of color and racial prejudice in nineteenth-century Puerto Rico. Durham NC: Duke University Press, 1996. xiv + 176 pp.-Gage Averill, Deborah Pacini Hernandez, Bachata: A social history of a Dominican popular music. Philadelphia PA: Temple University Press, 1995. xxiii + 267 pp.-Vera M. Kutzinski, Lorna Valerie Williams, The representation of slavery in Cuban fiction. Columbia: University of Missouri Press, 1994. viii + 220 pp.-Peter Mason, Elmer Kolfin, Van de slavenzweep en de muze: Twee eeuwen verbeelding van slavernij in Suriname. Leiden: Koninklijk Instituut voor Taal-, Land- en Volkenkunde, 1997. 184 pp.-J. Michael Dash, Jean-Pol Madou, Édouard Glissant: De mémoire d'arbes. Amsterdam: Rodopi, 1996. 114 pp.-Ransford W. Palmer, Jay R. Mandle, Persistent underdevelopment: Change and economic modernization in the West Indies. Amsterdam: Gordon and Breach, 1996. xii + 190 pp.-Ramón Grossfoguel, Juan E. Hernández Cruz, Corrientes migratorias en Puerto Rico/Migratory trends in Puerto Rico. Edición Bilingüe/Bilingual Edition. San Germán: Caribbean Institute and Study Center for Latin America, Universidad Interamericana de Puerto Rico, 1994. 195 pp.-Gert Oostindie, René V. Rosalia, Tambú: De legale en kerkelijke repressie van Afro-Curacaose volksuitingen. Zutphen: Walburg Pers, 1997. 338 pp.-John M. Lipski, Armin J. Schwegler, 'Chi ma nkongo': Lengua y rito ancestrales en El Palenque de San Basilio (Colombia). Frankfurt: Vervuert, 1996. 2 vols., xxiv + 823 pp.-Umberto Ansaldo, Geneviève Escure, Creole and dialect continua: Standard acquisition processes in Belize and China (PRC). Amsterdam: John Benjamins, 1997. ix + 307 pp.

-James Sidbury, Peter Linebaugh ,The many-headed Hydra: Sailors, slaves, commoners, and the hidden history of the revolutionary Atlantic. Boston: Beacon Press, 2000. 433 pp., Marcus Rediker (eds)-Ray A. Kea, Herbert S. Klein, The Atlantic slave trade. Cambridge, U.K.: Cambridge University Press, 1999. xxi + 234 pp.-Johannes Postma, P.C. Emmer, De Nederlandse slavenhandel 1500-1850. Amsterdam: De Arbeiderspers, 2000. 259 pp.-Karen Racine, Mimi Sheller, Democracy after slavery: Black publics and peasant radicalism in Haiti and Jamaica. Gainesville: University Press of Florida, 2001. xv + 224 pp.-Clarence V.H. Maxwell, Michael Craton ,Islanders in the stream: A history of the Bahamian people. Volume two: From the ending of slavery to the twenty-first century. Athens: University of Georgia Press, 1998. xv + 562 pp., Gail Saunders (eds)-César J. Ayala, Guillermo A. Baralt, Buena Vista: Life and work on a Puerto Rican hacienda, 1833-1904. Chapel Hill: University of North Carolina Press, 1999. xix + 183 pp.-Elizabeth Deloughrey, Thomas W. Krise, Caribbeana: An anthology of English literature of the West Indies 1657-1777. Chicago: University of Chicago Press, 1999. xii + 358 pp.-Vera M. Kutzinski, John Gilmore, The poetics of empire: A study of James Grainger's The Sugar Cane (1764). London: Athlone Press, 2000. x + 342 pp.-Sue N. Greene, Adele S. Newson ,Winds of change: The transforming voices of Caribbean women writers and scholars. New York: Peter Lang, 1998. viii + 237 pp., Linda Strong-Leek (eds)-Sue N. Greene, Mary Condé ,Caribbean women writers: Fiction in English. New York: St. Martin's Press, 1999. x + 233 pp., Thorunn Lonsdale (eds)-Cynthia James, Simone A. James Alexander, Mother imagery in the novels of Afro-Caribbean women. Columbia: University of Missouri Press, 2001. x + 214 pp.-Efraín Barradas, John Dimitri Perivolaris, Puerto Rican cultural identity and the work of Luis Rafael Sánchez. Chapel Hill: University of North Carolina Press, 2000. 203 pp.-Peter Redfield, Daniel Miller ,The internet: An ethnographic approach. Oxford: Berg Publishers, 2000. ix + 217 pp., Don Slater (eds)-Deborah S. Rubin, Carla Freeman, High tech and high heels in the global economy: Women, work, and pink-collar identities in the Caribbean. Durham NC: Duke University Press, 2000. xiii + 334 pp.-John D. Galuska, Norman C. Stolzoff, Wake the town and tell the people: Dancehall culture in Jamaica. Durham NC: Duke University Press, 2000. xxviii + 298 pp.-Lise Waxer, Helen Myers, Music of Hindu Trinidad: Songs from the Indian Diaspora. Chicago: University of Chicago Press, 1998. xxxii + 510 pp.-Lise Waxer, Peter Manuel, East Indian music in the West Indies: Tan-singing, chutney, and the making of Indo-Caribbean culture. Philadelphia: Temple University Press, 2000. xxv + 252 pp.-Reinaldo L. Román, María Teresa Vélez, Drumming for the Gods: The life and times of Felipe García Villamil, Santero, Palero, and Abakuá. Philadelphia: Temple University Press, 2000. xx + 210 pp.-James Houk, Kenneth Anthony Lum, Praising his name in the dance: Spirit possession in the spiritual Baptist faith and Orisha work in Trinidad, West Indies. Amsterdam: Harwood Academic Publishers. xvi + 317 pp.-Raquel Romberg, Jean Muteba Rahier, Representations of Blackness and the performance of identities. Westport CT: Bergin & Garvey, 1999. xxvi + 264 pp.-Allison Blakely, Lulu Helder ,Sinterklaasje, kom maar binnen zonder knecht. Berchem, Belgium: EPO, 1998. 215 pp., Scotty Gravenberch (eds)-Karla Slocum, Nicholas Mirzoeff, Diaspora and visual culture: Representing Africans and Jews. London: Routledge, 2000. xiii + 263 pp.-Corey D.B. Walker, Paget Henry, Caliban's reason: Introducing Afro-Caribbean philosophy. New York: Routledge, 2000. xiii + 304 pp.-Corey D.B. Walker, Lewis R. Gordon, Existentia Africana: Understanding Africana existential thought. New York; Routledge, 2000. xiii +228 pp.-Alex Dupuy, Bob Shacochis, The immaculate invasion. New York: Viking, 1999. xix + 408 pp.-Alex Dupuy, John R. Ballard, Upholding democracy: The United States military campaign in Haiti, 1994-1997. Westport CT: Praeger, 1998. xviii + 263 pp.-Anthony Payne, Jerry Haar ,Canadian-Caribbean relations in transition: Trade, sustainable development and security. London: Macmillan, 1999. xxii + 255 pp., Anthony T. Bryan (eds)-Bonham C. Richardson, Sergio Díaz-Briquets ,Conquering nature: The environmental legacy of socialism in Cuba. Pittsburgh: University of Pittsburgh Press, 2000. xiii + 328 pp., Jorge Pérez-López (eds)-Neil L. Whitehead, Gérard Collomb ,Na'na Kali'na: Une histoire des Kali'na en Guyane. Petit Bourg, Guadeloupe: Ibis Rouge Editions, 2000. 145 pp., Félix Tiouka (eds)-Neil L. Whitehead, Upper Mazaruni Amerinidan District Council, Amerinidan Peoples Association of Guyana, Forest Peoples Programme, Indigenous peoples, land rights and mining in the Upper Mazaruni. Nijmegan, Netherlands: Global Law Association, 2000. 132 pp.-Salikoko S. Mufwene, Ronald F. Kephart, 'Broken English': The Creole language of Carriacou. New York: Peter Lang, 2000. xvi + 203 pp.-Salikoko S. Mufwene, Velma Pollard, Dread talk: The language of Rastafari. Kingston: Canoe Press: Montreal: McGill-Queen's University Press. Revised edition, 2000. xv + 117 pp.

Jersey Oil and Gas Unearths Wengen Prospect The Greater Buchan Area (GBA) now has four drill-ready prospects to add to discoveries already slated for development. In a new subsurface evaluation, Jersey Oil & Gas, a British-independent North Sea-focused upstream oil and gas company, has uncovered a new prospect, named Wengen, to complement its Verbier Deep, Cortina NE, and Zermatt drill-ready prospects. The four are estimated to host some 222 million bbl of P50 prospective resources, all in the immediate vicinity of Jersey’s planned GBA production facility. The consolidated Greater Buchan venture comprises Buchan field (80 million bbl), Verbier (c25 million bbl), J2 (c20 million), and Glenn (14 million). The new prospect, located in License P2170, is directly west of the Tweedsmuir field and should host some 62 million bbl of potential resources (P50), with the probabilistic range set at 31 million bbl at P90 (higher confidence) and 162 mil-lion for P10 (lower confidence). Probability of geological success is 22% for the prospect. Contractor Rockflow previously estimated the recoverable resources in the GBA at 94.7 million bbl, including the parts within P2170. In late November, Jersey announced it is taking full ownership of License P2170, which hosts most of the Verbier discovery, as part of the GBA. In March, Jersey told investors the project is fully funded and that it intends to take the project to potential industry partners via a farm-out process. An exploratory drilling campaign is being planned for 2022. Jordan Finds “Promising” Gas Reserves Near Iraq Border Jordan’s majority state-owned National Petroleum Company (NPC) has discovered “promising” natural gas in the Risha gas field along its eastern border with Iraq. Risha makes up nearly 5% of the kingdom’s consumption of natural gas of around 350 MMcf/D for power generation, Jordanian officials said. The flow of new gas supplies will raise the productivity of the gas field and help Jordan cut dependence on oil imports to fuel its power sector and industries. The country, which now imports over 93% of its total energy supplies, is burdened by a $3.5-billion annual bill, comprising almost 8% of Jordan’s GDP. Although British supermajor BP abandoned the eastern desert area in 2014 after investing over $240 million, Jordanian exploration has stepped up since 2019, boosting quantities by at least 70%, Mohammad al Khasawneh, head of NPC, said. An ambitious 10-year energy plan unveiled in 2019 aims to secure nearly half of the country’s electricity generation from local energy sources com-pared to a current 15%, according to Iraq Energy Minister Hala Zawati. The plan is meant to diversify local energy sources by expanding investments in renewable and oil shale to reduce costly foreign fuel imports, Zawati added. ExxonMobil Discovers Hydrocarbons Offshore Suriname ExxonMobil and Petronas have discovered several hydrocarbon-bearing sandstone zones with good reservoir qualities in the Campanian section of the Sloanea-1 exploration well on Block 52 offshore Suriname, adding to ExxonMobil’s finds in the Guyana-Suriname basin. The well was drilled by operator Petronas. ExxonMobil said in November that it is prioritizing near-term capital spending on advantaged assets with the highest potential future value. Maersk Drilling reported in early July that it had secured the Maersk Developer from Petronas subsidiary PSEPBV in a $20.4-million one-well exploration con-tract offshore Suriname. The semisubmersible rig drilled the Suriname-Guyana basin well to a total depth of 15,682 ft. “We are pleased with the positive results of the well,” Emeliana Rice-Oxley, Petronas’ vice president of upstream exploration, said. “It will provide the drive for Petronas to continue exploring in Suriname, which is one of our focus basins in the Americas.” Block 52 covers an area of 1.2 million acres and is located approximately 75 miles offshore north of Paramaribo. The water depths on Block 52 range from 160 to 3,600 ft. ExxonMobil E&P Suriname BV, an affiliate of ExxonMobil, holds 50% interest in Block 52. PSEPBV is operator and holds 50% interest. CNOOC Starts Production on Penglai 25-6 Oil Field Area 3 Project China National Offshore Oil Corporation (CNOOC) announced on 14 December that its Bohai Sea Project - the Penglai 25-6 oil field area 3 - has started production ahead of schedule. The biggest offshore oil field and the second biggest oil field in China, the Penglai is located in the south central Bohai Sea, with average water depth of about 27 m. In addition to fully utilizing the existing processing facilities of Penglai oil fields, the project has built a new wellhead platform and plans 58 development wells, including 38 production wells and 20 water-injection wells. The project is expected to reach its peak production of approximately 11,511 B/D of crude oil in 2023. Six successful appraisal wells were also drilled, which confirmed the presence of hydrocarbons in reservoirs located with-in Miocene, Lower Minghuazhen, and Guantao sandstones. The Penglai 19-3 oil field is located in Block 11/05 of Bohai Bay, approximately 235 km southeast of Tanggu. The production-sharing contract for block 11/05 was signed between CNOOC and ConocoPhillips China (COPC) in December 1994; the field was discovered jointly by CNOOC and COPC in 1999. The oil field was developed in two phases. Phase I production started in December 2002; production from the wellhead platform C, which is tied back temporarily to the production facilities of Phase I, began in June 2007. Since June 2020, CNOOC has announced five production startups: the Jinzhou 25-1 oilfield 6/11 area project, the Liuhua 16-2 oilfield/ 20-2 oil-field joint development project, the Nan-bao 35-2 oilfield S1 area project, the Luda 21-2/16-3 regional development project, and the Qinhuangdao 33-1S oilfield phase-I project. In Q3 2020, CNOOC achieved a total net production of 131.2 million BOE, which the company said represented an increase of 5.1% year over year. Production from China was said to have increased by 10.4% year over year to 88.6 million BOE. In November, CNOOC revealed that the Liuhua 29-1 gas field had begun production; in September, the company said the Bozhong 19-6 condensate gas field pilot area development project had also begun. Operator CNOOC holds 51% interest while COPC holds 49% interest in the Penglai 25-6 oilfield area 3 project. Equinor’s Snorre Expansion Project Starts Ahead of Schedule, Below Cost Work began in December on the Snorre Expansion Project in the southern part of the Norwegian Sea. This increased-oil-recovery project will add almost 200 million bbl of recoverable oil reserves and help extend the productive life of the Snorre field through 2040. The expansion project is proposed in blocks 34/4 and 34/7 of the Tampen area, approximately 124 miles west of Florø in the Norwegian North Sea. “I am proud that we have managed to achieve safe startup of the Snorre Expansion Project ahead of schedule in such a challenging year as 2020. In addition, the project is set to be delivered more than NOK 1 billion below the cost estimate in the plan for development and operation,” Geir Tungesvik, Equinor’s executive vice president for technology, projects, and drilling, said. Originally scheduled to come onstream in the first quarter of 2021, the project comprises 24 new wells divided into six subsea templates, drilled to recover the new volumes. Bundles connecting the new wells to the platform have been installed, in addition to new risers. The project also includes a new module and modifications on Snorre A. In December 2017, Equinor submitted a modified plan for development and operation of the field. With the expansion, the recovery factor will increase from 46 to 51%, representing significant value for a field with 2 billion bbl of recoverable oil reserves. Wind power will supply about 35% of the power requirement for the Snorre and Gullfaks fields. The Hywind Tampen project, featuring 11 floating wind turbines, should start up in Q3 2022. The investments in the expansion project total NOK 19.5 billion (2020 value). The project has had substantial spin-off effects for the supply industry in Norway, particularly in eastern Norway and in Rogaland. The Snorre field partnership comprises Equinor (operator) 33.27%, Petoro 30%, Vår Energi 18.55%, Idemitsu 9.6%, and Wintershall Dea 8.57%. Petrobras To Sell Entire Stake in Onshore Field of Sergipe Petrobras on 11 December signed a contract with Energizzi Energias do Brasil to sell its entire stake in the onshore field of Rabo Branco, located south of the Carmópolis field in the Sergipe-Alagoas Basin, Sergipe state. The Rabo Branco field is part of the BT-SEAL-13 concession. The $1.5-million sale is in line with Petrobras’ strategy to cut costs and improve its capital allocation, to focus its resources increasingly on deep and ultradeep waters. The average oil production of the field, from January to October 2020, was 138 B/D. Energizzi Energias do Brasil will own 50% stake in the Rabo Branco field; operator Produção de Óleo e Gás (Petrom) holds the remaining 50%. On 10 December, Petrobras closed the divestiture of its full ownership in four onshore fields at the Tucano Basin site in the state of Bahia. Petrobras sold its entire interest to Eagle Exploração de Óleo e Gás (Eagle). Petrobras earned $2.571 million from this sale, in addition to the $602,000 that the company received at the time of signing the sale contract, for a total of $3.173 million. BP, Reliance Announce First Gas From Asia’s Deepest Project Oil-to-telecom conglomerate Reliance Industries Limited (RIL) and BP have started production from India’s first ultradeepwater gas project, the first of three such projects in the KG D6 block. The R Cluster gas field is located off the east coast of India, about 60 km from the existing KG D6 control-and-riser platform (CRP), and comprises a subsea production system tied back to the CRP via a subsea pipeline. It is the deepest offshore gas field in Asia at a depth greater than 2000 m. The companies’ next project, the Satellites Cluster, is expected to come on stream this year, followed by the MJ project in 2022. These projects will utilize the existing hub infrastructure in the KG D6 block. “Growing India’s own production of cleaner-burning gas to meet a significant portion of its energy demand, these three new KG D6 projects will support the country’s drive to shape and improve its future energy mix,” BP Chief Executive Bernard Looney said. The R Cluster field is expected to reach plateau gas production of about 12.9 million standard cubic meters per day (MMscm/D) in 2021. Peak gas production from the three fields should be 30 MMscm/D (1 Bcf/D) by 2023, about 25% of India’s domestic production, and will help reduce the country’s dependence on imported gas. RIL is the operator of KG D6 with a 66.67% interest; BP holds a 33.33% participating interest.

Angola Opens Congo, Kwanza Blocks in Ongoing Bid Round Angola’s National Oil, Gas, and Biofuel’s Agency has opened blocks for licensing in the Onshore Lower Congo Basin and the Onshore Kwanza Basin as part of its 2020 oil and gas licensing round. This latest call to tender is part of the agency’s ongoing 2019–2025 hydrocarbons licensing strategy. The Onshore Lower Congo Basin Blocks include CON1, CON5, and CON6; while the Onshore Kwanza Basin Blocks comprise KON5, KON6, KON8, KON9, KON17, and KON20. The round aims to expand research and evaluation activities across sedimentary basins, increase geological knowledge of Angola’s hydrocarbon potential, and invite a new wave of explorers to yield new discoveries. Raven Field Startup for BP in Egypt Natural gas has begun flowing from the BP-operated Raven field, the third stage of the company’s major West Nile Delta (WND) development off the Mediterranean coast in Egypt. The $9-billion WND development includes five gas fields across the North Alexandria and West Mediterranean Deepwater offshore concession blocks in the Mediterranean Sea. Raven is currently producing approximately 600 MMcf/D with a peak potential of 900 MMcf/D and 30,000 B/D of condensate. Raven follows the Taurus/Libra and Giza/Fayoum projects, which started production in 2017 and 2019, respectively. It produces gas to a new onshore processing facility, alongside the existing WND onshore processing plant. In total, the WND development includes 25 wells producing gas to the onshore processing plant via three long-distance subsea tiebacks. The onshore facilities—including the new Raven facility—now have a total gas processing capacity of around 1.4 Bcf/D of gas. All gas produced is fed into Egypt’s national grid. BP is the operator and has an 82.75% stake in the WND development, with Wintershall Dea holding the remaining 17.25% interest. CGX Secures Rig for Kawa-1 Well off Guyana CGX Energy and Frontera Energy, joint venture partners in the Petroleum Prospecting License for the Corentyne block offshore Guyana, have secured semisubmersible Maersk Discoverer to drill the Kawa-1 well. An early third quarter spud for the exploration well is targeting a Santonian age, stratigraphic trap, interpreted to be analogous to the discoveries immediately to the east on Block 58 in Suriname. The well is anticipated to be drilled to a total depth of approximately 6500 m in a water depth of approximately 370 m. The contract has an estimated duration of 75–85 days and has a one-well option attached. If exercised, that probe would spud in the nearby Demerara Block and take an estimated 40 days to reach its target. Talos’ Bulleit Reservoir in US Gulf Smaller Than Expected A technical assessment of the main producing sand performance at Talos Energy’s Green Canyon Block 21 Bulleit field in the US Gulf has indicated a smaller reservoir than originally anticipated. Project partner Otto Energy said the assessment included detailed bottomhole pressure and reservoir performance data collected after hookup and first production. The Block 21 field is flowing via a single subsea well tied back to a platform in nearby Green Canyon Block 18. While additional technical work is ongoing, the currently favored path forward is to move away from the current sand and execute a recompletion of the well in the shallower DTR-10 sand. A DTR-10 recompletion will require the procurement of long-lead items from manufacturers, which are expected to cost $3.5 million with payment expected in mid-2021. The recompletion is expected to begin in mid-2022, with production from the DTR-10 immediately following in mid-to late 2022. Captain Field EOR Stage 2 Project a Go Ithaca Energy, operator of the Captain field, has sanctioned the Captain Enhanced Oil Recovery (EOR) Stage 2 project in the UK Central North Sea after receiving Field Development Plan Addendum consent from the Oil and Gas Authority. EOR Stage 2 is designed to significantly increase hydrocarbon recovery by injecting polymerized water into the reservoir through additional subsea wells, subsea infrastructure, and new topsides facilities. Stage 1 of the project demonstrated that polymer EOR technology can work, with the production response in line with or better than expected across all injection patterns, helping maximize economic recovery. The Captain field was discovered in 1977, in Block 13/22a located on the edge of the outer Moray Firth. The billion-barrel field achieved first production in March 1997—over 24 years ago. Ithaca Energy holds 85% working interest, while partner Dana Petroleum holds the remaining 15%. Equinor Touts new Tyrihans Field Discovery Equinor and partners Total E&P Norge AS and Vår Energi AS have struck oil and gas in a new segment belonging to the Tyrihans field in the Norwegian Sea. Exploration well 6407/1-A-3 BH in production license 073 was drilled from sub-sea template A at Tyrihans North. The well was drilled to a measured depth of 5332 m by semisubmersible drilling rig Transocean Norge and struck a gas column of about 43 m and an oil column of about 15 m in the Ile formation, including about 76 m of moderate to good reservoir quality sandstone. In the Tilje formation, moderate to good quality water-bearing reservoir was struck. The Tyrihans field is in the middle of the Norwegian Sea, some 25 km southeast of the Åsgard field and 220 km northwest of Trondheim. The licensees consider the discovery commercial and intend to start production immediately. Recoverable resources are so far estimated at between 19 and 26 million BOE. Maersk Awarded Intervention Work off Brazil Maersk Drilling has been awarded a contract with Karoon Energy Ltd. for the semisubmersible rig Maersk Developer to perform well intervention on four wells at the Baúna field offshore Brazil. The contract is expected to begin in the first half of 2022, with a firm duration of 110 days. The value of the contract is $34 million, including rig modifications and a mobilization fee. The contract contains options to add up to 150 days of drilling work at the Patola and Neon fields. Carnarvon Completes Farmout of Buffalo Project Carnarvon Petroleum has completed the farmout of 50% of the Buffalo project to Advance Energy PLC. On 17 December 2020, Carnarvon announced that Advance Energy would acquire 50% of the Buffalo project off the west coast of Australia by funding the drilling of the Buffalo-10 well up to $20 million on a free carry basis. Advance met this funding requirement and now has a 50% interest in the project. The well is on track to be drilled in late 2021, subject to securing a drilling rig, where the tendering process is already underway. Following the well, the joint venture will acquire development funding from third-party lenders and any additional funding will be provided by Advance as an interest-free loan. The current plan is to suspend a successful well as a future producer and begin early development studies during 2021. Shell Hires Seadrill Rig for Brazilian Campaign Shell has contracted Seadrill’s drillship West Tellus for a new drilling campaign offshore Brazil this year. The program is expected to start in BC-10 of the Campos Basin, where Shell operates the Parque das Conchas made up of the Abalone, Argonauta, and Ostra fields. BC-10 has produced more than 100 million bbl since oil first started flowing from the block in 2009. The drillship will be used on the third phase of BC-10 activity, which includes five additional production wells and two water-injection wells at the Massa and Argonauta O-Sul fields, with the wells connected to the Espirito Santo FPSO. Shell owns a 50% operating stake in BC-10. India’s ONGC retains a 27% minority share and Qatar Petroleum the remaining 23%. Following the BC-10 work, the operator is expected to drill the first wells in the Campos Basin’s C-M-791 block, which was acquired during the 15th bid round held in 2017. Shell owns a 40% operating stake in the block, with Chevron retaining a 40% interest and Portugal’s Galp Energia the remaining 20%. Panoro Energy Kicks Off 2021 Drilling Campaign Offshore Gabon Panoro Energy has initiated its 2021 Gabon drilling campaign with the spudding of the Hibiscus Extension well on the Dussafu Marin Permit. That well will be followed by drilling at Tortue and Hibiscus North. Hibiscus and Tortue are two out of a total of six discovered fields within the Dussafu Permit offshore Gabon. Panoro currently holds a 7.5% interest in the license and has entered into an agreement to acquire an additional 10% working interest in the Dussafu Permit, bringing its total ownership to 17.5% following completion of the transaction. The Extension well is being drilled with the jackup Borr Norve and is the first well in a three-well campaign planned on Dussafu during 2021. The well is planned as a vertical well to test structure, oil, and reservoir presence in what is believed to be a possible northerly extension of the Gamba reservoir in the Hibiscus field. The well is positioned about 3 km northwest of the Hibiscus discovery well drilled by the joint venture in 2019. The initial well and its appraisal sidetrack established a 2P gross recoverable reserves of just over 46 million bbl at the Hibiscus field. The Extension well is expected to take around 30 days to drill and log to a total depth of 3500 m. Success at the probe could prompt one or two appraisal side-tracks to further delineate the field. Following the Hibiscus Extension, the rig will move to drill a horizontal production well, DTM-7H, at the Tortue field. This will complete the Phase 2 development of Tortue and, along with DTM-6H, will bring the total number of production wells at Tortue up to six. An exploration well at the Hibiscus North prospect, located approximately 6 km north-northeast of the initial Hibiscus well is also scheduled. Hibiscus North is a separate 10–40 million bbl prospect that could be tied into the Hibiscus/Ruche development project. Puma West Strike for BP in the US Gulf An exploration well at the Puma West prospect in the deepwater US Gulf has yielded a significant oil discovery for operator BP. The well, on Green Canyon Block 821, was drilled using Seadrill drillship West Auriga to a total depth of 23,530 ft and encountered oil pay in a high-quality Miocene reservoir with fluid properties like productive Miocene reservoirs in the area. Preliminary data supports the potential for a commercial volume of hydrocarbons. The Puma West partners will begin planning an appraisal program to better define the discovered resource. The discovery well has been suspended as a keeper well to preserve future utility. Puma West is located west of the BP-operated Mad Dog field and is approximately 131 miles off the coast of Louisiana in 4,108 ft of water. The Puma West is operated by BP with a 50% working interest. Partners include Chevron with 25% and Talos Energy with the remaining 25%. Petrobras Pushes First Oil at Mero Into 2022 Petrobras has postponed first oil from its Mero 1 field via the FPSO Guanabara in the Santos Basin offshore Brazil due to delays with the production system. Startup at Mero 1 was originally expected in the fourth quarter of this year and is now expected to begin flowing during the first quarter of 2022 due to COVID-19 pandemic-related delays with the buildout of the production system in China. The FPSO will be installed in the Mero field, which belongs to the Libra Block, in the Santos Basin pre-salt area, with a processing capacity of 180,000 OPD. The field is operated by Petrobras (40%) in partnership with Shell Brasil Petróleo (20%), Total E&P (20%), CNODC Brasil Petróleo e Gás (10%), CNOOC Petroleum Brasil (10%), and Pré-Sal Petróleo, which is the contract manager.