Academic literature on the topic 'Jersey Central Power and Light Company'

This article is a historiographical study of urban renewal in Newark, New Jersey. The paper offers a cross-sectional view of policymaking and appropriation at the federal and local levels, which is critical when analyzing the delimitations of ethnic coalition building. The article centers on a typological study of Black resistance to the New Jersey College of Medicine and Dentistry (NJCMD) construction project that was slated to commence around 1965-1966. NJCMD, renamed the University of Medicine and Dentistry, New Jersey (UMDNJ) in 1981, was initially proposed as a revitalization project that would stymie urban decay in Newark. However, the project proposal would also displace close to 22,000 people in the Central Ward—a predominately poor, majority Black section of Newark. Using social movement scholarship, specifically the literature on resource mobilization during the mid-twentieth century Civil Rights Movement, this article examines the distinct ways that Black residents of Newark responded to the NJCMD project. The response involved community board meetings, rallies, and surveys that ultimately led to significant overhauls of NJCMD’s initial design. Black resistance to NJCMD also culminated in the 1970 election of Kenneth Gibson, Newark’s first Black mayor. Key concepts such as “collective action framing” and “frame diffusion” inform this study of grassroots mobilization and community resistance. Also included in this work is an exploration of Black Power politics, its key figures in Newark, and the impact that such solidarity movements had on municipal politics. A thorough analysis of “pressure politics” and “protest politics” in the public sphere will also shed light on how racial exclusion frames elections and electorates.

This study highlights that the British had long experiences in the Malay Peninsula before Francis Light’s acquisition and development of Penang, due to the central role of Malayan ports such as Kedah, Takuapa, Langkasuka, Terengganu, Palembang, Siak, and Malacca in global trade between China and India. Under the influence of Islam, Malacca (and, to a lesser extent, Kedah) became a Muslim Sultanate and reached its peak in this trading network, which attracted European traders (and subsequent colonialism), initially from Portugal and Spain, and later France, the Netherlands, and Britain. After the East India Company attained hegemony in India, it was strongly placed to extend its power from its presidencies in Calcutta, Bombay, and Madras. The EIC’s main focus was Bengal, where the Company founded the Fort William College as its headquarters in Calcutta. As trade with China became more important, the Malay Peninsula commensurately became a more attractive destination for investment due to its closer proximity to the Chinese sea lanes, and closer access to the Indo-Malay hinterlands and their products. In 1784, the EIC sent Kinloch to Aceh but he was unsuccessful in negotiating to establish a factory there. Nevertheless, they succeeded in establishing a foothold in Malaya with Francis Light’s embassy to Riau, Kedah, and Penang. Kedah also became prosperous under the Muslim Sultanates. Many Chinese and Indian merchants were settled there, benefitting from the trade in jungle products like camphor, betelnut, bird nests, situated near the Kedah River, was identified as a strategic location. Sultan Muhammad Jiwa Zainal Abidin Muazzam Shah II of Kedah (r. 1710-1778) at that time was facing many internal as well as external conflicts. His son Sultan Abdullah Mukarram Shah (r. 1778-1797) also suffered the same fate. As a result of internal crisis and dynastic intrigues, he agreed to lease Penang to the EIC in exchange for military assistance in 1785. In July 1786, Francis Light sailed from Calcutta and reached Penang in August, and thus Penang became an EIC stronghold.

Objective – Tax policies play significant role in the direction of foreign direct investments. We investigate the proposition that tax policies enacted by military and democratic regimes differ on the influence the foreign direct investments. Methodology/Technique – Our hypotheses are tested using the error correction model as we compare the impact of tax policies on flow foreign direct investments in Nigeria between two dispensations: military rule from 1983 to 1999 and democratic rule from 1999 to 2017. Panel data between 1983 and 2017 were obtained from the databases of the World Bank, Central Bank of Nigeria and the Federal Inland Revenue Services. The explanatory variables include company income tax, value added tax, tertiary education tax and customs and exercise duties. Findings – The study reveals that tax variables during the military regime exerted more explanatory power of 79% compared to the civilian administration of 66% with respect to the impact of corporate taxes on FDI. The effect of company income tax on FDI was more pronounced during the military regime than in the civilian regime. FDI had a higher degree of convergence during the military regime compared to civilian rule, and this is vital for policy assessments and comparison. Novelty – We bring to light new evidences on the effects of taxes polices on FDI. Type of Paper: Empirical Keywords: Corporate taxes; Tax Policies; Foreign Direct Investments; Error Correction Model; Military regime; Civilian regime. Reference to this paper should be made as follows: Edo, O.C; Okafor, A; Emmanuel, A. (2020). Tax Policy and Foreign Direct Investment: A Regime Change Analysis., J. Fin. Bank. Review, 5 (3): 84 – 98 https://doi.org/10.35609/jfbr.2020.5.3(3) JEL Classification: E22, F21, H2, P33.

This research article throws light on the impacts of Corporate Governance in the developing countries particularly to Pakistan, Mexico, Brazil and Bangladesh. The paper starts with discussions on how and when there is an alteration in different features of company administration during the practice of financial advancing in Mexico. It encompasses ultimately the impact of transforms in the replica of business control regarding the expansion of the state e.g. enlargement in purchaser commodities in favour of central group buyers, growth revelation through home firms, fewer help in favour of community public schemes etc. The authors of this research article assert that problems of governance in Bangladesh are at the helm of affairs of its economy. We observed the data regarding governance of Bangladesh of period 1996-2004 and analysed these various governance dimensions out of the aforesaid economic progress analysis the key dimensions have been divulged. These are political governance, institution dimensions and technology dimensions. The political governance in Bangladesh has been paralysed from 1998 to 2004. When the performance of governance in Bangladesh become functional it had positively affected the economy. We cannot say the importance of company authority within growing kingdoms. The commercial domination might include a slightly different system than prevalent in the European countries and North America due to insufficient infrastructure and destroy governmental policy interventionism. We also throw light on important features of Brazilian firm’s changes after the application for communal power exercises. After making a deliberation on the implementation of joint supremacy in Brazil, Mexico, and Bangladesh and subsequently we have emphasized the impact of Corporate Governance and proper growth in Pakistan. The relationship between good governance and proper growth is proportional generally. Having studied different scenarios of the countries under remonstration, the writers have reached the conclusion that good governance is an essential component for upgrading the economies of developing countries because of these reasons it may be said that high-quality control leads towards a country obtain sky-scraping and frequent monetary increase through establishment of congenial environment for savings and investment, entrepreneurship, yielding implement upon manufacturers, generating constancy among marketplace, expansion in souks though elimination of hurdles/barriers towards inner job and progress over the competitors. Keywords: Business Control, Economic Development and Proper Growth.

Abstract The taxation system is most certainly one of the main pillars of economic development towards sustainable growth.The aim of this paper is to critically assess the importance of an effective Tax System, its impact on the Albanian economy. Furthermore we shall outline a comparison of the Albanian Tax system to that of the United Kingdom. At this time a number of very important reforms are being undertaken by the government of Albania in light of future integration towards the European Union.The overview on the United Kingdom has the aim to enlighten the path on what should be our focus while building a Tax System that can help economic growth, to that effect Great Britain as a country of a stable and strong economy can be of example.Many differences can be noticed between the United Kingdom tax system and the Albanian one. This fact is simple to be accepted as Britain is one of the world superpowers, while the Albanian economy is a developing one. The tax systems in these two countries, the development history, application of VAT or Income Tax have had very different processions.The United Kingdom has one of the most voluminous Tax Acts in the world. The international company of legal research “LexisNexis” discovered that the Acts of Parliament on Taxation in the United Kingdom have more than doubled since 1997. The annual amendments to taxation are part of the Finance Act which has the power to change norms and principles of taxation as previously defined. Taxation in the United Kingdom usually includes payments for central government agencies called Her Majesty’s Revenues and Incomes and local councils. Local Councils collect a tax called business norms from businesses. The Albanian Taxation System consists of a packet of laws, regulations, guidance and tax agreements, on the procedure of application, measure, amendment and removal of taxes.Taxes are the main source of income in the state budget and the local government budget and the foundation of the whole Albanian tax system. In conclusion, we shall analyze the impact of the frequent changes to Taxation Law within the Albanian system and the challenges faced in light of this changes in terms of implementation and application.

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.

Purpose – The concept of value at risk is used in the risk-based calculation of solvency capital requirements in the Basel II/III banking regulations and in the planned Solvency II insurance regulation framework planned in the European Union. While this measure controls the ruin probability of a financial institution, the expected policyholder deficit (EPD) and expected shortfall (ES) measures, which are relevant from the customer's perspective as they value the amount of the shortfall, are not controlled at the same time. Hence, if there are variations in or changes to the asset-liability situation, financial companies may still comply with the capital requirement, while the EPD or ES reach unsatisfactory levels. This is a significant drawback to the solvency frameworks. The paper aims to discuss these issues. Design/methodology/approach – The author has developed a model framework wherein the author evaluates the relevant risk measures using the distribution-free approach of the normal power approximation. This allows the author to derive analytical approximations of the risk measures solely through the use of the first three central moments of the underlying distributions. For the case of a reference insurance company, the author calculates the required capital using the ruin probability and EPD approaches. For this, the author performs sensitivity analyses considering different asset allocations and different liability characteristics. Findings – The author concludes that only a simultaneous monitoring of the ruin probability and EPD can lead to satisfactory results guaranteeing a constant level of customer protection. For the reference firm, the author evaluates the relative changes in the capital requirement when applying the EPD approach next to the ruin probability approach. Depending on the development of the assets and liabilities, and in the cases the author illustrates, the reference company would need to provide substantial amounts of additional equity capital. Originality/value – A comparative assessment of alternative risk measures is relevant given the debate among regulators, industry representatives and academics about how adequately they are used. The author borrows the approach in parts from the work of Barth. Barth compares the ruin probability and EPD approach when discussing the RBC formulas of the US National Association of Insurance Commissioners introduced in the 1990s. The author reconsiders several of these findings and discusses them in the light of the new regulatory frameworks. More precisely, the author first performs sensitivity analyses for the risk measures using different parameter configurations. Such analyses are relevant since in practice parameter values may differ from estimates used in the model and have a significant impact on the values of the risk measures. Second, the author goes beyond a simple discussion of the outcomes for each risk measure, by deriving the firm conclusion that both the frequency and magnitude of shortfalls need to be controlled.

The GT24 and GT26 are the latest in a series of gas turbines from ABB. The GT24 is a 60 Hz, 183 MW turbine, while the GT26 is its (scaled) 50 Hz equivalent, producing 265 MW. They feature a 22 stage controlled diffusion aerofoil compressor, two combustors separated by a single stage high pressure turbine with a four stage low pressure (LP) turbine following the second combustor. This arrangement permits very high efficiencies while avoiding high temperatures and the need to use new, expensive materials. The first GT24 was delivered to Jersey Central Power and Light, Gilbert, New Jersey, USA, at the end of 1995 and achieved baseload operation in May 1996. The engine was highly instrumented with some 1200 measurement points to evaluate component performance. Subsequently, a through-flow datamatch to the design point data was made for the LP turbine and is compared to a full 3D multistage analysis in this paper. The 3D analysis accounts for all the cooling and leakage flows that enter the turbine flowpath and maintains a steady flow calculation by means of interface planes between each blade row that remove any circumferential non-uniformity from the computational flow field. To complement this aerodynamic analysis, some heat transfer results from the ABB GT26 test facility in Birr, Switzerland are also shown. The paper demonstrates how component technology for the first stage was verified at four universities and research centers concurrently with the design process. This experimental data supplemented the existing databases and engendered confidence in the overall aero/thermal design approach.

New high temperature materials and improved blade cooling techniques have led 10 design of advanced models of industrial gas turbines with inlet or “firing” temperatures of 2350 degrees F. and higher. All major vendors now offer large new commercial gas turbine-generators, with outputs of 150 megawatts and higher, based on these new designs. These new turbine units offer higher overall performance and fuel efficiencies, with promise of better reliability and availability, as well as lower operating and maintenance costs. EPRI began to assess the durability of early models of these advanced gas turbines (AGT) in 1991, by closely monitoring their performance during electric utility operation. The durability surveillance program, involving several AGT installations outlined below, will be described. However, only the first two sites involving GE units have produced a substantial operating history for discussion. The latter two sites have only recently had new AGT units installed by ABB and Siemens respectively. At the time of this writing, those new units are still being readied for utility operation. Their operating history under the durability surveillance program will be monitored, and discussed in a future paper. • General Electric Gas Turbine Model MS7001F in peaking service at Potomac Electric Power Co. Station H at Dickerson, Maryland. • General Electric Gas Turbine Model MS7001FA in baseload service at Florida Power & Light Co. Martin Plant at Indiantown, Florida. • ASEA Brown Bovert Gas Turbine Model GT 24 initially in peaking service at Jersey Central Power & Light Co.(now GPU GenCo) Gilbert Station at Milford, New Jersey. • Siemens Gas Turbine Model V84.3A in peaking service at Kansas City Power & Light Co. Hawthorn Station at Kansas City, Missouri. The purpose is to determine the prospects for improved unit life cycle costs as a result of higher levels of performance, availability, reliability, and mantainability achieved by adding these engines to the industry fleet. This paper will describe the initial results from the Durability Surveillance studies, including observations from unit maintenance inspections as well as the output of advanced diagnostics and monitoring systems.