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Journal articles on the topic 'Upstream petroleum sector'
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1
Livingston, Peter, and Rhys Hunt. "Reducing regulatory burden on the upstream petroleum sector." APPEA Journal 50, no. 2 (2010): 687. http://dx.doi.org/10.1071/aj09051.
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On 30 April 2009, the Productivity Commission released its Review of Regulatory Burden on the Upstream Petroleum Sector. The report identified significant unnecessary costs from delays and uncertainties in obtaining approvals, duplication of compliance requirements and inconsistent administration of regulatory processes. The commission found that these burdens could be reduced through new institutional arrangements—principally the establishment of a national offshore regulator—as well as implementation of best practice regulatory principles in all jurisdictions. On 5 August 2009, the Commonwealth Minister for Resources and Energy, the Hon Martin Ferguson AM MP, announced the Australian Government’s intention to establish a national offshore petroleum regulator in Commonwealth offshore areas, from 1 January 2012. The Council of Australian Governments is scheduled to consider an all-of-governments’ response to the commission’s recommendations in early 2010. The paper will discuss the policy rationale for reform, the proposed reforms and how they will be implemented.
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Olujobi, Olusola Joshua, and Oluwatosin Michael Olujobi. "Theories of Corruption “Public Choice-Extractive Theory” as Alternative for Combating Corruption." International Journal of Environmental Sustainability and Green Technologies 11, no. 2 (2020): 68–83. http://dx.doi.org/10.4018/ijesgt.2020070105.
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Corruption is a recurrent decimal in Nigeria's upstream petroleum sector due to weak enforcement of anti-corruption and transparency laws. This sector is considered corrupt due to the rampant mismanagement of petroleum resources. The article analyses rent-seeking, public choice and extractive theories of corruption among others due to their impacts in combating corruption. It also queries other anti-corruption models that are relevant to this study to promote transparency and to strengthen national anti-corruption laws for combating corruption in the Nigeria's upstream petroleum sector. The study is a doctrinal legal research that adopts a point-by-point comparative approach with library research method. The study proposed a hybrid theory of corruption titled “Public Choice-Extractive Theory of Corruption” as an alternative perspective that will effectively combat corruption in the sector. In conclusion, the study finds that corruption strives on the weak enforcement of anti-corruption laws and lack of political will in providing effective regulatory intervention. The study recommends among other reforms, soft law approach and strict enforcement of anti-corruption laws for transparency in the upstream petroleum sector in Nigeria.
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Beggs, J. M. "Research for the Upstream Petroleum Sector: The Crown Research Institute Concept." Energy Exploration & Exploitation 13, no. 2-3 (1995): 245–52. http://dx.doi.org/10.1177/0144598795013002-313.
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New Zealand's scientific institutions have been restructured so as to be more responsive to the needs of the economy. Exploration for and development of oil and gas resources depend heavily on the geological sciences. In New Zealand, these activities are favoured by a comprehensive, open-file database of the results of previous work, and by a historically publicly funded, in-depth knowledge base of the extensive sedimentary basins. This expertise is now only partially funded by government research contracts, and increasingly undertakes contract work in a range of scientific services to the upstream petroleum sector, both in New Zealand and overseas. By aligning government-funded research programmes with the industry's knowledge needs, there is maximum advantage in improving the understanding of the occurrence of oil and gas resources. A Crown Research Institute can serve as an interface between advances in fundamental geological sciences, and the practical needs of the industry. Current publicly funded programmes of the Institute of Geological and Nuclear Sciences include a series of regional basin studies, nearing completion; and multi-disciplinary team studies related to the various elements of the petroleum systems of New Zealand: source rocks and their maturation, migration and entrapment as a function of basin structure and tectonics, and the distribution and configuration of reservoir systems.
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Ferreira, Doneivan, Saul Suslick, Joshua Farley, Robert Costanza, and Sergey Krivov. "A decision model for financial assurance instruments in the upstream petroleum sector." Energy Policy 32, no. 10 (2004): 1173–84. http://dx.doi.org/10.1016/s0301-4215(03)00080-6.
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Alexander, Elinor. "Australian onshore petroleum acreage and releases 2018." APPEA Journal 58, no. 2 (2018): 426. http://dx.doi.org/10.1071/aj17057.
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This paper is a compilation of information provided by state and territory jurisdictions about onshore acreage and its availability for petroleum exploration in 2018. Australian state and territory governments continue to research and promote petroleum prospectivity to stimulate local and international investment in petroleum exploration by generating new exploration concepts and opportunities, facilitating discoveries and fostering new ideas to assist the nation’s upstream petroleum sector to keep on delivering the maximum net benefits to all Australians. Present and future policy directions that relate to onshore petroleum exploration are described, particularly for jurisdictions that are not making petroleum acreage available this year.
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Redutskiy, Yury. "Modelling and Design of Safety Instrumented Systems for Upstream Processes of Petroleum Sector." Procedia Engineering 182 (2017): 611–18. http://dx.doi.org/10.1016/j.proeng.2017.03.165.
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Agoro, Bode. "Impediments to Expansion: Why is the Upstream Sector of Nigeria's Petroleum Industry Not Growing?" Journal of Energy & Natural Resources Law 19, no. 1 (2001): 16–30. http://dx.doi.org/10.1080/02646811.2001.11433213.
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Lim, C. L. "The Function of the Transnational Chinese Contract." Journal of World Investment & Trade 20, no. 2-3 (2019): 313–34. http://dx.doi.org/10.1163/22119000-12340133.
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Abstract This article focusses on Chinese contractual practice in the energy sector and related sectors – principally in China’s inbound and outbound investments in the petroleum sector as well as in other energy-related financing and infrastructure construction contracts. Its concern is with the drafting of Belt and Road contracts, especially where this may lead to contract ‘internationalisation’. The article also discusses the interplay between Chinese contracts and treaties. It asks if there is Chinese receptiveness to international principles in seeking to protect the rights of Chinese as well as foreign parties. A preliminary finding is that there is an asymmetry between what Chinese upstream oil contracts do in protecting foreign ownership interests, even to the point of evincing Chinese acceptance of the ‘internationalisation’ of contracts, and the intergovernmental work done through negotiated treaty terms to protect Chinese investments abroad.
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Zhang, Jin, Xiuling Yin, Zuxin Li, Dufen Sun, and Shenaoyi Liu. "Reform and amendment of Russian petroleum fiscal term: trends and implication to asset acquisition." Oil & Gas Science and Technology – Revue d’IFP Energies nouvelles 75 (2020): 43. http://dx.doi.org/10.2516/ogst/2020042.
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This article analyzes reform and amendment of petroleum tax policy in Russia to investigate instability of tax regime which is one of the main concerns for decision making in asset acquisition. Historical and recent amendments of upstream fiscal terms in Russia are reviewed and studied in an attempt to understand the trends of reform. Tax burden of four different cases is modeled with the change of tax policy to analyze the effect of tax incentives. The recent “tax maneuver” of transferring export duty to Mineral Extraction Tax (MET) is studied in detail to analyze effects to upstream, refinery, and customers. Net present values of three field cases under previous tax regime and new Added Income Tax (AIT) regime are comparatively studied with cashflow modeling. The article concludes that recent “tax maneuver” has indirect influence on upstream sector but may lead to upward pressure on retail. New AIT regime introduces a universal taxation system and requires less government intervention, which may reduce aboveground risk of unstable fiscal regime and boost international investment in Russia. Also, key suggestions are summarized for international investors who are interested in oil and gas asset in Russia.
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Olujobi, Olusola Joshua. "Analysis of the Legal Framework Governing Gas Flaring in Nigeria’s Upstream Petroleum Sector and the Need for Overhauling." Social Sciences 9, no. 8 (2020): 132. http://dx.doi.org/10.3390/socsci9080132.
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Nigeria is rated the number one producer of crude oil in Africa. Still, oil exploration activities have resulted in a high rate of gas flaring due to weak enforcement of the anti-gas flaring laws by the regulatory authorities. Associated natural gas is generated from oil production, and it is burnt in large volumes, thereby leading to the emission of greenhouse gases and waste of natural resources which could have generated billions of dollars for the Federal Government of Nigeria. There are concerns that if nothing is done to curtail this menace, humans and the environment will be imperiled due to its negative consequences. There is therefore a need to decrease gas flaring by replicating the strategies applied in the selected case study countries to combat the menace. It is relevant to carry out this analysis to reduce greenhouse gas emissions in the oil industry for the sustainability of the energy sector and to generate more revenues for the government. This study provides guidelines for legislatures on suitable approaches to adopt for formulating an anti-flaring legal framework. The study is a comparative analysis of national legal regimes on gas flaring in Nigeria, Canada, the United Kingdom, Saudi Arabia, and Norway. The study adopts a doctrinal legal research method, a point-by-point comparative approach with a library-based legal research method. The study finds that weak enforcement of laws is a critical factor responsible for the menace. It recommends the use of more advanced technologies, a sophisticated mixture of regulations and non-regulatory incentives such as fiscal policies and gas market restructuring, and proffers further suggestions based on the lessons learnt from the selected case study countries.
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Lin, Kun-Chin. "Protecting the petroleum industry: renewed government aid to fossil fuel producers." Business and Politics 16, no. 4 (2014): 549–78. http://dx.doi.org/10.1515/bap-2014-0019.
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The dual pressures of the global economic crisis in 2008 and high crude prices through the subsequent recovery period have prompted oil-producing countries to adopt a wide range of protectionist measures including subsidies in all forms and trade and investment restrictions. Focusing on fiscal and industrial policy adjustments in the UK and the People's Republic of China since 2008, this paper argues that both governments have sought an increase in tax contributions from the corporate sector in exchange for intensified, targeted support for specific capital investments that will address the challenges of overall decline in domestic oil production and new field exploration and oil recovery opportunities. These novel “rent-sharing” schemes – inadequately captured in recent academic debates over precise measurements of fuel subsidies – raise concerns for fair competition in the upstream market and politicians’ long-term commitment to the transitioning of energy mix toward green and renewable sources.
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Rachman, Andika, and R. M. Chandima Ratnayake. "Adoption and implementation potential of the lean concept in the petroleum industry: state-of-the-art." International Journal of Lean Six Sigma 10, no. 1 (2019): 311–38. http://dx.doi.org/10.1108/ijlss-10-2016-0065.
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Purpose A systematic literature review is performed to reveal the state-of-the-art in the implementation of lean principles in the petroleum industry. This paper aims to generate a conceptual framework and reveal research gaps with respect to lean concept application in the petroleum industry. Design/methodology/approach After formulating research questions, the search strategy is generated, followed by data extraction, literature review and synthesis of the results. The search covers any studies in peer-reviewed scientific journals and conference proceedings in the period 1990-2017 that discuss the implementation of the lean concept in the petroleum industry. Findings The lean concept has been used to improve operational and technical aspects, contractor/supplier relationships, team organization and project management practice in the petroleum industry. Based on the literature review, a conceptual framework is generated comprising four main elements: leadership and commitment from management, employee involvement, cooperation and trust with contractors/suppliers and lean project management. These elements are the pillars that are founded on lean philosophy and principles to support technical/operational improvement in the organization. The types of literature identified indicate that the subject of the study is still immature. Research limitations/implications This study focuses only on the upstream sector of the petroleum industry, which restricts the generalizability of the results to midstream and downstream businesses. Practical implications This paper provides knowledge and information regarding the current state of lean implementation in the petroleum industry. The developed conceptual framework provides general guidance for practitioners regarding lean implementation in the petroleum industry, and is also expected to support research on theory building. Originality/value Few studies have discussed the application of the lean concept in the petroleum industry. This paper contributes a platform for researchers and practitioners to comprehend how the lean concept has been applied in the petroleum industry, and provides a foundation for further studies on lean implementation in the petroleum industry.
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Renner Nrior, Renner. "Ultimate Biodegradation of Industrial Detergent Used in the Upstream Sector of the Nigeria Petroleum Industry in Freshwater, Brackish and Marine Water." International Journal of Ecotoxicology and Ecobiology 2, no. 4 (2017): 134. http://dx.doi.org/10.11648/j.ijee.20170204.11.
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SAIDU, SANI, and ABDEL RASHEED MOHAMMED. "The Nigerian Petroleum Industry Bill: An Evaluation of the Effect of the Proposed Fiscal Terms on Investment in the Upstream Sector." Journal of Business and Management Sciences 2, no. 2 (2014): 45–57. http://dx.doi.org/10.12691/jbms-2-2-3.
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Wee, Kenneth. "Shining the spotlight on the petroleum resource rent tax." APPEA Journal 58, no. 2 (2018): 643. http://dx.doi.org/10.1071/aj17209.
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The petroleum resource rent tax (PRRT), a 40% profits-based upstream tax that applies to Australian oil and gas projects, has come under significant scrutiny as to its effectiveness in providing an appropriate return to the community for the exploitation of Australia’s petroleum resources. The April 2017 independent Callaghan review into the design and operation of the PRRT found that it remained the preferred way of achieving a fair return to the community from petroleum exploration and recovery, without discouraging investment into the sector. However, the Callaghan review recommended possible changes to the regime to improve its sustainability and compatibility with the current state of the industry, while ensuring fiscal stability for existing investments. In response to the findings and recommendations of the Callaghan review, Australian Treasury embarked on a consultation process to investigate potential reform options to the PRRT. Government has yet to announce its decision on the way forward. What the future holds for the PRRT and the consequential impact on existing and new or proposed projects remain to be seen pending the Government’s chosen policy direction. This paper covers the following: • a survey of the economic rent theory underpinning the framework of the PRRT regime, including its pros and cons compared with other forms of resource taxation • a review of key recent developments in the administration and interpretation of the PRRT law, and • how the PRRT regime is anticipated to change and the associated repercussions on the after-tax economics and practical compliance for existing and future projects.
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Lockhart, Deborah, and Jessica Xu. "How the upstream oil and gas industry can leverage interdisciplinary research to more effectively engage with Indigenous communities." APPEA Journal 61, no. 2 (2021): 417. http://dx.doi.org/10.1071/aj20150.
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Since 2010, mining companies have requested permission for the destruction of over 463 Aboriginal heritage sites. Recent high-profile events have profoundly impacted culturally significant Indigenous sites, and mining companies are under intense pressure to demonstrate greater sensitivity in their relationships with stakeholders. The Australian Disputes Centre uses several case studies to explore how the upstream petroleum industry can leverage current interdisciplinary research to engage with Indigenous communities more effectively, both nationally and internationally. Interest-based negotiation frameworks are considered as actionable mechanisms that are as applicable in day-to-day business operations as they are in supporting consistent, culturally-sensitive stakeholder agreements. The application of a range of communication strategies and skills to harness intersectional decision-making is reviewed, and asks the extent to which engagement with external stakeholders reflects internal corporate culture. Obtaining and retaining a social licence to operate is top of mind for all resource companies, but it does not come without a congruent culture of principled negotiation. This study considers the emerging challenges within the sector, including how to empower all parties to negotiate more fulsome outcomes. Using various case studies, including one involving the conservation of submerged Indigenous heritage, an holistic, interdisciplinary methodology for managing cross-cultural sensitivities while companies undertake technical investigations, liaise with archaeological and ethnographic experts and negotiate with local community leaders has been reviewed. Clearly, inclusive communication is just the beginning.
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Muhibudeen, Latifat, and Sadiya Abdulrahman. "Compliance with Statement of Accounting Standard 14 by Listed Oil and Gas Firms in Nigeria." Applied Finance and Accounting 6, no. 1 (2019): 15. http://dx.doi.org/10.11114/afa.v6i1.4632.
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The study aimed at examining the financial statements of Companies in the Nigerian petroleum industry in other to determine their level of transparency which is a function of their level of compliance with the provisions of Statements of Accounting Standards (SAS) 14 in the upstream sector. Data were collected from annual reports and accounts of the 14 listed oil companies for the period of five years 2013 to 2017. They were analyzed using compliance index, descriptive statistics, correlation and regression. The result reveals that oil and gas companies in Nigeria strongly complied with the requirements of SAS14 with 92.44%. It also shows that the age, size of assets, ROA and Leverage of the companies have insignificantly effect on SAS 14. The study recommends that International Accounting Standard Board, Financial Reporting Council and other relevant regulatory bodies to, as a matter of urgency, commission additional and effective follow up campaigns and supervision aimed at enlightening not only corporate bodies but also individual stakeholders on the benefits derivable from compliance with requirement of SASs.
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Egede, Hephzibah. "Regulation of The Upstream Petroleum Sector: A Comparative Study of Licensing and Concession Systems edited by TinaHunter Published by Edward Elgar, 2015, 392 pp. + xxxiii, £115, hardback." Review of European, Comparative & International Environmental Law 28, no. 2 (2019): 223–24. http://dx.doi.org/10.1111/reel.12297.
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Higgs, W. G., and P. E. Prass. "AUSTRALIAN GTL CLEAN DIESEL: A STRATEGIC OPPORTUNITY FOR AUSTRALIA’S STRANDED GAS RESERVES." APPEA Journal 42, no. 2 (2002): 121. http://dx.doi.org/10.1071/aj01064.
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Australia’s lack of gas supply infrastructure and market opportunities means that in the northwest of our nation more than 100 trillion cubic feet of gas remains uncommitted to customer contracts.Because of Western Australia’s relatively small domestic gas markets and the long transport distances to larger markets, the belief has been that only the LNG industry has the scale to monetise the large volumes of gas required to underpin greenfield developments and expansion of gas supply infrastructure.Changing fuel specifications around the world, combined with the limited opportunities for new LNG contracts, has renewed interest in gas-to-liquids (GTL) technology as an alternative to crude oil refining for a source of clean and efficient transport fuels. GTL is an exciting new market opportunity for Australian gas.Exploration interest in Australia appears to be waning. Declining opportunities for oil discoveries and the lack of markets for natural gas make investments in Australia’s upstream sector unattractive compared to other locations around the world.In addition, Australia has dwindling crude oil supplies and faces the prospect of increasing reliance on imported crude oil and refined products. An Australian GTL Clean Diesel industry can help overcome these hurdles by creating a designer blendstock and a valuable new GTL Clean Diesel export industry.A GTL Clean Diesel industry would not only help resolve many of Australia’s current upstream and downstream problems in the petroleum industry, but would also provide massive economic benefits to Australia.This paper will look not only at the making but also the marketing of this fuel of the future.
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Bomasang, Rufino B. "THE EMERGING PHILIPPINE NATURAL GAS INDUSTRY AND OPPORTUNITIES FOR FOREIGN INVESTMENT." APPEA Journal 36, no. 1 (1996): 622. http://dx.doi.org/10.1071/aj95042.
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The main Philippine energy policy objectives are availability of energy supply; competitive, affordable, and reasonable energy prices; and environmentally compatible energy infrastructure. A key strategy in the pursuit of these objectives is expanded natural gas utilisation.Development of the Camago-Malampaya gas field in offshore northwest Palawan is the vital anchor of the emerging Philippine gas industry. It has proven reserves of 3–4 trillion cubic feet, enough to supply a 3,000 megawatt power plant, but located in very deep water (over 800 m) and far away from the market (requiring 500 km of pipeline). Nevertheless, the developers (Shell and Occidental Petroleum) are prepared to develop the field and build a 24-inch offshore pipeline to transport the gas to power plants in Luzon which independent power producers are likewise prepared to put up, all to be completed by 2001–2002. Total capital requirements from upstream to downstream are estimated at US$4–5 billion.While the initial gas market will be limited to power generation, the government intends to expand the use of gas to the industrial, commercial/residential, and transport sectors. To assure reliable gas supply to the entire gas industry, the government is actively promoting gas exploration and supports LNG importation to supplement indigenous gas.With the government's policy of maximising private sector participation, the gas industry offers tremendous foreign investment opportunities includingindigenous gas exploration/development;pipeline construction;LNG supply and construction/operation of LNG infrastructure;independent power production; anddevelopment of new gas markets.
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Arafeen, Qamar Ul. "Multi-Dimensional Effect of Oil Pricing On Pakistan Economy: A Case of Study." IBT Journal of Business Studies 14, no. 2 (2018): 209–20. http://dx.doi.org/10.46745/ilma.jbs.2018.14.02.17.
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Pakistan economy is growing steadily. This growth demands higher energy consumption and consequently putting high pressure on countries economy. Pakistan mainly depends upon oil and gas resources to fulfill energy requirements. Indigenous resources of Oil are not enough to quench energy thirst of the growing economy. As a result Pakistan has to import large quantity of oil and oil based products from Middle East countries. Gas reserves in the country are enough for current gas requirements. So natural gas is playing a key role in power sector. Currently in oil upstream and downstream sector there are some local and international companies involved and government of Pakistan is establishing such policies that it can attract more international investors in this sector but the rapid pace of change, high degree of uncertainty and unstable political situation of the country present significant challenges and risk to foreign investment. The paper is a review of possible consequences and challenges presented by high oil prices in Pakistan. Pakistan is heavily dependent on imported fuels and this dependence is expected to increase even further in future given the depleting gas resources. The rising oil prices in the international market has had affected negatively balance of payment position as well as on the budgetary position of the country and contributed in creating inflationary pressures in the economy. For long run development oil will remain an important source of energy. The government should chalk out strategies for ensuring efficiency in use; and development, adequacy and reliability of supply and the pricing of petroleum products in such a way that will not create extra burden on the consumers. Unless appropriate steps are taken this trend of rising oil prices will further aggravate the negative impacts on the economy.
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Heiden, K. "ASSESSMENT AND APPROVAL OF PETROLEUM ACTIVITIES UNDER THE COMMONWEALTH ENVIRONMENT PROTECTION AND BIODIVERSITY CONSERVATION ACT 1999—LESSONS LEARNED." APPEA Journal 43, no. 1 (2003): 779. http://dx.doi.org/10.1071/aj02047.
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This paper provides a brief overview of the Environment Protection and Biodiversity Conservation Act 1999 (the Act) with respect to the upstream petroleum industry and focusses on the aspects of assessments and approvals under the Act.The inception of the Act on 16 July 2000 has created a new environmental assessment and approval regime at the Commonwealth level. No longer are proposals referred for assessment on the basis of government decisions, but on the basis of the potential for a proposal to impact upon a matter of National Environmental Significance (NES). Examining the statistics of referrals made, controlled actions determined and approvals granted, provides a useful guide as to the types of activities that are captured by the Act. This exercise is particularly valuable for the oil and gas sector.With more than 20 of the referrals received from the petroleum sector being determined to be controlled actions (that is, actions that are likely to have a significant impact upon matters of NES), a review of the assessment and approval processes under the Act provides some useful insights into what factors to consider when seeking approval under the Act. In particular, information on the timeframes involved, extent of information required, form and scope of approval conditions and synergies with other approval requirements provide valuable insights to proponents and can assist in planning future activities in a manner that is consistent with both the requirements of the Act and those of the proposed action.This paper identifies key issues and lessons for proponents when seeking approval under the Act and also identifies areas where industry can work closely with the Commonwealth Government in ways to achieve a balance between environmental protection and the continued development of the oil and gas industry.
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Joumayle, Omar A. M. El. "Oil production and abrupt institutional change: the multi-cyclic Hubbert model and the case of Iraq." Contemporary Arab Affairs 10, no. 2 (2017): 256–85. http://dx.doi.org/10.1080/17550912.2017.1302059.
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Iraq, one of the world's leading crude oil producers with the fifth largest share of proven global oil reserves, recently ranked as the second-largest producer among Organization of the Petroleum Exporting Countries (OPEC) members. Nevertheless, performance of the upstream subsector in terms of oil production volume has been subject to severe disruptions for more than four decades. The main sources for these fluctuations are multi-institutional changes caused by nationalization, wars and United Nations sanctions. This article applies to the Iraqi case an extended version of the multi-cycle Hubbert model, developed by Reynolds and Kolodziej in 2008 and 2009. This econometrics model explores and attempts to quantify statistically the relationship between oil production and multi-institutional changes within Iraq. Findings indicate the negative and significant impacts of abrupt institutional change on the performance of the oil industry where this adverse impact varies in magnitude from one episode to another. As Iraq is still yet in the midst of a turbulent transition, the article also discusses the major challenges of the post-2003 era, associated with the present and potential future development of the Iraqi oil-producing sector. This is especially with regard to the increasing economic and political fragmentation that stems from the absence of a unified oil policy.
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Brasoveanu, Sergiu. "Oil and gas business in changing times." Proceedings of the International Conference on Business Excellence 11, no. 1 (2017): 9–24. http://dx.doi.org/10.1515/picbe-2017-0002.
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Abstract The top 5 oil majors (British Petroleum, ExxonMobil, Total, Chevron and Royal Dutch Shell) are analyzed in terms of investments, earnings and financial & operational performance along the entire business value chain, for a period of 5 years. One of the key objectives is to understand how the Upstream and Downstream segments may play different roles in the definition of a winning corporate strategy, considering how they may reveal very different strengths and weaknesses during crude oil price crises. When the crude oil price goes down, the upstream sector is running big cost cutting measures, in order to reduce expenditures and keep acceptable gross margins per barrel of oil equivalent. On the other hand, the downstream segment receives cheaper raw material without a significant decrease in the final price of the oil products. Thus, how can oil companies leverage this flexibility in order to pass successfully through periods of crude oil price slides, and even take advantage of those? The paper aims to analyze the correlation between oil price and oil volume produced on one hand, and investments and earnings, split by business segments, on the other hand. The variation of investment and earnings is hence compared to crude oil price fluctuations for a clearer picture of the business profitability per segment during the peak and bottom periods of the oil market. Upstream and Downstream segments are also benchmarked against each other to understand the role that each of them is playing in the industry. The results are expected to provide some trend lines to understand how much the cost cutting measures are impacting the overall business, as well as to appreciate whether the reduction in the oil production, which in theory should be followed by a rise in prices, is indeed in the best interest of the oil majors. Going further into analysis, the paper is trying to define an optimum production interval, that will maximize profits along the entire value chain (upstream and downstream) of the oil business, defined by both the production volume of crude oil (replacement cost per barrel in accordance with volume), as well as the price per barrel of oil equivalent. The analysis takes into account official sources exclusively, i.e. oil companies’ websites, corporate crude oil production reports, annual financial reports and investors’ analyses.
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Lin, Jianyi, Shihui Cheng, Huimei Li, Dewei Yang, and Tao Lin. "Environmental Footprints of High-Speed Railway Construction in China: A Case Study of the Beijing–Tianjin Line." International Journal of Environmental Research and Public Health 17, no. 1 (2019): 105. http://dx.doi.org/10.3390/ijerph17010105.
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The environmental footprints of China’s high-speed railway (HSR) have attracted much attention nationally and internationally. Although there is some research focusing on CO2 emissions, a comprehensive environmental impacts assessment of HSR construction is still lacking. In this study, the emissions of the Beijing–Tianjin intercity HSR line was calculated using a hybrid input–output life cycle assessment method to quantify the environmental impacts of HSR throughout its construction. The environmental footprints during the construction stage were analyzed in terms of different subsystems and sectors. The results showed that bridges contribute the largest environmental footprints at approximately 60%, followed by rail and electric multiple unit (EMU) systems. The top three sectors that contribute to pollutant emissions are the metal smelting and rolling industry, transport equipment manufacturing, and non-metallic mineral production. CO2 and NOx are the major pollutants directly emitted by site equipment operation. More chemical oxygen demand (COD), total phosphorus (TP), total nitrogen (TN), and petroleum are emitted in EMU production than in rail construction, while NH3-N is emitted more in rails instead. Cd, Pb, As, and Hg are the significant pollutants in the metal smelting and rolling industry, whereas Cr, Cu, and Zn are the main heavy metal emissions in the transport equipment manufacturing sector. Heavy metals are the main types of environmental footprints in bridges, stations, and electric systems. Water pollutants are the main environmental impacts for rail and EMU systems, and the emissions of air pollutants are significant in subgrades. The production efficiency of upstream materials, desulfurization and denitration in fossil combustion, and the length of the bridge construction should be considered for an HSR under construction, in order to become environmentally friendly and sustainable.
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Goldstein, Barry, Michael Malavazos, Belinda Hayter, et al. "Regulatory nirvana for low-permeability gas reservoir development." APPEA Journal 52, no. 1 (2012): 351. http://dx.doi.org/10.1071/aj11028.
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‘Trusted land access is both the first factor and the final outcome of a virtuous exploration and production life-cycle’ (Goldstein et al, 2007). Governments are under pressure to deploy trusted regulatory frameworks that enable profitable and environmentally sustainable development of unconventional gas resources for matters including, but not limited to, fracture stimulation operations. Nirvana regulation will entail: attractive licence tenure; regulatory certainty and efficiency without taint of capture; regulators and licensees with trustworthy capabilities (competence and capacity); effective (informative) stakeholder consultation well-ahead of land access; public access to details of risks and reliable research to reduce key uncertainties, and to back-up risk management strategies so the basis for regulation is contestable anytime, everywhere; timely notice of entry with sufficient operational details to effectively inform stakeholders; potentially affected people and organisations who can object to land access without support for vexatious objections; fair and expeditious dispute resolution processes; fair compensation to affected land-users for costs, losses, and deprivation due to operations; risks that are reduced to low or as low as reasonably practicable (ALARP) while also meeting community expectations for net outcomes; licensees who monitor and report on the efficacy of their risk management processes, while the regulator probes the same; regulators who can prevent and stop operations, require restitution, levy fines and cancel licences; and, industry compliance records, which are made public so the efficacy of regulation is transparent. This paper will describe how these principles are deployed in SA where: 24 unconventional gas play-trends are being explored, each with giant gas potential; hundreds of wells have been safely hydraulically fracture stimulated to enhance flow rates from both petroleum and geothermal reservoirs, and in doing so, enable economic development; and, since implementing SA’s Petroleum and Geothermal Energy Act 2000, more than 11,000 notices of entry for petroleum operations have led to just one court action, and that was to establish legal precedent that geophysical surveys can extend outside a licence to attain full-fold control in a licence. The introduction of new energy development technologies is inevitable, so regulatory nirvana will remain an aspiration. Regulation for compatible, multiple-use of land in Australia is undertaken with community ownership of subsurface resources in mind. SA aspires to achieve regulatory nirvana for the upstream petroleum sector. Expeditious, welcomed access to land for compatible, multiple uses is the metric for performance, and leading practice is based on the principle that trust is the most valuable lead factor and lag outcome in sustaining welcomed land access for resource exploration, development and production.
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Feder, Judy. "SPE Technical Directors’ Outlook - The Industry’s Transformation in 2020 and What It Means for the Future." Journal of Petroleum Technology 73, no. 02 (2021): 23–28. http://dx.doi.org/10.2118/0221-0023-jpt.
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For an industry in which terms like “first ever,” “unparalleled,” “unprecedented,” and “novel” are often over-used to the point of losing their meaning, 2020 hit hard with the true meaning of those words as the COVID-19 pandemic exploded onto the world and disrupted almost everything about life as we knew it. The oil and gas industry, which had begun showing signs of recovery from a generational downturn, was hit particularly hard. Jobs were lost, companies shuttered, and supply chains upended. But the same combination of audacity and ingenuity that has driven the industry for over a century took hold quickly. Oil and gas people love - and need - to network, share ideas, transfer and apply technology, and gather intelligence. So, when in-person conferences, workshops, and tradeshows were suddenly canceled or indefinitely postponed, entities such as the Society of Petroleum Engineers scrambled to use digital technology to take those events online and make them virtual. While not a perfect replacement, virtual online events offer some unique advantages, as SPE technical directors pointed out in their annual roundup. Digitalization, long a controversial topic among many in the upstream sector, is now being called essential by the directors across the six SPE technical disciplines they lead. Automation is mentioned frequently in the directors’ comments as a growing contributor to efficiency and risk reduction. Capital discipline, balance sheet management, and cash flow are seen as crucial, as are collaboration (both internal and external) and value - ranging from core values to value-driven data, to provable, value-based outcomes. Agility and the ability to comply with environmental, social, and governance (ESG) criteria have taken on new importance. So has work - how and where we do it, and how we balance it with other aspects of life. Knowledge dissemination is considered more important than ever. Uncertainty continues to characterize the upstream sector, even more so than before the pandemic, but at least one thing is certain: The work of the industry, and the way in which people who comprise it work, is forever changed. The SPE technical disciplines and the directors who lead them are as follows. Completions - Terry Palisch, CARBO Ceramics Data Science and Engineering Analytics - Silviu Livescu, Baker Hughes Drilling - David Reid, NOV HSE and Sustainability - Annamaria Petrone, Eni Production and Facilities - Robert Pearson, Glynn Resources Reservoir - Erdal Ozkan, Colorado School of Mines Here, they reflect on a truly unprecedented year and share their outlooks for their disciplines going forward.
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Sonaike, Kola. "Labor Union Leadership And Career Advancement In Major Nigerian Oil Companies." International Business & Economics Research Journal (IBER) 11, no. 12 (2012): 1397. http://dx.doi.org/10.19030/iber.v11i12.7418.
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Labor related issues in the upstream sector of the Nigerian oil industry started to emerge soon after the discovery of petroleum in commercial quantities within the Niger Delta area mid- 1950s (Shell, 2000). Different groups within and outside the oil industry formed opinions about union leaders in the most strategic industry in the country. This was in part the case because the work force became better educated than their predecessors. One group among the industrys stakeholders believe labor union leaders have been ill treated, penalized, and stagnated, over the years by their managements. Supervisors and managers, it is alleged, act repulsively and harassingly towards union leaders in order to suppress their activities. Others believe the union leaders have been pampered and favorably treated by the managements of these companies in order to maintain peace. This study sets out to discover whether or not these notions about labor union leaders in the major oil companies in Nigeria are true. In this regard, ten null hypotheses were tested to accept or reject the notion that union leaders are not favored, are not educationally qualified, are not productive, are not militant, are not loyal, are not penalized for holding labor union leadership positions, cannot progress beyond executive status and cannot score more than 70 percentile on the researchers charismatic and superior leadership scale. One of the hypotheses was tested using ANOVA, two were tested using Kruskal-Wallis, and seven were tested using Chi-Square. The research findings highlighted some areas that the management of major oil companies and the federal government of Nigeria need to look into. Management of these companies need to look into the issue of the small group of managers and supervisors in the companies who still view labor unionism in negative light and consider labor union leaders as mere loafers and trouble makers. Training programs in labor unionism need to be carried out on regular basis for union leaders, managers, and supervisors in these companies. Further, the federal government of Nigeria needs to look into the perennial labor-related conflicts between the major oil companies and their host communities.
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Abramov, Aleksandr. "Agile methodology of well pad development." Journal of Petroleum Exploration and Production Technology 10, no. 8 (2020): 3483–96. http://dx.doi.org/10.1007/s13202-020-00993-3.
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Abstract Placing of wells in clusters with unequal number of thereof is an emerging concept of well pad development which still requires scrutiny even from a theoretical standpoint. The concept has its potential in improving economic efficiency of one of the most capital intensive processes in upstream sector of petroleum industry—the well pad drilling. To advocate and strengthen this profitability enhancing potential, this work integrates clustering of unequal number of wells into modern project management methodologies (agile project management), which has not been done before. It is shown that such symbiosis, which is called here the adaptive well pad development (or agile methodology of well pad development), has twofold benefit consisting of (1) managing of and accounting for uncertainties of real projects and (2) further improving economic performance of development projects in comparison with standalone well pad configurations with unequal number of wells. To exemplify these advantages, detailed simulations of well pad drilling projects were performed with equal and unequal number of wells in clusters. The simulation model accounting for more than 40 parameters and individual features of wells shows that combination of unequal well clustering configurations with adaptation of well pad designs to updates in project parameters results in significant improvements to the net present value (NPV). For three drilling scenarios studied in this work, the NPV increments ranged from 8 to 36%. Additionally, it was found that groupings with unequal number of wells consistently outperform groupings with equal number of wells in uncertain conditions, and NPV improvements from 10 to 20% have been obtained. These findings enrich understanding of the vast space of clustering schemes with unequal number of wells and demonstrate how these well pad configurations can be applied to use ever-changing environment to one's advantage. On basis of this computational study, it is now valid to assert with high degree of certainty and confidence that industrial deployment of clustering with unequal number of wells in combination with proper organizational measures results in boost to the NPV of well pad development projects at the level of several to tens of percent.
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Jacobs, Trent. "Canadian Operator Works To Transform an Oil Field Into a Hydrogen Factory." Journal of Petroleum Technology 73, no. 03 (2021): 38–40. http://dx.doi.org/10.2118/0321-0038-jpt.
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As the oil and gas industry scans the known universe for ways to diversify its portfolio with alternative forms of energy, it might want to look under its own feet, too. For inside every oil reservoir, there may be a hydrogen reservoir just waiting to get out. The concept comes courtesy of Calgary-based Proton Technologies. Founded in 2015, the young firm is the operator of an aging heavy oil field in Saskatchewan. There, on a small patch of flat farm-land, Proton has been producing oil to pay the bills. At the same time, it has been experimenting with injecting oxygen into its reservoir in a bid to produce exclusively hydrogen. Proton says its process is built on a technical foundation that includes years of research and works at the demonstration scale. Soon, the firm hopes to prove it is also profitable. While it produces its own hydrogen, Proton is licensing out the technology to others. In January, fellow Canadian operator Whitecap Resources secured a hydrogen production license of up to 500 metric tons/day from Proton. Whitecap produces about 48,000 B/D, and thanks to carbon sequestration, the operator has claimed a net negative emissions status since 2018. Proton says it has struck similar licensing deals with other Canadian operators but that these companies have not yet made public announcements. Where these projects go from here may end up representing the ultimate test for Proton’s innovative twist on the in-situ combustion process known so well to the heavy-oil sector. “In-situ combustion has been used in more than 500 projects worldwide over the last century. And, they have all produced hydrogen,” said Grant Strem, a cofounder and the CEO of Proton. Strem is a petroleum geologist by back-ground who spent the majority of his career working on heavy-oil projects for Canadian producers and research analysis with the banks that fund the upstream sector. While his new venture remains registered as an oil company, the self-described explorationist has come to look at oil fields very differently than he used to. “In an oil field, you have oil—hydrocarbons, which are made of hydrogen and carbon. The other fluid down there is H2O. So, an oil field is really a giant hydrogen-rich, energy-dense system that’s all conveniently accessible by wells,” Strem explained. But, in those past examples, the hundreds of other in-situ combustion projects, hydrogen production was merely a byproduct, an associated gas of sorts. It was the result of several reactions generated by air injections that producers use an oxidizer to heat up the heavy oil and get it flowing. What Proton wants to do is to super-charge the hydrogen-generating reactions by using the oil as fuel while leaving the carbon where it is. That ambition includes doing so at a price point that is roughly five times below that of Canadian natural gas prices and an even smaller fraction of what other hydrogen-generation methods cost.
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Slater, Sue. "PESA industry review—2009 environmental update." APPEA Journal 50, no. 1 (2010): 143. http://dx.doi.org/10.1071/aj09010.
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This paper provides a brief update on some of the key environmental issues that arose during 2009. In Queensland, activity is dominated by coal seam gas projects and specifically coal seam gas (CSG) to liquefied natural gas (LNG) projects. Environmental milestones for these projects are discussed, and the State Government’s response policy and regulation development response is reviewed. The progress of the more conventional LNG projects in Western Australia and the Northern Territory is also discussed. The final report on the mandated ten year review of the Environment Protection and Biodiversity Conservation Act 1999 was released in December 2009. Seventy-one recommendations were made, and some key recommendations related to our industry are discussed here. Climate change has again dominated the media, with the United Nations Climate Change Conference held in Copenhagen in December 2009. In Queensland, the Government released a paper that presented a range of strategies and policies, building on a number of existing schemes and introducing new measures. Gas is identified as a key transitional fuel while low emission coal technology and emerging renewable energy sources are being developed. Greenhouse gas legislation is continuing to be developed across several states, but subordinate legislation is yet to be finalised. In Victoria, submissions on the Greenhouse Gas Geological Sequestration Regulations closed in October 2009, and the Greenhouse Gas Geological Sequestration Act 2008 came into effect on 1 December 2009. In March 2009, ten offshore acreage releases were made under the Commonwealth legislation; however, the closing date for submissions is dependent upon the development of the regulations. South Australia passed an Act amending the Petroleum and Geothermal Act 2000 on 1 October 2009 to allow geosequestration. A number of reviews of the regulatory framework or the administrative systems associated with the upstream oil and gas sector have been completed in the last decade. All these reviews make similar findings and recommendations, and most recently the Jones Report, tabled in Western Australian Parliament on 12 August 2009, found that most key recommendations from previous reports and reviews had not been addressed or properly implemented. There seems to be little point in undertaking regulatory and system reviews that consistently make similar findings, if these findings are never addressed. The hurdles to implementation of key recommendations need to be identified, so that progress can be made in improving the approvals processes for the industry, and improving the environmental outcomes.
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Al-Salem, S. M., and A. R. Khan. "Monitoring and Modelling the Trends of Primary and Secondary Air Pollution Precursors: The Case of the State of Kuwait." International Journal of Chemical Engineering 2010 (2010): 1–12. http://dx.doi.org/10.1155/2010/879836.
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Since the beginning of the industrial revolution, processes of different scales have contributed greatly to the pollution and waste load on the environment. More specifically, airborne pollutants associated with chemical processes have contributed greatly on the ecosystem and populations health. In this communication, we review recent activities and trends of primary and secondary air pollutants in the state of Kuwait, a country associated with petroleum, petrochemical, and other industrial pollution. Trends of pollutants and impact on human health have been studied and categorized based on recent literature. More attention was paid to areas known to researchers as either precursor sensitive (i.e., nitrogen oxides (NOx), volatile organic compounds (VOCs)) or adjacent to upstream- or downstream-related activities. Environmental monitoring and modelling techniques relevant to this study are also reviewed. Two case studies that link recent data with models associated with industrial sectors are also demonstrated, focusing mainly on chemical mass balance (CMB) and Gaussian line source modelling. It is concluded that a number of the monitoring stations and regulations placed by the Kuwait Environment Public Authority (KUEPA) need up-to-date revisions and better network placement, in agreement with previous findings.
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Su, Yuqi, Yi Liang, Li Chai, et al. "Water Degradation by China’s Fossil Fuels Production: A Life Cycle Assessment Based on an Input–Output Model." Sustainability 11, no. 15 (2019): 4130. http://dx.doi.org/10.3390/su11154130.
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Fossil energy production not only aggravates water depletion but also severely contaminates water resources. This study employed a mixed-unit input–output model to give a life cycle assessment of national average water degradation in production of common types of fossil fuels in China. The results show that the amount of grey water generated is much more than that of consumptive and withdrawn water in all cases. Although there is a high discharge amount of chemical oxygen demand (COD) in fossil fuel production, the pollutants of petroleum (PE) and volatile phenols (VP) require more dilution water than COD. PE is the greatest contributor to water degradation caused by primary fossil fuels, while VP pollution is prominent in production of upgraded fossil fuels. Basically, the main causes of water degradation, PE and VP discharge, occurs at coal mines, oil fields, refinery plants, and coking factories, rather than in the upstream sectors. A scenario analysis showed that water pollution can be significantly reduced if VP discharge in the coking process is controlled to be at the standard concentration. PE requires a standard withalower discharge concentration in order to further mitigate water pollution in production of fossil fuels. The coal production industry has a much lower pollutant removal rate but spends more on wastewater treatment, up to 12% of its profit. The other fossil fuel industries have high removal rates of PE and VP (97%–99%) and thus demand technological renovation to further remove those pollutants at a low concentration.
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JPT staff, _. "E&P Notes (January 2021)." Journal of Petroleum Technology 73, no. 01 (2021): 18–19. http://dx.doi.org/10.2118/0121-0018-jpt.
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GOM Lease Sale Generates $121 Million in High Bids; Shell Offshore Takes Top Spot Regionwide US Gulf of Mexico (GOM) Lease Sale 256 generated $120,868,274 in high bids for 93 tracts in federal waters. The sale on 18 November featured 14,862 unleased blocks covering 121,875 square miles. With $27,877,809 spanning 21 high bids, Shell Offshore Inc. took the top spot among 23 competing companies. A total of $135,558,336 was offered in 105 bids. Among the majors, Shell, Equinor, BP, and Chevron submitted some of the highest bids. Each company claimed high bids of over $17 million, signaling the GOM remains a priority in their portfolios. Last year was a record year for American offshore oil production at 596.9 million bbl, or 15% of domestic oil production, and $5.7 billion in direct revenues to the government. Offshore oil and gas supported 275,000 total domestic jobs and $60 billion total economic contributions in the US. “The sustained presence of large deposits of hydrocarbons in these waters will continue to draw the interest of industry for decades to come,” Deputy Secretary of the Interior Kate MacGregor said. Still, as Mfon Usoro, senior research analyst at Wood Mackenzie, noted, “Although bidding activity increased by 30% from the March 2020 sale, the high bid amount of $121 million still trends below the average high bid amount seen in previous regionwide lease sales, proving that companies are still being conservative with exploration spend.” Although the Bureau of Ocean Energy Management has proposed another regionwide GOM lease sale in March 2021, Usoro predicted that Lease Sale 256 “could potentially be one of the last lease sales.” “With the Biden administration set to inaugurate next year and possibly ban future lease sales, a massive land grab might have ensued,” he continued. “But companies are constrained by tight budgets due to the prevailing low oil price. Additionally, companies in the region have existing drilling inventory to sustain them in the near term. The best blocks with the highest potential reserves are likely already leased. As a result, we do not expect a potential ban on leasing to materially impact production in the region until the end of the decade.” This was the seventh offshore sale held under the 2017–2022 National Outer Continental Shelf Oil and Gas Leasing Program; two sales a year for 10 total regionwide lease sales are scheduled for the gulf. Nine Areas on Norwegian Continental Shelf Open for Bids The 25th licensing round on the Norwegian Continental Shelf, comprising eight areas in the Barents Sea and one in the Norwegian Sea, has been announced by the Norwegian Ministry of Petroleum and Energy. Known for being a country with some of the greenest credentials and policies in the world, Norway surprised observers in June by announcing plans for a licensing round that signaled further oil exploration in the Norwegian sector of the Arctic Sea. In this round, 136 blocks/parts of blocks will be available: 11 in the Norwegian Sea and 125 in the Barents Sea. The application deadline for companies is 23 February 2021. New production licenses will be awarded in Q2 2021. Johan Sverdrup Capacity Increased to Half Million B/D Following positive results in a November capacity test, the Johan Sverdrup field is set to increase daily production capacity. Capacity will rise from today’s 470,000 to around 500,000 B/D in the second increase since the field came on stream just over a year ago. The move will increase the field’s total production capacity by around 60,000 bbl more than the original basis when the field came on line. Overall, the field is estimated to have resources of 2.7 billion BOE. “The field has low operating costs, providing revenue for the companies and Norwegian society, even in periods with low prices,” said Jez Averty, Equinor’s senior vice president for operations south in development and production, Norway. The Johan Sverdrup field uses water injection to secure high recovery of reserves and maintain production at a high level. An increase in the water-injection capacity should further increase production capacity by mid-2021, according to Rune Nedregaard, vice president for Johan Sverdrup operations. Phase 2 production starting in Q4 2022 will raise the Johan Sverdrup full-field plateau production capacity from 690,000 to around 720,000 B/D. Equinor operates the field with 42.6% stake; other partners include Lundin Norway (20%), Petoro (17.36%), Aker BP (11.57%), and Total (8.44%). ConocoPhillips Makes Significant Gas Discovery Offshore Norway ConocoPhillips announced a new natural-gas condensate discovery in production license 1009, located 22 miles northwest of the Heidrun oil and gas field and 150 miles offshore Norway in the Norwegian Sea. The wildcat well 6507/4-1 (Warka) was drilled in 1,312 ft of water to a total depth of 16,355 ft. Preliminary estimates place the size of the discovery between 50 and 190 million BOE. Further appraisals will determine potential flow rates, the reservoir’s ultimate resource recovery, and plans for development. “The Warka discovery and potential future opportunities represent very low cost-of-supply resource additions that can extend our multi-decade success on the Norwegian Continental Shelf,” said Matt Fox, executive vice president and chief operating officer. The drilling operation, which was permitted to ConocoPhillips in August 2020, was performed by the Transocean-managed Leiv Eiriksson semisubmersible rig. ConocoPhillips Skandinavia AS is the main operator of the license with a 65% working interest; PGNiG Upstream Norway AS holds the remaining stake. Lundin Energy Completes Barents Sea Exploration Well, Comes Up Dry Lundin Energy has completed exploration well 7221/4-1, targeting the Polmak prospect in licenses PL609 and PL1027, in the southern Barents Sea. The well was meant to prove hydrocarbons in Triassic-aged sandstones within the Kobbe formation of the Polmak prospect. After finding indications of hydrocarbons in a 9-m interval in poor-quality reservoir in the targeted formation, the well was classified as dry. The well was drilled 30 km east of the Johan Castberg discovery, by the Seadrill-operated West Bollsta semisubmersible rig. Lundin Energy, operator of Polmak, holds a 47.51% working interest. Partners are Wintershall DEA Norge AS (25%), Inpex Norge AS (10%), DNO Norge AS (10%), and Idemitsu Petroleum Norge AS (7.5%). Polmak is the first of Lundin’s three high-impact exploration prospects drilled this quarter in the Barents Sea; the wells target gross unrisked prospective resources of over 800 million bbl of oil. The West Bollsta rig will now proceed to drill the Lundin Energy-operated Bask prospect in PL533B. Well 7219/11-1 will target Paleocene-aged sandstones, estimated to hold gross unrisked prospective resources of 250 million bbl of oil. Tullow Sells Remaining Stake in Ugandan Oil Field Tullow Oil has completed the 10 November sale of its assets in Uganda to French giant Total for $500 million. Tullow will also receive $75 million when a final investment decision is taken on the development project, calculated to hold 1.7 billion bbl of crude oil. Contingent payments are payable after production begins if Brent crude prices rise above $62/bbl. The completion of this transaction marks Tullow’s exit from its licenses in Uganda after 16 years of operations in the Lake Albert basin. The deal is designed to strengthen Tullow’s balance sheet, as tumbling crude prices combined with exploration setbacks have created problems for the company. In September, the company reported that it had lost $1.3 billion in the first 6 months of 2020 as falling oil prices forced it to write down the value of its assets. The deal cut Tullow’s net debt to $2.4 billion; it has $1 billion in cash.
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JPT staff, _. "E&P Notes (February 2021)." Journal of Petroleum Technology 73, no. 02 (2021): 20–22. http://dx.doi.org/10.2118/0221-0020-jpt.
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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.
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Onojake, M. Chukunedum, and T. Angela Waka. "Review of Oilfield Chemicals Used in Oil and Gas Industry." Asian Journal of Physical and Chemical Sciences, April 29, 2021, 8–24. http://dx.doi.org/10.9734/ajopacs/2021/v9i230132.
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The petroleum industry includes the global processes of exploration, extraction, refining, transportation and marketing of natural gas, crude oil and refined petroleum products. The oil industry demands more sophisticated methods for the exploitation of petroleum. As a result, the use of oil field chemicals is becoming increasingly important and has received much attention in recent years due to the vast role they play in the recovery of hydrocarbons which has enormous commercial benefits. The three main sectors of the petroleum industry are Upstream, Midstream and Downstream. The Upstream deals with exploration and the subsequent production (drilling of exploration wells to recover oil and gas). In the Midstream sector, petroleum produced is transported through pipelines as natural gas, crude oil, and natural gas liquids. Downstream sector is basically involved in the processing of the raw materials obtained from the Upstream sector. The operations comprises of refining of crude oil, processing and purifying of natural gas. Oil field chemicals offers exceptional applications in these sectors with wide range of applications in operations such as improved oil recovery, drilling optimization, corrosion protection, mud loss prevention, drilling fluid stabilization in high pressure and high temperature environment, and many others. Application of a wide range of oilfield chemicals is therefore essential to rectify issues and concerns which may arise from oil and gas operational activities. This review intends to highlight some of the oil field chemicals and their positive applications in the oil and gas Industries.
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AB Naafs, Michael. "Occupational Diseases in the Petrochemical Sector and Offshore Upstream Petroleum Industry." Progress in Petrochemical Science 2, no. 2 (2018). http://dx.doi.org/10.31031/pps.2018.02.000535.
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Odion, Job Ohioma. "A critical examination of the role of public participation in petroleum development contract in Nigeria*." International Journal of Law and Management ahead-of-print, ahead-of-print (2021). http://dx.doi.org/10.1108/ijlma-02-2018-0032.
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Purpose The topic is examined with a view to ascertaining the various methods by which indigenous oil companies can participate in petroleum development contract in Nigeria. Also, the raison d’etre of the policy will be considered to see whether the government has achieved its primary aim and how successive government has approach the issue with a view to determining the best policy to adopt. The challenges facing this policy will be considered with a view to unfold whether the Petroleum Industry Bill proffers solution. Design/methodology/approach This methodology of research is doctrinaire and analytical. The author used the available statute and case law in extrapolation of the views expressed in this paper; where necessary, secondary data as sourced from existing literature was used. Findings This paper revealed that the existing laws in Nigeria do not support public participation in the petroleum sector. so much is in the hands of the government. The paper also found that this government's monopoly of the sector is one of the reasons for the slow level of development in the sector. Originality/value This paper is original to the extent that it focusses on a relatively new area of public participation in the upstream petroleum sector in Nigeria. Most papers have often focussed on the downstream sector; however, this study seeks to re-direct the debate to the upstream sector.
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"04/02284 A decision model for financial assuranceinstruments in the upstream petroleum sector." Fuel and Energy Abstracts 45, no. 5 (2004): 324. http://dx.doi.org/10.1016/s0140-6701(04)80087-0.
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Manneh, Musa. "Retail Marketing Of Imported Petroleum Products: Evidence From The Downstream Petroleum Sector Of The Gambia." European Journal of Business and Management Research 5, no. 4 (2020). http://dx.doi.org/10.24018/ejbmr.2020.5.4.365.
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The downstream petroleum sector is a key contributor to the Gambian economy with the absence of upstream petroleum exploration. The growth of the industry is highly dependent on ensuring that imported refinery petroleum products are distributed consistently and timely to consumers through an effective and efficient supply chain system as well as adopting innovative marketing programs. This is the ideal situation yearned for by stakeholders of the sector. To this effect, this research aims to explore the perspectives of retail petroleum marketing as well as challenges of petroleum import, storage and sales in the Gambia’s downstream petroleum sector. A qualitative method was adopted for the study through in-depth interviews in a semi-questionnaire format. The study discovered that OMCs downstream marketing strategies, programs and activities shifted from undifferentiated commodity imported refinery products marketing (old/previous marketing scenario) to branded value added services differentiated petroleum products (present marketing scenario) marketing owing to increase in both downstream energy market liberalization and market competition. The study also revealed that industry players face many challenges ranging from inadequate legislation, government interference, limited fuel terminal tanks, supply chain and other operational difficulties, high import duties and lack of subsidy on imported petroleum products. The study recommends that OMCs should develop and implement marketing strategies, programs and activities in line with product differentiation, branding and value added services. This research equally recommend that the stakeholders in the industry should work on the amendments of downstream petroleum legislation, expand the fuel terminal tank storage facility, adopt and enforce national downstream petroleum quality standard in the daily operations and work towards realizing full deregulation in the sector.
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Özgür, Emre. "The Role of Enhanced Oil Recovery in the Upstream Petroleum Sector, a Turkey Case." Bulletin Of The Mineral Research and Exploration, July 18, 2018, 1–2. http://dx.doi.org/10.19111/bulletinofmre.444903.
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OLUJOBI, OLUSOLA JOSHUA, and OLUSOLA-OLUJOBI TEMILOLA. "THE APPRAISAL OF LEGAL FRAMEWORK REGULATING GAS FLARING IN NIGERIA’S UPSTREAM PETROLEUM SECTOR: HOW EFFICIENT?" INTERNATIONAL JOURNAL OF ADVANCED RESEARCH IN ENGINEERING & TECHNOLOGY 10, no. 3 (2019). http://dx.doi.org/10.34218/ijaret.10.3.2019.024.
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Bamidele, T., A. Iwundu, W. I. Eke, O. Joel, and O. Akaranta. "Evaluation of Red Onion Skin Extract as Inhibitor for Gum Formation in Gas Condensates." Chemical Science International Journal, August 3, 2019, 1–10. http://dx.doi.org/10.9734/csji/2019/v27i330114.
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In the upstream sector, gum in condensate causes significant erosion in value worth millions of dollars per annum and increases operational cost due to high injection concentration of conventional antioxidants. Phenolic compounds are commonly used at low concentrations in the downstream sector to inhibit gum formation in refined petroleum products. However, gum inhibition in condensates, in the upstream sector, requires high concentrations of phenolic antioxidant. Therefore, there is need for cheaper and more effective antioxidants for gas condensates. The present study investigates the use of Red Onion Skin Extract (ROSE) as a natural inhibitor for gum formation in condensate based on ASTM D381. Treatments with ethanolic extracts of red onion skin were carried out on seven gas condensate samples with gum formation tendency. At a dosage of 200ppm red onion skin extract caused a reduction of 17.4% to 99.6% in washed gum content of the condensate samples. The performance of ROSE was comparable to, and in some condensates better than, commercially available catechol. The result obtained using ROSE highlights the need to explore the commercial viability of this application in oil & gas upstream operations.
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Atsrim, Robert, Charles Yaw Atsrim, and Abdul Manan Adam. "Local Content in the Upstream Petroleum Sector of Ghana. How Well Is Ghana Doing So Far?" SSRN Electronic Journal, 2018. http://dx.doi.org/10.2139/ssrn.3185844.
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Renner Nrior, Renner, David N. Ogbonna, and Alaumogute Edward Alabo. "Biodegradation of Drilling Fluid used in Upstream Sector of the Nigeria Petroleum Industry in Marine Water Environment." International Journal of Waste Resources 07, no. 04 (2017). http://dx.doi.org/10.4172/2252-5211.1000302.
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Olujobi, Olusola Joshua, and Temilola Olusola‐Olujobi. "Comparative appraisals of legal and institutional framework governing gas flaring in Nigeria's upstream petroleum sector: How satisfactory?" Environmental Quality Management, July 3, 2020. http://dx.doi.org/10.1002/tqem.21680.
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J. M. Beggs. "The New Zealand Framework for Government and Private Sector Research, and Its Operation with Respect to the Upstream Petroleum Industry: ABSTRACT." AAPG Bulletin 79 (1995). http://dx.doi.org/10.1306/8d2b23a3-171e-11d7-8645000102c1865d.
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Akinwale, Yusuf O. "Empirical analysis of inbound open innovation and SMEs performance: Evidence from oil and gas industry." South African Journal of Economic and Management Sciences 21, no. 1 (2018). http://dx.doi.org/10.4102/sajems.v21i1.1608.
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Background: This article contributes to existing literature by examining the relationship between inbound open innovation and firms’ financial performance in the Nigerian oil and gas industry. Aim: This article seeks to identify the factors of inbound open innovation and whether these factors influence the financial performance of small and medium-sized enterprises (SMEs) in the Nigerian oil and gas industry. Setting: This article examines 150 indigenous oil and gas SMEs in the upstream subsector of the Nigerian petroleum sector through a survey, using a questionnaire, conducted in 2015. Methods: The study applied the structural equation modelling (SEM) method. This method is used to test the relationships between the factors and to calculate the measurement errors in the hypotheses formulated. Results: The results show that technology scouting, vertical technology collaboration (VTC) and horizontal technology collaboration (HTC) positively and significantly contribute to inbound open innovation, which are thus significant in influencing the financial performance of SMEs. The size of technical staff and research and development (R&D) fund allocations also have a positive and significant correlation with the SMEs’ financial performance. Meanwhile, the age of SMEs is negative and not significant in influencing financial performance. Conclusion: The results suggest that inbound open innovation through scouting, HTC and VTC should therefore be encouraged among SMEs to boost their internal capabilities, which have hitherto enhanced their financial performance. The management members of each SME should continually consider collaboration with the external actors because they cannot singularly possess all the innovative skills required in the industry. Also, each firm should commit itself to allocate more funds to R&D and at the same time should hire those who have relevant production skills and train the existing ones in their firms.
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"A Review of Petroleum Waste Management and Environmental Quality Status of Niger Delta." Advance in Environmental Waste Management & Recycling 1, no. 1 (2018). http://dx.doi.org/10.33140/aewmr.01.01.07.
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This paper provides a review and assessment of many researches and documentaries on Niger delta petroleum waste management. What new strategy or operational techniques would be added to improve waste management and environmental quality of Niger delta is our concern. Poor waste management, lack of environmental impacts assessment (EIA) and remediation neglects in the three sectors of oil and gas operations (upstream, midstream and downstream) are responsible for environmental pollution in the Niger delta. There is need to adopt continuous, operational, and periodic EIA with immediate remediation in the three operational sectors. This will end the old method of remediation only after a crisis. Application of Remove, Reduce, and Reuse to petroleum waste water should be considered. Avoidance of gas flaring near residential areas is obvious. Replacing unlined waste water pits with lined pits, solid waste dumps with sanitary landfills and partial waste treatment with full treatment are inevitable in sustainable management of petroleum wastes. Oil companies and the Nigeria National Petroleum Corporation (NNPC) could establish research grant for environmental studies to have the findings reported to them directly. Niger delta operational areas with maximum toxicity should be mapped out as brown fields and declared “no farm areas”.
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"Application of Data Mining in Hydrocarbon Transportation, Storage and Safety Handling." International Journal of Innovative Technology and Exploring Engineering 9, no. 8 (2020): 121–23. http://dx.doi.org/10.35940/ijitee.h6265.069820.
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Considering the present scenario, in the hydrocarbon industries, heavy oil prices and need for explorations leads to decide the economy of the country. Technology had been identified and experimentally considered for new hydrocarbon exploration with the help of data mining. Besides, transportation and storage of the produced Hydrocarbon has been monitored and can be maintained in control limit using data mining too. Hydrocarbon can be stored within a tank made up of steel, iron or combination of suitable material. The tanks are properly designed, erected and all its fittings are secured. Proper construction and maintained will aid in preventing any leakage of petroleum products to the environment. Current study is about influence of hydrocarbon transportation and storage using available methodology in upstream hydrocarbon sectors. Petroleum reservoir consist of complex heterogeneities that are not limited to extract the hydrocarbon from the subsurface to surface. Post drilling, produced crude and gas will be transported fuel have to transported to refineries for further processing of crude into various products. Apart from upstream, persons working on midstream and downstream plays a crucial role. Crude hydrocarbon can be transported by vessels, pipelines and road. Pipeline and truck transportation are considered to be the prior most than other modes. Transporting oil and gas by pipeline or rail is in general quite safe. But when the safety of transporting oil and gas by pipelines and rail is compared, taking into consideration the amount of product moved, pipe-lines are found to be the much safer transportation method. Refinery has to ensure safety aspects of storing the received petroleum crude which has to be processed in to commercial products. They must be maintained in prescribed temperature and pressure condition. In order to make this successful, some of the safety protocols has to be followed which are defined and approved ministry and safety norms. This article deals about the process and procedures in transporting and storage of fuels from upstream, midstream and downstream. Hence, the protocols and other safety precaution aspects are discussed to have a safe storage and handling practices.