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STAN, Marius, Valentin Paul TUDORACHE, Lazăr AVRAM, Mohamed Iyad AL NABOULSI, Claudiu TĂNASĂ, and Georgeta ALECU. "Elements constituent for the design of a riser system in areas deep water and extreme deep water applied for offshore drilling." EMERG - Energy. Environment. Efficiency. Resources. Globalization 6, no. 3 (2020): 127–44. http://dx.doi.org/10.37410/emerg.2020.3.10.
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Riser systems are integral components of the offshore developments used to recover oil and gas stored in the reservoirs below the earth’s oceans and seas. These riser systems are used in all facets of the development offshore process including exploration and exploitation wells completion/intervention, and production of the hydrocarbons. Their primary function is to facilitate the safe transportation of material, oil and gases between the seafloor oceans and seas and the marine platform. As the water depth increases, the working conditions of this system becomes challenging due to the complex forces and extreme environmental conditions which are impacting the operational mode as well as the stability. In this paper several aspects concerning riser mechanics and the behaviour of the riser column will be evaluated against different operational situations.
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Duarte, Victor Magalhães, Luciano Matos Queiroz, Ednildo Andrade Torres, and Asher Kiperstok. "Energetic aspects and opportunities for reusing water on offshore platforms in Campos Basin, Brazil." Ambiente e Agua - An Interdisciplinary Journal of Applied Science 12, no. 5 (August 23, 2017): 786. http://dx.doi.org/10.4136/ambi-agua.2121.
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In the drilling and production of oil at sea, a large quantity of potable water used is most commonly transported to oil platforms using offshore supply vessels (OSVs). Sea water desalination is used as well, but only in a few oil platforms. To minimize energy consumption, water supply options were studied. The desalination of seawater and the reusing of streams of grey water and black water were evaluated and compared with the characteristics of the current supply via OSVs. In both desalination and OSV water supply options an electrolytic wastewater treatment plant is used. The objective of this study was to analyze the current situation regarding water supply on offshore platforms located in the Campos Basin, Rio de Janeiro, Brazil, and to propose measures to take advantage of opportunities to reuse water and reduce energy expenditure. Two alternative scenarios were developed that involved the reuse of water that comes from the effluent of a biological wastewater treatment plant (WWTP). Information on the logistics of supplying water to platforms was obtained through direct consultation with companies and sources in the literature. The results show that annual energy consumption (uptake, treatment, transportation, use and waste water treatment) of water on offshore platforms is currently 1.89 GWh, and that a reduction of 1.8 GWh of the energy consumed can be achieved using advanced reuse treatments. Energy consumption in the water reuse treatment is more competitive than those of transport by OSVs or seawater desalination.
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Ndubuisi Elizabeth Chinyerem and Eguzoro Chika.Chelsea. "Environmental and living organisms’ disaster caused by discharge of drilling fluid waste." World Journal of Advanced Research and Reviews 22, no. 1 (April 30, 2024): 393–400. http://dx.doi.org/10.30574/wjarr.2024.22.1.1082.
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The oil and gas industry plays a vast and vital role in our society. Despite the numerous benefits of the production of crude oil, its activities pose a lot of dangers to the environment and living organisms because it generates a huge volume of solid and liquid wastes, thus, these wastes require treatment before disposal. The major drilling wastes are drilling muds, drilling cuttings, and obnoxious gas emissions. Parameters that should be considered during the disposal of decontaminated drilling muds and drill cuttings are heavy metals. These wastes are introduced into the environment through accidental spills as well as intentional discharge. The discharge into the environment has effects on humans, plants, birds, soil, and also aquatic life. Generally, oil based drilling fluid usage and disposal are not preferable. However, water based drilling fluid and synthetic based drilling fluid can be a technically and economically disposed because they are biodegradable. Generally, drilling waste disposal options are offshore disposal, onshore disposal and drill cuttings re-injection. Zero discharge can achieved by drill cuttings re-injection. However extensive study must be carried before drill cuttings can be re-inject to the formation. Disposal options must be evaluated based on economics, environment and operational aspects. This study aimed at evaluating the heavy metals present in the drilling fluid waste and drilling cuttings. The experiment was achieved with the aid of a Flame Atomic Absorption Spectrophotometer (FAAS). Upon the investigation, it was discovered that lead concentration in drilling cuttings was the highest with the concentration of 1,058.9 mg/l and drilling fluid was 190.3 mg/l whereas NUPRC limit is 5 mg/l; the total chromium concentration in drilling cuttings was 19.16 mg/l and drilling fluid was 8.38 mg/l whereas NUPRC limit is 8 mg/l; zinc was 58.10 mg/l in drilling cuttings while in drilling fluid it was 23.96 mg/l whereas NUPRC limit is 50 mg/l; silver concentration in drilling cuttings was 14.67 mg/l and drilling fluid 0.91 mg/l whereas NUPRC limit is 5 mg/l; Cadmium concentration in drilling cuttings was 2.17 mg/l and drilling fluid was 1.36 mg/l whereas NUPRC limit is 1 mg/l. In no doubt. The study has shown that disposal of this drilling fluid waste and drilling cutting directly into the environment without treatment will be detrimental to the living organisms and therefore should be discouraged.
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Di Martino, Gianluca, Roumen Sankoff, Craig Marshall, and Bobby Chopra. "The Coniston development: another offshore challenge in Western Australia." APPEA Journal 54, no. 2 (2014): 475. http://dx.doi.org/10.1071/aj13048.
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This extended abstract discusses the key challenges associated with the Coniston development; particular emphasis is on engineering, operations, and project management aspects. The Coniston development will produce oil and gas from the Coniston and Novara hydrocarbon accumulations, located in permit WA-35-L, about 100 km north of Exmouth, in water depths of about 400 m. The Coniston development will consist of a sub-sea tieback to the existing Van Gogh sub-sea infrastructure and the Ningaloo Vision FPSO, currently producing from the Van Gogh Field. The project was sanctioned by Apache in 2011 and will be on production in 2Q 2014. To maximise reservoir exposure, multilateral wells will be drilled, and completed, employing inflow control devices of latest generation and monitoring production with the installation of tracers. To take advantage of project synergies, gas lift will be provided by Van Gogh wells through a dedicated gas production manifold. The Coniston development represents a remarkable multidisciplinary effort to develop a relatively small-size oil reservoir offshore WA. Some of the challenges achieved are the high oil viscosity, the complexity of the engineering to install new sub-sea infrastructure while minimising the impact on Van Gogh production and maximising the synergies of the tie back, the constant increase in drilling and facilities costs while maintaining attractive project economics, and the more stringent regulations environmental permits and the ability to optimise drilling and operation to achieve production as quickly as possible.
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Olugu, Ezutah Udoncy, Kuan Yew Wong, Jonathan Yong Chung Ee, and Yslam D. Mammedov. "Incorporating Sustainability and Maintenance for Performance Assessment of Offshore Oil and Gas Platforms: A Perspective." Sustainability 14, no. 2 (January 12, 2022): 807. http://dx.doi.org/10.3390/su14020807.
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The existence of external two-fold pressure regarding competitiveness and sustainable development in a capital-intensive industry supports the need for sustainable performance. However, endeavors to create a sustainable framework to measure the performance of the oil and gas (O&G) industry are mostly devoted to the production and supply chain of petrochemical products and rarely focus on a maintenance perspective. Motivated by such scarcity, the goal of this research was to discuss and articulate the performance assessment framework by integrating concepts of maintenance and sustainability in the O&G industry. This study proposed the use of a range of performance measures for assessing sustainability on offshore production and drilling platforms. The conceptual framework consists of four aspects of sustainability categorized into technical, environmental, social, and economic dimensions. Each measure was assigned according to its relevance at the strategic, tactical, and functional levels of maintenance decision making. The conceptual framework resulted in hierarchical clusters of twelve strategic indicators. These indicators consist of conventional measures as well as new ones relating to the safety and reliability on offshore platforms. The potential contribution of the present study is found in its intention to empower a better understanding of sustainable maintenance and encourage those making decisions about practical implementation within the O&G industry. This paper culminates with directions for future studies.
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Ziegler, Robert. "Technology Focus: High-Pressure/High-Temperature (March 2022)." Journal of Petroleum Technology 74, no. 03 (March 1, 2022): 79–80. http://dx.doi.org/10.2118/0322-0079-jpt.
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What a difference a year can make. Oil and gas prices have reached and stabilized at levels that have not been seen for over half a decade, demonstrating that the adage “low oil prices are the remedy of low oil prices” is still true. Let us now see if we are again at the cusp of a new period of exuberance and if the cyclical nature of oil prices could soon show its grim face once more. A key industry discipline required to delay, or maybe even avoid, another price collapse is the planning and execution of high-pressure/high-temperature (HP/HT) projects. Perhaps the movement of some financial institutions toward considering environmental, social, and governance aspects when deciding to fund oil and gas projects will provide the beneficial longer-term stabilization of the current oil and gas price levels. More than ever, the saying “the easy/cheap oil is over” is true, and that requires a more-stable economic environment than we had in past years to assure the world’s uninterrupted energy and chemical feedstock supply, an important share of which will come from HP/HT reservoirs. For this year, I think we can see where the activity currently is from the available HP/HT related papers of the past year or two. A predominance of papers came from Chinese companies enthusiastically embarking on these challenging projects to secure their domestic energy needs and reporting their technology innovations and learning curves in interesting case studies. I was able to find some geographic diversity by including case studies from the Middle East as well, where good ideas and innovative low-cost approaches have enabled economically feasible project delivery in tough times. Notably absent in the choice of papers were the traditional HP/HT areas of the deep Gulf of Mexico and the North Sea. But maybe the more favorable oil and gas prices will spawn some new activity in these areas as well, if the regulatory and fiscal environment also improves. Reading this year’s case studies, some of the more experienced engineers among us will notice that, on some occasions, known challenges have been encountered that, in our experience, had been successfully mitigated in previous projects. This is likely a weakness from the Great Crew Change, where the knowledge preservation and transfer may not always have happened satisfactorily. The cut-throat cost-saving environment of the past few years, combined with the worldwide health crisis leading to curtailed travel and many workshops and conferences being canceled, certainly contributed to this lack of information flow as well. This is why it is so important to engage in SPE through online interest/discussion groups to find the necessary expertise in our pool of members. With this recommendation, I hope you will read the 2022 featured papers with interest and take them as encouragement and a source of good ideas for the years of greatly improved activity levels before us. Recommended additional reading at OnePetro: www.onepetro.org. IPTC 20148 - Solid Management Optimization for Offshore Big-Bore HP/HT Sour Gas Well Cleanup by Ardian Nengkoda, Saudi Aramco, et al. SPE 199052 - One of the Deepest Wells Drilled in Bolivia: High Pressure and Temperature in More Than 9 Months of Drilling, No Casing Wear Detected by Russell Mertens, WWT International, et al. SPE 202250 - Next-Generation Ceramic Sand Screens as Openhole Completion Solution in High-Rate Erosive and Corrosive Well Environment at Dvalin HP/HT Field, Offshore Norway by Robert Ritschel, Wintershall DEA, et al.
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Carpenter, Chris. "Machine-Learning Algorithms Optimize Drilling-Center Locations Offshore." Journal of Petroleum Technology 75, no. 10 (October 1, 2023): 72–74. http://dx.doi.org/10.2118/1023-0072-jpt.
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_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 211772, “Optimizing Future Drilling-Center Locations Using Advanced Analytics and Machine-Learning Algorithms Offshore Abu Dhabi,” by Rail Salimov, Benoit Jaffres, and Jamal Alblooshi, ADNOC, et al. The paper has not been peer reviewed. _ Long-term development planning requires infill drilling. Because of the limited number of slots in the offshore environment, new drilling centers (wellhead towers) are required. Optimized location of drilling centers can play a major role in reducing drilling expenses. Two main challenges related to wellhead-tower placement are discussed in the complete paper: first, where to place future drilling centers based on subsurface coordinates and drilling constraints; and second, how to allocate dozens of subsurface targets to multiple drilling centers. The drilling-center placement optimization algorithm developed by the authors is based on multiple optimization parameters related to well cost. Introduction To finalize well trajectories, and thus best manage well costs, before the drilling phase, the following detailed analyses are required: - Evaluation of horizontal trajectory in terms of landing point and total depth - Optimization of horizontal drain length - Optimization of the horizontal drain length in the best oil-bearing zone - Torque-and-drag evaluation - Anticollision assessment - Selection of optimal completion accessories However, for most giant offshore fields with complex plans, hundreds or even thousands of infill developments are required. Definition of optimal locations and allocations of wells to drilling centers will require multiple iterations of already tedious work. An alternative methodology is described in the complete paper that allows finalization of future facility placement with the use of open-source machine-programming tools and applied mathematics. The presented methodology was deployed successfully on two major offshore fields where current production is connected through wellhead towers. Evolution of the development plan and the ramp-up of production means that additional drilling is planned during the next 10 years. Approximately 100–150 development wells are planned to be drilled from yet-to-be-constructed wellhead towers. One of the main challenges in achieving cost efficiency is effective placement of the new towers to minimize the total drain length of all development wells. The methodology covers the two most important aspects of facility construction that play vital roles in optimization of capital investment in facility expansions of offshore oil and gas fields. These aspects are optimized allocation of future wells to drilling centers and placement of those drilling centers.
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Deryaev, Annaguly. "Engineering aspects and improvement of well drilling technologies at the Altyguyi field." Naukovij žurnal «Tehnìka ta energetika» 15, no. 2 (April 30, 2024): 9–20. http://dx.doi.org/10.31548/machinery/2.2024.09.
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The relevance of the research is justified by the rapid development of the oil industry, which requires constant improvement of methods and equipment to increase extraction efficiency and reduce environmental impact. The aim of this study is to enhance the current engineering aspects of drilling in the Altyguyi field while considering increased productivity and reduced environmental impact. Among the methods used, it is necessary to mention the synthesis method, abstraction method, generalization method, induction method, deduction method, classification method, and others. This study examines the technological aspects of operating wells in the Altyguyi gas-condensate field. Extensive laboratory and industrial research on the properties and composition of oil, gas, and condensate was conducted to properly implement the dual completion technology for gas extraction from one formation and oil extraction from another formation in a single well. By implementing advanced drilling methods, including horizontal and multi-hole drilling, as well as using modern drilling fluids, it was possible to improve well productivity and reduce drilling time. As a result of technology optimization, the overall efficiency of the oil and gas extraction process in the field has been increased, confirming the significance of innovation implementation for improving results in the oil industry. These enhancements not only increased drilling safety and efficiency, but also reduced the negative impact on the environment, emphasizing the importance of integrating modern technologies with environmental considerations in the oil extraction process. This research makes a significant contribution to the development of more efficient and environmentally sustainable drilling methods in oil fields, contributing to increased oil extraction productivity and reduced environmental impact
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Noussia, Kyriaki. "Global Offshore Energy Installations: Implications for Environmental Pollution Liability Insurance in Relation to Major Oil Spill Incidents." European Energy and Environmental Law Review 32, Issue 2 (March 1, 2023): 100–111. http://dx.doi.org/10.54648/eelr2023005.
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Post the Deepwater Horizon (DWH) incident, offshore energy insurance underwriters reassessed their risk exposures in response to newly perceived operational risks involving blowouts, fires, explosions, lost control of well and other non-hurricane risks. Already in the aftermath of the DWH incident, it has been noted that it would be crucial to consider the willingness of the global offshore energy insurance market to participate in efforts to establish and fix a new liability limit for environmental pollution liability insurance. In relation to the approach followed by the USA administrations, this has been fragmented, with the current administration in office introducing a moratorium on new oil and gas leasing on federal lands and waters and in terms of its policy relating to its climate agenda. Against this background, this article describes the insurance implications of environmental pollution liability in case of offshore drilling operations incidents (such as the DWH) resulting in major oil spills. In doing so it discusses in detail the legal framework and the position in the EU and draws a comparison with other jurisdictions. It also contains proposals for future measures so as to be able to offer better insurance coverage for such offshore drilling disasters, such as the introduction and collection of data on damages, or an EU wide and an international agreement especially focusing on offshore-related incidents with a transboundary character, as well as a mechanism to facilitate early compensation payments to potentially vulnerable victims.
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Carpenter, Chris. "Integrated Work Flow Aids Data Digitization, Management for Offshore Drilling." Journal of Petroleum Technology 73, no. 10 (October 1, 2021): 49–50. http://dx.doi.org/10.2118/1021-0049-jpt.
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This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 202290, “Digital Documentation and Data Management for Offshore Drilling,” by Zhong Cheng, SPE, Xi’an Shiyou University and CNOOC, and Rongqiang Xu and Xiaolong Yu, CNOOC, et al., prepared for the 2020 SPE Asia Pacific Oil and Gas Conference and Exhibition, originally scheduled to be held in Perth, Australia, 20–22 October. The paper has not been peer reviewed. The industry is expending significant effort into using instrumentation and software to optimize operations in all domains for exploration and production to move toward the digital oil field. The complete paper describes an integrated geological-engineering data-management project covering all aspects of well-engineering work flows, with the objective of providing a continuous improvement platform to users. Introduction CNOOC has spent more than 20 years on the progression of information construction. A private cloud platform was completed in 2018, and the characteristics of oil and gas data and critical storage-management technologies were studied systematically. At the same time, nearly 20 kinds of drilling- operation analysis software have been developed independently. From the perspective of engineering technology, these provide real-time monitoring, remote decision-making, technical training, and other information resource services and support for offshore drilling operations. However, the following problems restrict the efficient operation of such projects: - Because of the lack of a unified data-integration-application platform, data sharing has not yet been realized. - In the process of real-time monitoring and remote decision-making, more engineering information based on drilling operations lacks the support of geomechanical data. - The knowledge base and case library to guide the prevention and handling of drilling-operation accidents have not been established. System-Target Analysis The design goals of the platform are embodied in three aspects: function, safety, and operability, while system performance requirements are summarized as adaptability, response speed, scalability, maintainability, and the effective-ness of failure-handling mechanisms. According to the functional requirements of different users for offshore-drilling cloud technical services, users generally are divided into three categories: headquarters decision-making managers, drilling-operation project teams, and system-operation and maintenance-service providers. System Construction Goals and Architecture Construction Goals - Chief among these was to build a geological-engineering integrated data-management platform. Another important goal was to build a case-management platform. An intelligent search engine is established to retrieve the corresponding disposal knowledge through a comprehensive information model. A knowledge-management subsystem is established, and users are linked with internal knowledge-management processes with the help of the cloud. The specific operation process is carried out in the private cloud, and the results are fed back to the user through the human/computer interface.
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Ovchinnikov, P. V., and A. S. Syrchina. "Optimization methods for well designs, drilling and well completion technologies." Proceedings of higher educational establishments. Geology and Exploration, no. 5 (December 13, 2023): 22–32. http://dx.doi.org/10.32454/0016-7762-2023-65-5-22-32.
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Background. The task of increasing the efficiency of well construction, reducing the labor- and financial costs involved, and achieving the maximum operational characteristics of oil and gas wells requires the application of the most recent technologies and technological solutions for well drilling and well completion.Aim. Review and analysis of the implementation and development of promising technologies for well drilling and well completion in the Russian Federation to identify those capable of optimizing well designs, improving the efficiency of technological processes for drilling and completion of exploration and production wells.Materials and methods. An analysis of accumulated experience, generalization of the results of implementation of modern solutions and technologies for drilling and completion of wells by oil- and gas-producing enterprises of the Russian Federation.Results. The relevant tasks and directions for improving drilling and well completion technologies and using state-of-the-art equipment are outlined. These solutions can contribute to increasing the efficiency of well construction, reducing the drilling duration of oil and gas wells, and ensuring technological sovereignty.Conclusion. The considered directions and technologies, as well as their composite tasks and methodological, engineering, and software implementation aspects, can become a subject for research, project, and engineering works, as well as for final qualifying works of students and dissertations.
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Peng, Chunyao, Wenqiang Feng, Xiaohu Luo, Shujiao Li, and Chen Riji. "An Environmentally Friendly Wbm System Can Prevent Hard Brittle Shale Instability." Scientific Contributions Oil and Gas 32, no. 2 (March 17, 2022): 133–42. http://dx.doi.org/10.29017/scog.32.2.843.
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In the Weizhou Southwest oilfields, drilling delays and suspension of wells prior to reaching the targets due to wellbore instability had occurred frequently. The hard brittle shale played a problematic role. Conventional water-based drilling fluids didn’t conquer the problematic formation due to intrinsically performance deficiencies. While Oil based drilling fluids are routinely preferred in the more technically demanding applications, they are cause for increasing concern due to offshore environmental restrictions and expensive disposal costs. An environmentally acceptable water-based drilling fluid was developed to challenge the problematic formation based on the combination of methylglucoside-silicate concept. It stabilized the reactive shale by the same mechanism as did oil-based drilling fluid in preventing shale hydration, pore pressure increase and weakening of shale by effectively developing sufficient osmotic force to offset hydraulic and chemical forces acting to cause filtration flux into the hard brittle shale. A field trial was initiated on the CNOOC 931 platform in Weizhou oilfield. The data from the pilot well showed that the novel drilling fluid exhibited excellent inhibition and lubricity which approached or even exceeded oil-based fluids.
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Katerenchuk, Daniil Vladimirovich. "Oil and gas in Lebanon: shattered expectations." Международные отношения, no. 2 (February 2024): 32–41. http://dx.doi.org/10.7256/2454-0641.2024.2.70542.
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The article is dedicated to the peculiarities of the oil and gas policy of the Lebanese Republic - one of the few countries in the Middle East that does not engage in hydrocarbon extraction. The issue of oil and gas production in Lebanon remains insufficiently studied, although certain aspects of Lebanon's oil and gas policy have been touched upon by Russian scholars in the context of the Lebanon-Israel multiyear maritime border dispute. The author examines Lebanon's attempts to discover oil and gas in the 20th and 21st centuries against the backdrop of the complex political and economic situation in the country, describes the procurement process, in which Russian companies were also involved, and addresses the legislative framework for hydrocarbon production and exploration. The article explores the prospects of significant hydrocarbon reserves in Lebanon, with special attention paid to exploration in the country's exclusive economic zone (EEZ). According to experts, Lebanon possesses substantial oil and gas potential, as evidenced by the discovery of significant gas deposits offshore Israel and Cyprus. However, initial drilling in Lebanon's EEZ did not confirm the presence of commercially viable hydrocarbon reserves. It is concluded that the unstable political situation in the country, as well as the dispute with Israel over maritime borders, significantly hindered exploratory drilling offshore Lebanon. The unsuccessful tender process in recent years indicates Beirut's insufficiently effective oil and gas policy. The author believes that even if confirmed oil and gas reserves are discovered, Lebanon's economic crisis cannot be resolved in the foreseeable future due to weak governance and a lack of developed infrastructure for hydrocarbon export.
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Ferreira, Hélder O., Alexandre Cabrai, and Álvaro Souza Junior. "An Application of Worst Case Scenario Concept in Oil Spill Response Planning for Offshore Drilling Operation in Brazil." International Oil Spill Conference Proceedings 2003, no. 1 (April 1, 2003): 371–76. http://dx.doi.org/10.7901/2169-3358-2003-1-371.
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ABSTRACT The Brazilian oil and gas E&P sector has been experiencing important changes since the end of the state monopoly in 1998. These changes include a new regulatory environment which is still under construction, in particular the requirements for environmental protection. In this context, Resolution 293 of Brazilian National Environmental Council (CONAMA) was enacted regulating Facility Response Plans for oil spill incidents. These plans, which should be approved by the competent authority, include a vulnerability analysis that should discuss the probability of oil reaching certain areas as well as the environmental sensitivity of these areas. Oil spill modeling is an important tool to estimating the areas likely to be affected by an oil spill. Although oil spill modeling is also part of the environmental studies required in the environmental permitting process for oil E&P activities, there are not well defined criteria to compose the oil spill scenarios to be modeled. In order to demonstrate the impacts of different approaches in the results of oil spill modeling, a case study is presented related to an offshore drilling activity.
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Carpenter, Chris. "Multifunctional-Team Approach Achieves Extended-Reach Record Offshore Abu Dhabi." Journal of Petroleum Technology 76, no. 05 (May 1, 2024): 94–96. http://dx.doi.org/10.2118/0524-0094-jpt.
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_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 216326, “Longest Extended-Reach-Drilling Well Worldwide Drilled in Middle East, Offshore Abu Dhabi, UAE,” by Marah Mohamad Alabed, Naser Salah Alsuwaidi, and Jamie Scott Duguid, SPE, ADNOC, et al. The paper has not been peer reviewed. _ The complete paper describes the engineering design and operational practices that supported the setting of a new extended-reach world record in a mature carbonate field offshore Abu Dhabi. This accomplishment reduces the carbon footprint of the development, allows acquisition of reservoir data earlier in the development plan, and accelerates production while reducing costs. This extended-reach development program is a strong example of what can be accomplished when a multifunctional team cultivates a strategic plan to expand technical and operational capabilities in a drilling campaign. Reservoir and Development-Plan Background The 1-md oil reservoir is a carbonate dominated by packstone and grainstone rock types in terms of storage capacity. Average porosity is 18%, and thickness is 130 ft. Permeability reduces in an southeast/northwest direction, dropping below 1 md. Calcite cementation development has occurred in the westernmost areas of the reservoir because of late oil in these low structural areas. Initially, the target reservoir was drilled at 2-km well spacing with a five-spot waterflooding scheme from wellhead platform towers. Later, development was optimized by a line waterflooding scheme at 250-m well spacing by development from an environmental island. The target reservoir area was partitioned into four development areas (West A, West B, West C, and West D). The partition is based on drilling reachability from environmental islands and underlying geology. The current optimized development began in the West A reservoir area through an artificially constructed island. The remaining reservoir areas required investment of two new islands. High risk is associated with these investment decisions because these reservoir areas degrade in terms of reservoir rock properties. Additionally, an increasing trend of water saturation exists with progress in the northwest direction within the transition zone. The development plan in the West A area is based on drilling segments called AB and BC, first with over-20,000-ft laterals to achieve production buildup by target date. To test the West B area, Segment BC was extended, thus covering both West A and B areas. This option reduced drilling complexity and maximized the reservoir-production rate. Additionally, by adopting the island drilling option instead of appraising a limited area of West B, an extensive area of approximately 10 km could be appraised. To implement this option, a stepout drilling plan was executed by drilling eight extended-reach maximum-reservoir-contact wells in increments to meet the goal of appraising the West B reservoir area. These first wells were extended in increments of 1,000–2,000 ft to test the capability to drill and run completion to target a measured depth (MD) of 45,000 ft. Upon applying learnings from these pilot wells, a stepout to extending wells to 50,000 ft MD and greater was studied. Fig. 1 shows the map of the subject drilled well with an extended MD of 50,000 ft with an underlying oil-saturation map. This optimized field-development strategy has allowed for effective West B reservoir appraisal.
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Singh, Atresh Kumar, Alok Kumar Singh, and Som Shankar. "APPLICATIONS, NANOTOXICITY, ENVIRONMENTAL ASPECTS AND FUTURE CHALLENGES OF NANOTECHNOLOGY IN THE OIL AND GAS INDUSTRY: A REVIEW." RASAYAN Journal of Chemistry 15, no. 03 (2022): 1943–54. http://dx.doi.org/10.31788/rjc.2022.1536921.
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In the present review, applications of nanotechnology are employed to amplify the tendencies of growing traditional and cut-off resources of gas and to improve the process of drilling and production of oil and gas by designing it more accessible to separate oil and gas inside the reservoir. The impact of nanotechnology in many areas is more effective, cheaper, and more environment-friendly than what is presently accessible. A summary of various types of nanomaterials used together with a deep investigation of their compliance in advancing the objective factors is widely described. This paper reviews nanotechnology applications in the various parts of the oil patch such as exploration, production, EOR, wettability alteration, refinery processes, and drilling operations including drilling tools, drilling fluids, and cement. The impacts of numerous nanoparticles in drilling fluids and enhanced oil recovery has been explored. This paper gives a notified analysis of the improvements of nanotechnology in exploration as well as production. Moreover, the toxic effects of various nanoparticles and their environmental aspects have been observed and studied. The oil and gas industry can be made greener by nanotechnology. Finally, an outlook on the recent challenges and a few predictions for future applications is also underlined.
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Dzyublo, A. D., S. О. Borozdin, and E. E. Altukhov. "Technologies for Safe Handling of Drilling Waste during Well Construction in the Ob Bay." Occupational Safety in Industry, no. 6 (June 2021): 52–60. http://dx.doi.org/10.24000/0409-2961-2021-6-52-60.
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Development of the Russian oil and gas fields in the Arctic requires ensuring industrial and environmental safety of conduct of the operations. Large and unique oil and gas condensate fields are discovered in the southern part of the Kara Sea. The Kamennomysskoye-Sea, Severo-Kamennomysskoye, Semakovskoye, Parusovoye, etc. gas condensate fields are located in the Ob Bay of the Kara Sea. The raw material base of the Severo-Obskoye gas condensate field, unique in terms of the reserves, will become the basis for future Arctic LNG projects. Based on the published data, the initial recoverable total hydrocarbon resources in the Ob and Taz bays are about seven billion tons. Active exploration and commissioning of the already discovered fields require the large volumes of well drilling in a freezing sea, the presence of permafrost, and gas hydrates. During construction of the wells and operation of the offshore ice-resistant oil and gas production platforms, it is required to ensure the disposal of drilling waste (cuttings) and domestic water. There are two technologies for waste disposal — injection into the reservoir or into the clay formations. The first one is used in onshore fields, the second one — on the shelf. Injection into a clay reservoir is successfully used in the Lunskoye gas field on the shelf of the Sakhalin island, and on the Prirazlomnoye oil field in the Pechora Sea. The possibility of using the method and the selection of a reservoir for injecting waste into it requires a geological justification, and the reservoir should ensure a stable injectivity of the required volume. The article presents the results of modeling the injection into the formation of drilling waste, and the waste of the household activities for the Kamennomysskoe-Sea gas condensate field. Calculation was made concerning the zone of absorption of the technological waste into the designed well of the offshore ice-resistant stationary platform. Formation allocation for waste injection was made according to the data of a complex of offshore wells geophysical studies. Three packs of sandy-argillaceous rocks with high reservoir properties were selected as the object of industrial waste disposal. Сalculation was carried out related to the radius of the spread of waste (effluent) in the target reservoir considering drilling and operation of twenty five wells, the construction of which is planned for five years. The results of modeling the process of pumping industrial waste of various types into an absorption well showed that the planned volumes can be successfully disposed of in the selected objects. This will allow to ensure functioning of the marine industry and its environmental safety.
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Siddique, AH, T. Shamsi, and M. Hasan. "Human Machine Interaction (HMI) in Offshore Drilling - oil rig workers’ opinion about their interaction with machines." International Journal of Occupational Safety and Health 11, no. 3 (September 30, 2021): 181–91. http://dx.doi.org/10.3126/ijosh.v11i3.39812.
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Introduction: There are huge numbers of drilling platforms in the world and once the worker on those platforms meet with an accident, the situation could be very serious. The consequence of this could be environmental, economic and in some cases fatal. Middle East, being one of the oil rich regions hence some of the largest operator works here. Companies here own various types of jack up rigs ranging from old generation rigs to the latest cyber-rig. This paper addresses what oil rig workers have to say about their interaction with machines, and how Human Machine Interaction (HMI) in Offshore Drilling can be improved with design.
Method: A case study approach was undertaken The analysis in this paper draws on the interviews conducted with two different employees involved in operating the drilling operations conducted in the driller’s cabin of newly designed offshore rigs. A semi-structured approach was adopted, using themes identified through analysis of the preceding. The interviews were transcribed by the research team. Each interview was analyzed thematically with existing system and reported discrepancy
Results: The study on Human Machine Interaction (HMI) and Human Factor regarding this has been conducted in the latest generation cyber rigs. There are many aspects of HMI and ergonomics but in this study a special concentration has been given to deal with the ergonomic standpoint and evaluates the drillers console controls.
Conclusions: When comparison is done with the existing machinery, few modifications can be thought of for better human machine interaction. A better human machine interaction system will ensure a more productive environment for the oil-rig workers.
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Esposte Coutinho, Priscila, Larissa Haringer Martins da Silveira, Marcio Cataldi, Fabiana Rodrigues Leta, Antônio Orestes de Salvo Castro, Cláudio Benevenuto de Campos Lima, and Gilson Brito Alves Lima. "Wavelet Transform Processing in Detecting Failures in Offshore Well Production." Latin American Journal of Energy Research 9, no. 1 (August 31, 2022): 1–11. http://dx.doi.org/10.21712/lajer.2022.v9.n1.p1-11.
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Brazil has a significant offshore oil production, which dates back to the late 1960s and is currently focused on exploring pre-salt reservoirs. The drilling technology Petrobras uses is considered a world standard: in 2020, it allowed offshore production to reach 97% of the country’s total oil production. During the process, however, unwanted events, and even operational failures may occur, which are capable of significant damage. Thus, failure detection is extremely important to prevent production losses or delays, to reduce costs and to avoid accidents. This study uses a real, public database on offshore production, and proposes using wavelet transforms to detect production failures. With the technique, we pinpointed which time intervals between measurements showed relevant variability, and then clustered the data, according to mobile averages, to shrink the record number. Using wavelet transforms, we analyzed which variables could be used as predictors of production failures and identified the temperature read by the Temperature and Pressure Transducer sensor (T-TPT) and the pressure at the Production Choke sensor (P-PCK) as possible predictor variables. We also observed the creation of a filtered series, averaged from the original data series, which maintained its variability, showing the viability of record regrouping in shorter series.
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Abed El Rahim, Mohamad khaled, and Moath Al Husban. "Analysis of the Lebanese oil and gas exploration in the Mediterranean Sea: An overview and analysis of offshore platforms." International Journal of Advanced Engineering, Sciences and Applications 2, no. 1 (January 31, 2021): 25–29. http://dx.doi.org/10.47346/ijaesa.v2i1.60.
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Offshore structures are used around the world for many functions, and these structures vary according to the depth of the water, the depth of water and environmental conditions are the main factors that determine the type of platform and method of drilling, appropriate planning, manufacturing, transportation, installation, and start-up. At the beginning of the twentieth century, oil and natural gas were discovered in the Middle East, specifically in the Lebanese basin. This discovery opened the door for Lebanon and entered the club of oil states. This paper is a study and analysis of blocks No. 4 and No. 9 that may contain the largest amount of oil and natural gas in addition to studying and analysing the types of marine installations (fixed and movable) and provide the best suggestions for the type suitable platform for the process of extracting oil and natural gas from the Sea of Lebanon according to the depth of water and factors Natural. The option of a drillship for drilling is the most appropriate option, given the lack of sufficient information about the nature of the soil in the Lebanese Sea. The drillship is considered an optimal solution given for ease of movement and in the absence of oil, the cost is much lower than the installation of fixed platforms. Semisubmersible rig for drilling and Tension Leg Platform or Semisubmersible Platform as well as Subsea System for oil/gas extraction are good alternatives to be employed in the Lebanese oil/gas fields.
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Gaidaichuk, Viktor, Lyudmyla Levkivska, and Maryna Lazareva. "Forecasting supercritical behavior of drill strings in horizontal wells." Strength of Materials and Theory of Structures, no. 110 (June 26, 2023): 118–30. http://dx.doi.org/10.32347/2410-2547.2023.110.118-130.
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The determining factor in the current changes in the world energy balance and its structure, as well as the global development of the oil and gas industry, is currently the technological factor. As a result, fundamentally new categories of horizontal and inclined wells appeared and developed. They give a multiple increase in flow rates, as they increase the production area many times over. They are used in the development of offshore projects, in swampy and very difficult areas, to increase oil recovery, restoration of inactive wells.
New technologies based on the method of horizontal drilling have revolutionized the practice and theory of world oil production, as they have allowed the destruction of offshore oil and gas fields without the construction of expensive offshore foundations and platforms.
When drilling horizontal wells, as a rule, the main cause of emergencies is the loss of stability of the drill string, its bifurcation protrusion and the maximum frictional interaction with the well wall. The issues of theoretical modeling of the phenomenon of unstable protrusion of columns are associated with significant difficulties, the main of which is due to the need to set the Sturm-Liouville boundary value problem on a large length of drill string. Because for deep wells, the drill string becomes geometrically similar to a human hair, many traditional mathematical methods used to integrate solving equations become poorly convergent in these cases.
Based on the theory of curvilinear flexible rods, the problem of theoretical modeling of supercritical states of drill strings taking into account their contact interaction with the walls of oil and gas wells is set. Analytical solutions of the problem are constructed, which determine the critical values of external tensile or compressive longitudinal force and torque at a given difference in the diameters of the cavity and the drill string, the zones of supercritical states of drill strings are established.
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Carpenter, Chris. "Drilling Dynamics, Mechanical Specific Energy Data Help Drill Record Extended-Reach Well." Journal of Petroleum Technology 73, no. 05 (May 1, 2021): 59–60. http://dx.doi.org/10.2118/0521-0059-jpt.
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This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 203335, “Using MSE and Downhole Drilling Dynamics in Achieving a Record Extended-Reach Well Offshore Abu Dhabi,” by Nashat Abbas and Jamal Al Nokhatha, ADNOC, and Luis Salgado, Halliburton, et al., prepared for the 2020 Abu Dhabi International Petroleum Exhibition and Conference, Abu Dhabi, held virtually 9–12 November. The paper has not been peer reviewed. Complex extended-reach-drilling (ERD) wells often present challenges with regard to geological aspects of data requirement and transmittal, reactive geosteering response times, and accuracy of well placement. Such scenarios may require innovative approaches in Middle East carbonate reservoirs. The objective of the complete paper is to illustrate that, by assessing the details of reservoir geology and key operational markers relevant for best practices, drilling approaches can be customized for each reservoir or scenario. Reservoir Background and Geology The planned reservoir section is a single horizontal of approximately 25,000-ft lateral length at a spacing of 250 m from adjacent injectors. The well was drilled from an artificial island. Field A, a shallow-water oil field, is the second-largest offshore field and the fourth-largest field in the world. Horizontal drilling was introduced in 1989, and an extensive drilling campaign has been implemented since then using steerable drilling technologies. This study is concerned only with wells drilled to develop Reservoir B in Field A, which contributes to the main part of initial oil in place and production. The thick limestone reservoir is subdivided into six porous layers, labeled from shallow to deep as A, B, C, D, E, and F. Each porous layer is separated by thin, low-porosity stylolites. The reservoir sublayer B, consisting of approximately 18-ft-thick calcareous limestones, was selected as the target zone for the 25,420-ft horizontal section. ERD, constructed on artificial islands, began on 2014 with a measured depth (MD)/true vertical depth (TVD) ratio approaching 2.2:1 or 2.4:1. A recent ERD well, Well A, was drilled at the beginning of 2020 with a MD/TVD ratio of 5:1. This value is a clear indication of progressively increasing challenges since the start of the project. Mechanical specific energy (MSE) has long been used to evaluate and enhance the rate of penetration (ROP); however, its use as an optimization tool in ERD wells has not been equally significant. This may have been mostly because of historical use of surface-measured parameters, which do not necessarily indicate the energy required to destroy the rock, particularly in ERD wells. Using optimization tools as part of the bottomhole assembly (BHA) downhole close to the bit provides actual weight-on-bit (WOB) and torque-on-bit (TOB) applied to the drilling bit to destroy the rock and, thus, results in more-representative MSE measurements to optimize drilling parameters and ROP in ERD wells.
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Innes, Gareth, Jan Thore Eia, and Steinar Nesse. "Case Study: Drill-Cuttings Treatment Alternatives—A Comparative Emissions Assessment." Journal of Petroleum Technology 74, no. 02 (February 1, 2022): 47–50. http://dx.doi.org/10.2118/0222-0047-jpt.
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The offshore oil and gas industry has always been cognizant of its impact on the marine environment. The choices that operators make in how they operate, including the disposal of drill cuttings, must address an increasing number of environmental and climate targets in addition to those related to health, safety, and cost. As a typical well will produce approximately 1000 metric tons of oil-based drill cuttings, quantifying greenhouse-gas (GHG) emissions associated with the disposal and treatment of drill cuttings has become an essential step to achieving net-zero ambitions. Since 1991 (1993 for fields in production), strict regulations relating to the discharge of oil-based drill cuttings have been in force under the OSPAR (Oslo/Paris) Convention. Those regulations banned the practice of discharge to sea of untreated oil-based drill cuttings and led to a situation where they were generally shipped to shore for treatment and disposal. In 2020, TWMA engaged DNV, the independent energy expert and assurance provider, to undertake a comparative study between the company’s offshore thermal drill-cuttings treatment solution and conventional alternatives including “skip and ship,” bulk transfer, and cuttings reinjection (CRI) used on the Norwegian Continental Shelf (NCS). It is the first paper to show a direct emissions comparison between offshore processing and alternative methods implemented. The study assessed the carbon dioxide (CO2) footprint and nitrogen dioxide (NOx) emissions for each of the different alternatives. The values were then used to create an interactive emissions calculator that can easily be applied to specific projects to clarify the actual potential for emissions reduction within the drilling waste management process. Background Technological improvements, as well as cost focus on existing solutions, have meant that offshore thermal drill-cuttings treatment has been widely adopted in many offshore basins as one of the safest and most cost-effective approaches. In Norway, which was the subject of the study, adoption of the technology has been slower than in other countries, with onshore thermal treatment of oil-based cuttings applied as the predominant technique, while some fields use offshore slurrification and injection into dedicated disposal wells. However, the cost of drilling new disposal wells and the track record of successful offshore thermal projects in other countries have improved the frame conditions for the use of offshore thermal treatment of cuttings on the NCS. It has also been demonstrated, in an earlier independent comparative study by Carbon Zero (SPE 207519), that the carbon footprint of skip and ship to shore of drill cuttings is 53% higher than that of drill-cuttings treatment at the wellsite (SPE 202639).
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Mohamed, Abdulrahman. "Novel approach for anti-collision planning optimization in directional wells." International Journal of Engineering & Technology 9, no. 2 (April 3, 2020): 333. http://dx.doi.org/10.14419/ijet.v9i2.30306.
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One of the most application of the directional drilling is drilling multiple wells from one location or platform. In drilling multiple wells from one location the major problem that faced is avoiding the collision with the offset wells that drilled near the proposed well in the same region. Therefore, the Potential of Collison between the wells can cause severe catastrophic accidents such as an explosion or oil spill. Several measurements of proximity calculation or methods have been adopted to control the distance between the wells, avoid the Collison, increas-ing the clearance along with smoothing the trajectory, Reducing the drilling time based on the anti-collision rules. A real case study of an offshore directional horizontal well drilled from the platform is studied through the paper. The proposed well is drilled in the neighboring of three Offset wells that should be Planned completely to avoid the Collison with them. The well is planned through an advanced anti-collision method that results in preventing the collision of well with optimized drilling performance through Oriented separation factor (OSF). This factor yields appropriate separation with OSF greater than 5. This yield efficient separation with offset well 1, offset well 2 and offset well 3 greater thant5, In addition to optimized drilling performance of 84% drilling versus 16% sliding that results in the completion of the well in 50 days with positive income that result in 8.55 Return on Investment (ROI).
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Glibovytska, Nataliia, and Lesya Plaksiy. "The drilling solution components’ impact on the environment and directions of its reduction." Biolohichni systemy 12, no. 1 (June 25, 2020): 52–57. http://dx.doi.org/10.31861/biosystems2020.01.052.
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The problem of the oil wells operation influence on the environmental ecological state is considered. The technical and biological aspects of the impact of drilling solution components used in the process of oil production on the biotic and abiotic environment are analyzed. The methods of preserving the cleanliness of reservoirs and soil during the wells operations and preventing pollutants from entering the environment are described. Possible effects of the toxic compounds of the drilling fluid on living organisms, in particular plants, have been identified. The components of drilling fluids of different types are characterized by different levels of environmental hazard. The lowest level of threat to environmental safety is inherent in the clay type of solution, and the polymer-potassium solution is characterized by the highest potentially dangerous impact on the biota. Despite belonging to the third class of moderately hazardous substances, sodium salts, calcium and chlorides, as components of drilling fluids, have the highest destructive effects on the environment. Soil salinization has the most detrimental effect on plants, as it breaks the osmotic equilibrium in the soil-plant system, disrupts the transport of organogenic elements throughout the plant, and reduces the availability of moisture and minerals. Increasing soil pH due to the ingress of calcium and sodium hydroxides as components of drilling fluids adversely affects plant growth and development. Stability of some groups of plants to the influence of components of drilling fluids and ability of phytoobjects to resist stress influence are noted. Halophytes are well adapted to the growth in conditions of excessive soil salinization due to the specific metabolic and structural features of the organization. Low oil content in drilling fluids can be released into the environment and, when accumulated in the aquatic and soil environments, lead to a number of destructive processes in living systems. Plants sensitive to oil pollution respond by reducing growth processes, increasing catabolic processes, and reducing assimilation function. In order to minimize the negative impact of chemicals on the environment of oil production territories, it is necessary to apply a comprehensive approach that combines the technical aspects of pollution control with effective biological methods. The urgent task of modern environmental science is to search for oil-resistant plant species that are effectively capable of converting toxic petroleum products to biota-safe compounds. Technological recommendations for the prevention of environmental pollution by drilling fluids are proposed, as well as phytorecultivation methods for controlling already polluted ecosystems.
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Tikebayev, A. T., and A. A. Beisenbayeva. "Improving the technology of drilling and well workover in conditions of unstable rocks." Neft i Gaz 140, no. 2 (February 15, 2024): 54–59. http://dx.doi.org/10.37878/2708-0080/2024-2.05.
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The exploration and extraction of hydrocarbons in regions characterized by unstable rock formations pose significant challenges to the oil and gas industry as increasing operational costs, safety hazards and environmental risks. This study focuses on advancing the technology of drilling and repairing wells in conditions where geological instability complicates traditional drilling processes, for example hole closure, collapse, fracturing etc. Moreover, it discusses all aspects of wellbore instability in drilling, from causes and symptoms to prevention and its impact. The mportance of ongoing research and development initiatives to advance drilling fluid technology suitable for unstable geological situations is also emphasized in the paper. In order to reduce the risk of borehole instability and maximize drilling efficiency, it investigates the formulation of high-performance drilling fluids with improved lubricity, filtration control, and shale inhibitory qualities. A frequent issue is lost circulation. Drilling fluid leaks into the nearby rock formations from the borehole cause this to happen. Numerous issues, like as decreased drilling efficiency, formation damage, and potentially environmental contamination, can result from lost circulation. The development of new technologies such as advancing drilling fluids, improving real-time monitoring are essential for improving the efficiency and safety of drilling and workover of wells in unstable rock formations.
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Muhammad Ahsan and Mike Wen Cao. "Driving sustainable success: Achieving emission reductions and operational excellence in ultra-deepwater drilling." World Journal of Advanced Engineering Technology and Sciences 12, no. 1 (June 30, 2024): 485–88. http://dx.doi.org/10.30574/wjaets.2024.12.1.0267.
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In the context of advancing sustainability goals, an operator faced challenges in drilling an ultra- deepwater exploration well offshore Malaysia, prompting the need for a solution to mitigate risks while minimizing environmental impact. Through a comprehensive life cycle analysis, emissions were quantified, and an emission baseline was established, laying the groundwork for achieving sustainability key performance indicators (KPIs). Baker Hughes' recommendation of their DELTA TEQ™ low-impact drilling fluid system, coupled with the unique rheology modifier additives, not only addressed operational challenges but also facilitated a significant 21% reduction in emissions. This integrated solution underscores a proactive approach towards sustainability in the oil and gas sector, leveraging data-driven insights to drive environmentally conscious practices and achieve overarching sustainability objectives.
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Breaux, E. J., S. A. Monroe, L. S. Blank, D. W. Yarberry, and S. A. Al-Umran. "Application of a Reservoir Simulator Interfaced With a Surface Facility Network: A Case History." Society of Petroleum Engineers Journal 25, no. 03 (June 1, 1985): 397–404. http://dx.doi.org/10.2118/11479-pa.
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Summary Management requires dependable information upon which to base decisions regarding large investments. The system discussed in this paper proves to be a viable tool for effectively managing reservoir development and provides several alternatives upon which management could base such decisions. A three-dimensional (3D), three-phase reservoir simulator is interfaced with a surface facility network simulator. The results are used in determining an integrated field development and operating plan for producing an onshore-offshore oil reservoir at a specified producing an onshore-offshore oil reservoir at a specified rate. Various aspects of alternative development and facility installation scenarios are investigated with the interfaced system. The requirements and sizing of major surface facilities and a drilling and workover program are determined over a 25-year study period. The most efficient development plan is one that combines cost-effective drilling and facilities scheduling while at the same time providing maximum operating flexibility and balanced providing maximum operating flexibility and balanced reservoir development. This technique has been applied to the future development planning of existing fields but is equally applicable to planning the development of new fields in any environment by altering the producing rules controls and reservoir and network models to account for the appropriate circumstances. Introduction Complex alternative development plans are evaluated in a decreased amount of time with a reservoir simulator interfaced with a surface facility network model. This study differs from typical reservoir simulation studies by recognizing surface facility and gathering system constraints and by responding to those constraints during the same timestep. The calculation procedure and example application of a reservoir simulator interfaced with a surface facility network simulator is presented by Emanuel and Ranney. The specific application of such a system to assist in planning the overall development of a major onshore offshore planning the overall development of a major onshore offshore oil reservoir is presented in this paper. The interfaced system simulates surface and subsurface pressures and three-phase fluid flow behavior throughout the system, allowing for the study of various operating strategies. The reservoir studied is an elongated anticline with several domes and underlies a surface area located onshore and offshore. This is an undersaturated oil reservoir with low GOR and saturation pressure. There is a multiple energy drive mechanism, active water drive in the south and fluid and rock expansion with limited water drive in the north. The current options for maintaining production from the field are limited to continued drilling and workovers. Production must be essentially dry and under natural Production must be essentially dry and under natural depletion since no water removal or artificial lift facilities are available. Production is being processed through three gas/oil separation plants. Primary development is along the crest of the structure, with drilling conducted from multiwell platforms. Future options for maintaining production are water removal, gas lift, trunkline and facility expansions, water injection, additional drilling, and well workovers. The reservoir simulator is a finite-difference, black-oil simulator that uses a 3D, three-phase formulation with an option for an implicit pressure/explicit saturation (IMPES) solution. Producing facilities are modeled using a multiphase producing facility simulator. This program simulates producing facility simulator. This program simulates steadystate, single- or multiphase fluid flow in wells, pipes, another equipment. Pressure loss calculations can be pipes, another equipment. Pressure loss calculations can be performed by a variety of methods published in the literature. performed by a variety of methods published in the literature. Fluid properties can be derived from generalized correlations, laboratory data, or compositional three-phase equilibrium calculations. A variety of network solution techniques are available; choice of technique depends on network complexity and fluid properties. The interface links the surface network simulator to the reservoir simulator through a suite of coupling routines. The simulators used in this system are a reservoir simulator for all subsurface calculations and a surface-facility network simulator for all vertical, wellbore, and surface fluid flow computations. SPEJ P. 397
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Ambati, Venkatesh, Nagendra Babu Mahadasu, and Rajesh R. Nair. "Seismic Driven Geomechanical Modeling of Uplifted and Subsided Wells in Mumbai Offshore and Its Engineering Implications." International Journal of Mathematical, Engineering and Management Sciences 6, no. 4 (July 18, 2021): 1025–43. http://dx.doi.org/10.33889/ijmems.2021.6.4.060.
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Seismic data provide evidence about hydrocarbon deposition, geological and geophysical subsurface information, including geomechanical aspects. Deriving and understanding geomechanical properties is crucial for reservoir management as it can avoid drilling and production-related problems that cause environmental impacts associated with land subsidence and uplift. The Poison's ratio (PR), Young Modulus (YM), and elastic moduli for a reservoir block were estimated using 3D seismic pre-stack data and well data. 3D Mechanical Earth Models (MEM) were also developed using the well logs, seismic horizons, and drilling data. Seismic data-derived geomechanical properties were compared with the mechanical earth models for the first time for this field. Well-tie analysis was used for inversion of 3D seismic data to extract detailed waveform and amplitude information. The brittleness index of the subsurface layers was estimated, which is a critical rock property that provides information about rock hardness and fragility phenomenon. The brittleness index has a diverse range from 5-35%, with significant contrast at shallow zones. PR and YM models generated from 3D MEM and seismic data have average values of 0.2 -0.6 and 5 - 28 GPa with significant contrast from shales and carbonates. The study recommends that the drilling through these problematic zones should be avoided to avoid wellbore problems that cause challenges in maintaining wellbore integrity and reservoir management in the North-Heera field, Mumbai Offshore Basin.
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Hoyle, W. Sloane, and S. Camille Peres. "Situation Awareness Offshore: Relevant Influencing Factors and Risks." Proceedings of the Human Factors and Ergonomics Society Annual Meeting 61, no. 1 (September 2017): 1700–1701. http://dx.doi.org/10.1177/1541931213601913.
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Offshore operations are an inherently hazardous activities that can result in catastrophic outcomes. The amalgamation of different hazards, constraints, and demands on offshore platforms can presents a substantial threat to the performance, productivity, and safety of workers. For most industrial accidents, there is a causal chain between human errors and organizational conditions. An investigation into the Macondo incident identified failures of situation awareness (SA) and risk perception as root causes of the disaster. Improving worker SA has become an important objective for the Oil and Gas industry. SA is a distinct, safety critical component for workers operating in complex, high-risk, and interactive work environments. Possession and maintenance of good quality SA is important for personnel whose work can be hazardous, complex, and pressured by time constraints. The drilling environment can change suddenly and for a drill crew, with an improper decision or inattention, the end result can be loss of life, severe injury, and cost millions of dollars in production loss. Offshore workers need to acquire and integrate information under operational conditions while contending with competing sources of information for their attention. SA can serve as a predictor of performance and has been particularly important where technical and situational complexity impacts the decision making efforts of the driller. A scoping literature review was conducted in order to identify how the influencing factors of elements of human factors on personnel and environmental safety, operational costs, and loss of time. Numerous databases were searched (e.g., EBSCOhost, Medline, PsychInfo, Science Direct) in combination other databases search using key terms: human factors or ergonomics and offshore with all of the following: drilling, production, fatigue, situation awareness, cognitive, oil and gas, as well as a search for human factors offshore and ergonomics offshore and human error offshore. Finally, our primary studies search was supplemented with a search of papers and abstracts within conferences. The fields of interest included stress, fatigue, interface design, human machine interaction, automation, safety culture and safety climate, risk perception and awareness. The purpose of this research was to present a summary of the current literature on the status of the oil and gas industry with regard to the adoption and integration of Human Factors methods, principles, and processes. Specific objectives were to summarize the state of the science regarding situation awareness for offshore operations, understand the importance of situation awareness for this environment, and determine key influencing factors that could affect drillers’ performance.
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Rakhmatullin, Nail Ravilovich, Raphail Anvarovich Suleymanov, and Timur Kamilevich Valeev. "Hygienic and environmental problems of oil and gas production on the offshore shelf." Sanitarnyj vrač (Sanitary Doctor), no. 4 (March 29, 2022): 282–94. http://dx.doi.org/10.33920/med-08-2204-05.
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The article discusses the results of research carried out within the framework of the industry program of Rospotrebnadzor “Hygienic scientific justification for minimizing risks to the health of the population of Russia” for 2016–2020 (p. 2. 16). During the development of oil and gas fields of the shelf in the waters of the Northern, etc. In addition to climatic conditions, dangerous and harmful factors of the production environment have a significant impact on working conditions: intense industrial noise, general and local vibration, insufficient lighting, contamination of the working area with dangerous chemicals and gases. Often, oil and gas in wells are under high pressure, which creates a threat of explosive emissions and fires. Among the unfavorable factors, the leading place is also occupied by noise, which affects workers during the entire shift from 7 to 30 or more days continuously. The noise sources are power plants and working mechanisms. Sound pressure levels in workplaces reach 72–107 dBA, in cabins 52–67 dBA. The equivalent daily sound levels are 71–102 dBA, and the total doses of acoustic energy affecting personnel exceed the permissible requirements by tens of times. In order to ensure the implementation of industrial and environmental control during the development of oil and gas fields on the offshore shelf, the main parameters, sources and mechanisms of marine water pollution have been determined. The sanitary and hygienic characteristics of the quality of sea water, ways and mechanisms of monitoring the state of sea waters are given. The analysis and updating of a number of existing regulatory and methodological documents in the field of ensuring the sanitary and epidemiological well-being of the population and the safety of environmental objects, including the draft SanPiN 2.2.3... “Sanitary rules and regulations for drilling rigs and structures used in the development of offshore hydrocarbon deposits” has been prepared.
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Rossi, Arley Silva, Marina Seixas Pereira, Jéssika Marina dos Santos, Irineu Petri Jr., and Carlos Henrique Ataíde. "Fundamentals of Microwave Heating and Drying of Drilled Cuttings." Materials Science Forum 899 (July 2017): 528–33. http://dx.doi.org/10.4028/www.scientific.net/msf.899.528.
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Drilled cuttings contaminated by non aqueous drilling fluids are the major waste from oil well drilling activities. More restrictive environmental legislation has led to the search for alternative technologies to promote cuttings decontamination according to the law. The mixture of cuttings and fluid returning from the well goes through a set of separation equipments, called solids control systems, in order to recover the drilling fluid for reuse. The cuttings from the solids control system must be decontaminated before they can be discharged into the sea. Microwave heating has been studied over the past few years as an alternative to promote the decontamination of this waste and has been shown to be a promising technology. This work aimed to investigate fundamental aspects of microwave heating and drying of drilled cuttings. The heating curve of two different drilling fluids commonly employed in well-drilling operations was obtained. The kinetics of drying of cuttings contaminated with these drilling fluids was also investigated. It was evaluated the behavior of organic phase and water removal in the microwave drying process.
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Gutierrez, David. "Case Study: Space-Age Directional Drilling Improves Efficiency, Economics." Journal of Petroleum Technology 74, no. 05 (May 1, 2022): 48–51. http://dx.doi.org/10.2118/0522-0048-jpt.
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Directional drilling has been used in oil and gas operations since the 1930s when onshore drillers employed the technology to reach offshore reservoirs. Over the years, technologies have been introduced to improve precision and control and at the same time have allowed multiple reservoirs to be produced through a single well, which reduces drilling costs and minimizes the environmental impact of the drilling process. In designing drilling plans, operators have considered economics when deciding whether to employ the traditional process of rotating the drillstring to control well trajectory or use more precise directional drilling techniques, but an either/or approach is not always the best one. The introduction of software that analyzes drilling conditions and determines the most appropriate drilling solution is changing the status quo, streamlining the drilling process and changing the playing field for drillers. The Evolution of Directional Drilling The widespread adoption of horizontal drilling from narrowly spaced slots on a centralized pad location has led to the introduction of complex wellbore geometry intended to maximize field development while minimizing geographical footprint. The growing need for precise execution of complicated well trajectories increased the demand for directional drilling expertise. Using a steerable bottomhole assembly (BHA) comprising a mud motor with a bent housing, an experienced directional driller can orient the bend of the motor in the direction prescribed on the well plan to steer the well on the intended trajectory in a process known as sliding. When the well trajectory is intended to remain relatively straight, the entire drillstring is rotated from surface in a process referred to as rotating. Experience and research have shown, however, that the well trajectory is rarely straight during periods of rotation due to rotational tendencies, a combination of systematic and random influences from BHA design, drilling parameters, and geological formation characteristics that can cause a significant divergence from plan. Rotational tendencies, along with designed well plan deviations, often require sliding to ensure the well follows the planned trajectory. All else being equal, it might seem that sliding should be applied across the board, but there are two reasons that sliding is not the default solution.
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Zeynalov, R. M., J. Kh Ibrahimli, E. A. Kazımov, N. M. Aliyev, Sh M. Khudiyeva, and U. E. Khalilova. "The study of regulation of characteristics of drilling mud on the green technologies." Azerbaijan Oil Industry, no. 03 (March 15, 2023): 59–62. http://dx.doi.org/10.37474/0365-8554/2023-3-59-62.
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The chemical agents, materials and drilling mud types developed on them and applied in the drilling of oil and gas wells significantly affect the technical-economic parameters of well construction. Moreover, in the time of the innovative technologies implemented in the context of the drilling mud, the consideration of the environmental aspects is crucially important and defines the most significant research areas as well. Therefore, the minimization of the impact of the drilling mud types and the particles of subsurface rocks transported from the depth on the environment is of no small interest. In the context of “Absheron” agent developed in our country based on the “green technologies”, the perspectives of its employment in the drilling process according to the results of the experimental studies are reviewed in the paper. Thus, due to the scientific-research surveys conducted and the introduction of the results obtained in the production, the advantages of the “green technologies” have been identified, the perspectives of the further development of this trend specified as well.
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Renilson, M., J. E. Soholt, and G. Macfarlane. "RECENT DEVELOPMENTS IN OCEAN ENGINEERING EDUCATION." APPEA Journal 41, no. 1 (2001): 783. http://dx.doi.org/10.1071/aj00047.
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Ocean engineering is a broad branch of engineering covering all aspects of engineering associated with the design, construction and operation of fixed and floating structures in the marine environment. It differs from naval architecture which traditionally focusses on ships and related ocean vehicles, and is of relevance to engineers in the offshore oil and gas industry.The Australian Maritime College (AMC) commenced running Australia’s first Bachelor of Engineering (Ocean Engineering) degree in 1997, with the first students graduating in 2000. The program was designed to meet the growing need of the Australian offshore oil and gas industry for graduate engineers skilled in the analysis and design of structures and facilities capable of operating in ever-increasing water depths. It builds on the already successful naval architecture degree offered by AMC, and has the first year completely in common.AMC makes use of its uniquely maritime focus and its wide variety of specialist facilities to produce graduates with a strong hands-on approach to complement their theoretical studies. The program features a unique blend of traditional marine and ocean-related subjects with a thorough grounding in hydrodynamics, wave theories, reservoir engineering, drilling technology, well design, offshore operations, oil and gas production technology and sub-sea engineering. As such, it is believed that the syllabus has a composition that is basically unique in the world.To support this new degree, AMC has commissioned the construction of a new Model Test Basin to complement its existing towing tank. This will have a plan form of 35 x 12 m and will be equipped with multi-directional wavemakers, making it ideal for student use, as well as consulting and staff research.The aim of the program is to produce engineering graduates with a broad theoretical background and a practical approach to problem solving. The ocean engineering graduates from AMC will be exceptionally well equipped to pursue successful careers within the international oil and gas industry.This paper describes briefly the various subjects that are unique to the ocean engineering degree and shows how the subject syllabi come together into a coherent program which will produce systems engineers rather than specialists. The course has just recently received Full Accreditation from The Institution of Engineers, Australia (IEAust).
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Timonina, N. N., D. S. Kuznetsov, and S. K. Kuznetsov. "Environmental aspects of industrial development of oil and gas fields in the Arctic territories of the Komi Republic." Arctic: Ecology and Economy 13, no. 3 (September 2023): 449–60. http://dx.doi.org/10.25283/2223-4594-2023-3-449-460.
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The paper considers the ecological aspects of the development of oil and gas fields in the Arctic zone of the Komi Republic. The authors inform about the state of the resource base, the dynamics of oil production, drilling of wells, and the increase in reserves. Oil and gas production dominates in the region’s economy, while at the same time impacts negatively on the environment. Field development, geological exploration, drilling of exploration and production wells, laying of pipelines, transportation of oil and other types of work are inevitably accompanied by harmful emissions into the atmosphere, pollution of water bodies and the earth surface. There is a thermal, mechanical and chemical impact on the environment. The situation is getting worse due to the increase in the share of hard-to-recover dense and high-viscosity oil in recoverable oil reserves. The development of hard-to-recover oil deposits is carried out via technologies that cause additional environmental damage. A large amount of oil enters the environment not during its extraction, but due to accidents at oil pipelines, especially inter-field and intra-field ones. The Arctic regions are ecologically very vulnerable due to the spread of permafrost. The technogenic thermal impact activates various negative processes, such as subsidence, swelling, erosion, landslides, flooding, waterlogging. Among the most polluted Arctic regions where oil production is carried out, is the Usinsky region with a number of large oil fields being developed, and extensive network of oil pipelines laid. The authors suggest a number of measures to minimize the negative impact on the environment during the construction and operation of oil production facilities. They outline the need to comply with the equipment technological operating modes, carry out preventive measures, including control of the technical condition of the basic equipment, to analyze the transported products (physical and chemical properties of the working environment), as well as to implement measures for the protection of surface and ground waters. It is expedient to upgrade the pipeline infrastructure in a timely manner with the use of the latest achievements in the field of pipe surface protection, and the elimination of decommissioned boreholes.
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Coolbaugh, Thomas, Andy Nicoll, Aaron Montgomery, Geeva Varghese, and Lucy Heathcote. "Effective Planning for Dispersant Operations – Making Decisions, Analyzing Options and Establishing Capability." International Oil Spill Conference Proceedings 2017, no. 1 (May 1, 2017): 2791–810. http://dx.doi.org/10.7901/2169-3358-2017.1.2791.
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ABSTRACT Within the oil spill response community, dispersant use is considered to be a key tool for the treatment and mitigation of oil spills. As a response technique, the benefits of dispersant application have been long proven, particularly in the case of large offshore spills such as those associated with the Sea Empress (UK, 1996), Montara (Australia, 2009) and Macondo (USA, 2010) incidents. Compared to other spill response techniques, dispersant application has less operational constraints associated with adverse weather conditions and can be rapidly applied from an aerial platform for larger spills far offshore. These reasons render dispersant application a critical tool in the toolbox for many offshore operators. Developing a successful dispersant application strategy requires comprehensive planning. For an offshore operator with a subsea well blowout risk, a number of elements should be carefully considered to ensure the successful execution of the dispersant application strategy. The decision making process should include a detailed evaluation of the oil type, release scenario and location, and the consideration of these parameters against the larger environmental and socio-economic needs of the stakeholder community. Once dispersant application is established to be a viable response option using a process such as Net Environmental Benefit Analysis (NEBA), the operator also needs to ensure that it is adequately resourced in terms of application platforms (vessel vs aircraft), monitoring techniques and supporting logistics. Well planned and detailed operational strategies are critical for successful subsea and surface dispersant operations, especially in the unlikely event of a large offshore spill. This paper summarizes the various operational considerations an offshore operator needs to assess during the preparedness stage for developing a viable dispersant application strategy. Drawing on the authors’ experiences in developing and implementing various preparedness projects globally, the different aspects of the dispersant planning process, including oil spill modelling to support decision making, ascertaining dispersant effectiveness for the oil type, selecting appropriate application techniques, establishing necessary logistical support and the setting up of an incident management team to support dispersant operations, will be discussed in detail. The goal of the paper is to build upon prior dispersant strategy discussions and provide an operationally focused blueprint for planning and implementing an effective dispersant application strategy in support of offshore operations.
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Demeshko, G., and R. Detsik. "Design and operation peculiarities of platform support vessels (PSVs)." Transactions of the Krylov State Research Centre 1, no. 395 (March 9, 2021): 85–98. http://dx.doi.org/10.24937/2542-2324-2021-1-395-85-98.
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Object and purpose of research. This papers discusses PSVs (or, in RS classification, Supply Vessels): special ships that provide offshore drilling rigs with drilling supplies, fuel, water, provisions, spare parts for equipment, as well as deliver personnel shifts to/from the platform and perform the functions of duty, rescue, fire, and environmental protection vessels. The purpose of the study is to develop a physical model of PSV functioning and give design recommendations for proper de-termination of its characteristics and properties. Materials and methods. Generalization and analysis of PSV design and operation, as well as analysis of Russian and foreign publications about PSV specifics, supported by systematized statistical materials sufficient for design recommendations. Main results. This work summarized the data on PSV properties, characteristics, design and operation requirements, as well as the ways to implement them in terms of hull shape, general arrangement, mission-specific equipment, conceptual type and power plant, suggesting a vision of PSV as design object. Regressive analysis performed by the authors is supported by a wide scope of design materials that summarizes PSV operation experience and development trends, thus preparing the basis for future PSV designs. Conclusion. PSVs are the main link in the offshore oil and gas production. The ships of this type are becoming more and more popular, especially in their multi-purpose variant. This paper makes it possible to formulate design requirements for them, as well as to trace the ways of their implementation. This paper also suggests the methods for determination of PSV dimensions, conceptual type and mission-specific equipment, as well as main design parameters, properties and transportation and operation capabilities.
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Putri, Mutiara R., Agus Setiawan, Titi Sari, B. Mayer, and T. Pohlmann. "TRAJECTORY MODEL FOR IDENTIFICATION OF OIL SPILL AROUND THE COAST OF PARI ISLAND, SERIBU ISLANDS, NORTH JAKARTA." Jurnal Ilmu dan Teknologi Kelautan Tropis 9, no. 2 (January 2, 2018): 657–64. http://dx.doi.org/10.29244/jitkt.v9i2.19299.
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Oil spills at sea are common in the shipping lanes of the ship as well as the locations of offshore oil drilling. Unfortunately, in every occurrence of the oil spill, we only see the effects after the occurrence, without knowing the original source. Indonesian Numerical Coastal Environmental Assessment (IndoNACE) is research collaboration between Indonesian and Germany by applying satellite data, numerical modeling, and field observations to make an assessment on environmental consequences to oil spills at sea. One of the locations of these research activities is Pari Island, Seribu Islands, North Jakarta. Simulation of hydrodynamic models around Pulau Pari with Hamburg Shelf Ocean Model (HAMSOM) was performed using tides, surface winds, and density difference of seawater as input. Afterwards, by utilizing results of the hydrodynamic model, the spreading of oil spills as well as the origin of the oil spills were estimated using forward and backward trajectory models, respectively. In the case study of Pari Island, there is a presence of thin film of oil in 5 November 2015 that disappears after one day. We suggest that the origin of oil spills were found on the beach Pari Island is expected from the east - northeast of Thousand Islands and is likely from the subsea pipeline which runs from the north to the city of Jakarta or shipping lanes through the Indonesian archipelagic sea lanes (ALKI) I of Karimata Strait up to Java Sea and the Jakarta Bay.
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Miller, Jessica, and Nick Quinn. "EXERCISE WESTWIND – A COLLABORATIVE OIL SPILL RESPONSE BY OIL & GAS OPERATORS AND AGENCIES." International Oil Spill Conference Proceedings 2017, no. 1 (May 1, 2017): 2851–62. http://dx.doi.org/10.7901/2169-3358-2017.1.2851.
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Abstract On June 9th, 2015, ACME Oil Company’s rig suffered a dynamic positioned ‘run-off’. The mobile drilling unit lost its station above the wellhead and a loss of well control was experienced. “A massive environmental emergency unfolded…affecting pristine coastline and masses of wildlife”. Incident Management and Field Response Teams were activated in a multi-agency operation, bringing together 200 personnel from 16 oil and gas companies and 18 government agencies and third party providers. Source control, aerial, offshore, nearshore, shoreline and oiled wildlife response capabilities were deployed and national/international support was utilised. Jointly managed by the Australian Marine Oil Spill Centre (AMOSC), the Australian Maritime Safety Authority (AMSA), the Federal Department of Industry and Science, and the Western Australian Department of Transport -Exercise Westwind was a successful multi-faceted marine spill response, demonstrating Australia’s collective Industry/Government capacity to respond to a large, offshore loss of well control incident in a remote and isolated location. ACME Oil Company was a fictitious company formed to enable the amalgamation of Australian petroleum companies to exercise industry arrangements under one ‘banner’ during the exercise period. ACME Oil Company had its own set of credentials, company website and Oil Pollution Emergency Plan. The company also held real time memberships with a number of service providers including AMOSC, Oil Spill Response Ltd, Trendsetter Engineering International, Oceaneering Australia and addenergy. Representing an innovative approach to spill response exercising, ACME Oil Company was a valuable and critical aspect to industry and governments participation under a non-attributable banner. Additionally, it enabled safe, widespread lessons to be observed, allowed for real-time testing of arrangements and provided a safe environment for regulators, stakeholder and industry interplay. The exercise was an efficient and practical solution for Industry titleholders and their third party supporting organisations, to test shared response resources and to ensure Industry arrangements for responding to oil pollution are in accordance with the Offshore Petroleum and Greenhouse Gas Storage (Environment) Regulations 2009. This paper will discuss the development program behind the exercise and the experience of managing an exercise of this nature. It will highlight the successes including the creation and implementation of a fictitious company and the extensive collaboration between the industry and government personnel involved. It will also look forward – where are we 11-months later? Can the history of exercising and/or response help us improve for the future-implementation of change and continued testing is critical in furthering our oil spill response capability and capacity.Exercise Westwind – Operational Phase TwoExercise Westwind – Operational Phase Two
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JPT staff, _. "E&P Notes (December 2020)." Journal of Petroleum Technology 72, no. 12 (December 1, 2020): 16–17. http://dx.doi.org/10.2118/1220-0016-jpt.
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China Shale-Gas Field Sets Production Record Sinopec recorded China’s highest daily output of shale gas at 20.62 million cubic meters (Mcm) at its Fuling shale-gas field in Chongqing, China, a key gas source for the Sichuan-East gas pipeline. The first major commercial shale-gas project in China, Fuling has continuously broken records for the shortest gasfield drilling cycle while significantly increasing the drilling of high-quality reservoirs covering more than 3 million m, according to Sinopec. Gasfield production construction was also expanded to raise production capacity. The company said the field maintains a daily output of 20 Mcm, producing an estimated 6.7 Bcm per year. Apache and Total Plan Suriname Appraisals Apache filed appraisal plans for its Maka and Sapakara oil discoveries in block 58 offshore Suriname. The company said another submission is expected for Kwaskwasi, the largest find in the block, by the end of the year. Operations continue for Keskesi, the fourth exploration target. There are plans to drill a fifth prospect at Bonboni in the North-Central portion of the concession. Partner company Total is assuming operatorship of the block ahead of next year’s campaigns. BP Emerges as Sole Bid for Offshore Canada Parcels BP was the only operator to place a bid in the Canada-Newfoundland and Labrador Offshore Petroleum Board (C-NLOPB) Call for Bids NL20-CFB01, which offered 17 parcels (4,170,509 hectares) in the eastern Newfoundland region. The successful bid was for Parcel 9 (covering 264,500 hectares) for $27 million in work commitments from BP Canada Energy Group. Subject to BP satisfying specified requirements and receiving government approval, the exploration license will be issued in January 2021. No bids were received for the remaining 16 parcels, which may be reposted in a future Call for Bids. Criteria for selecting a winning bid is the total amount the bidder commits to spend on exploration of the parcel during the first period of a 9-year license, with a minimum acceptable bid of $10 million in work commitments for each parcel. Beach Energy To Drill Otway Basin Well Beach Energy plans to drill at its Artisan-1 well about 32 km offshore Victoria, Australia, in the Otway basin, before the end of 2021. The well, located on Block Vic/P43, was to be spudded in 1H 2020 but was delayed due to COVID-19. The timeframe for drilling was confirmed by the National Offshore Petroleum Safety and Environmental Management Authority, which also said Beach is keeping open the option to suspend the well and develop it, pending reservoir analysis. Anchors, mooring chains, and surface buoys have already been laid for the well, which is in a water depth of approximately 71 m. The well is expected to take approximately 35–55 days to drill, depending on the final work program and potential operational delays. Diamond Offshore’s semisubmersible Ocean Onyx was contracted for the drilling program. Artisan is the first of Beach’s planned multiwell campaigns, which also include development wells at the Geographe and Thylacine fields. Hess Completes Sale of Interest in Gulf of Mexico Field Hess completed the sale of its 28% working interest in the Shenzi Field in the deepwater Gulf of Mexico (GOM) to BHP, the field’s operator, for $505 million. Shenzi is a six-lease development structured as a joint ownership: BHP (operator, 44%), Hess (28%), and Repsol (28%). The acquisition would bring BHP’s working interest to 72%, adding approximately 11,000 BOE/D of production (90% oil). The sale is expected to close by December 2020. Hess CEO John Hess said proceeds from the sale will help fund the company’s investment in Guyana. Greenland Opens New Offshore Areas Greenland opened three new offshore areas for application of oil and gas exploitation licenses off West Greenland. The areas are Baffin Bay, Disko West, and Davis Strait. The country also said it is working on an oil strategy to reduce geological uncertainty by offering an investment package to companies that engage in its Open Door Procedures. The procedures are a first-mover advantage to remove national oil company Nunaoil, as a carried partner, reducing turnover and surplus royalties. It is estimated to reduce the government take by 51.3% to 40.6%. Shell and Impact Oil & Gas Agree to South Africa Farmout Africa Oil announced Impact Oil & Gas entered into two agreements for exploration areas offshore South Africa. The company has a 31.10% share-holding in Impact, a privately owned exploration company. Impact entered into an agreement with BG International, a Shell subsidiary, for the farm-out of a 50% working interest and operatorship in the Transkei and Algoa exploration rights. Shell was also granted the option to acquire an additional 5% working interest should the joint venture (JV) elect to move into the third renewal period, expected in 2024. Algoa is located in the South Outeniqua Basin, east of Block 11B/12B, containing the Brulpadda gas condensate discovery and where Total recently discovered gas condensate. The Transkei block is northeast of Algoa in the Natal Trough Basin where Impact has identified highly material prospectivity associated with several large submarine fan bodies, which the JV will explore with 3D seismic data and then potential exploratory drilling. Impact and Shell plan to acquire over 6,000 km² of 3D seismic data during the first available seismic window following completion of the transaction. This window is expected to be in the Q1 2022. After the closing of the deal, Shell will hold a 50% interest as the operator and Impact will hold 50%. Impact also entered into an agreement with Silver Wave Energy for the farm-in of a 90% working interest and operatorship of Area 2, offshore South Africa. East and adjacent to Impact’s Transkei and Algoa blocks, Area 2 complements Impact’s existing position by extending the entire length of the ultradeepwater part of the Transkei margin. Together, the Transkei and Algoa Blocks and Area 2 cover over 124,000 km2. Area 2 has been opened by the Brulpadda and Luiperd discoveries in the Outeniqua Basin and will be further tested during 2021 by the well on the giant Venus prospect in ultradeepwater Namibia, where Impact is a partner. Impact believes there is good evidence for this Southern African Aptian play to have a common world-class Lower Cretaceous source rock, similar excellent-quality Apto-Albian reservoir sands, and a geological setting suitable for the formation of large stratigraphic traps. Following completion of the farm-in, Impact will hold 90% interest and serve as the operator; Silver Wave will hold 10%. Petronas Awards Sarawak Contract to Seismic Consortium The seismic consortium comprising PGS, TGS, and WesternGeco was awarded a multiyear contract by Petronas to acquire and process up to 105,000 km2 of multisensor, multiclient 3D data in the Sarawak Basin, offshore Malaysia. The contract award follows an ongoing campaign by the consortium in the Sabah offshore region, awarded in 2016, in which over 50,000 km2 of high-quality 3D seismic data have been acquired and licensed to the oil and gas industry to support Malaysia license round and exploration activity. The Sarawak award will allow for a multiphase program to promote exploration efforts in the prolific Sarawak East Natuna Basin (Deepwater North Luconia and West Luconia Province). The consortium is planning the initial phases and is engaging with the oil and gas industry to secure prefunding ahead of planned acquisition, covering both open blocks and areas of existing farm-in opportunities. Total Discovers Second Gas Condensate in South Africa Total made a significant second gas condensate discovery on the Luiperd prospect, located on Block 11B/12B in the Outeniqua Basin, 175 km off the southern coast of South Africa. The discovery follows the adjacent play-opening Brulpadda discovery in 2019. The Luiperd-1X well was drilled to a total depth of about 3,400 m and encountered 73 m of net gas condensate pay in well-developed, good-quality Lower Cretaceous reservoirs. Following a coring and logging program, the well will be tested to assess the dynamic reservoir characteristics and deliverability. The Block 11B/12B covers an area of 19,000 km2, with water depths ranging from 200 to 1800 m. It is operated by Total with a 45% working interest, alongside Qatar Petroleum (25%), CNR International (20%), and Main Street, a South African consortium (10%). The Luiperd prospect is the second to be drilled in a series of five large submarine fan prospects with direct hydrocarbon indicators defined utilizing 2D and 3D seismic data. BP Gas Field Offshore Egypt Begins Production BP started gas production from its Qattameya gasfield development offshore Egypt in the North Damietta offshore concession. Through BP’s joint venture Pharaonic Petroleum Company working with state-owned Egyptian Natural Gas Holding Co., the field, which is expected to produce up to 50 MMcf/D, was developed through a one-well subsea development and tieback to existing infrastructure. Qattameya, whose discovery was announced in 2017, is located approximately 45 km west of the Ha’py platform, in 108 m of water. It is tied back to the Ha’py and Tuart field development via a new 50-km pipeline and connected to existing subsea utilities via a 50-km umbilical. BP holds 100% equity in the North Damietta offshore concession in the East Nile Delta. Gas production from the field is directed to Egypt’s national grid.
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Sabu, Stephy, and T. P. Somasundaran. "Analysis of Bombay High Jacket during Load out and Transportation." Applied Mechanics and Materials 857 (November 2016): 41–46. http://dx.doi.org/10.4028/www.scientific.net/amm.857.41.
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Marine and offshore structures are constructed worldwide for various functions in a variety of water depths and environmental conditions like deep sea oil drilling, marine excavations etc. The offshore structures built onshore in “fabrication yards” have to be loaded out and transported offshore to the final assembly site, onboard a barge. Hence the design and analysis of an offshore structure must include load out and transportation calculations. The aim of the present work is to conduct load out and transportation analysis of a real time jacket platform installed in 78m water depth in the Mumbai High Basin. The platform was loaded onto a launch barge by lifting. The lift analysis was performed in SACS (Structural Analysis Computer System), to assure no overstressing of the jacket components during load out operations. The analysis was also used to compare the predicted and allowable values of the jacket/barge deflections. The motion analysis was performed in SACS, to determine the Response Amplitude Operators, from which, maximum values for the relevant degrees of freedom were predicted. The obtained data was used to compute the inertia forces and a deterministic structural analysis for the barge was performed. The predicted values obtained were well within the allowable values rendering the design safe. The jacket was also analyzed to determine the significance of water entry forces on its horizontal members during transportation. The predicted stresses were well within the allowable stresses; hence the transportation of the structure from the fabrication site to the Mumbai High Basin is safe.
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Singh, Dr Santosh Kumar. "A Comprehensive Analysis of Marine Life Pollution Using Machine Learning Techniques on historical shipping Pollutants data." INTERANTIONAL JOURNAL OF SCIENTIFIC RESEARCH IN ENGINEERING AND MANAGEMENT 08, no. 01 (January 8, 2024): 1–10. http://dx.doi.org/10.55041/ijsrem27969.
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Oil spills significantly threaten marine and coastal ecosystems, resulting in devastating ecological and economic consequences. The current research highlights the key aspects surrounding oil spills, including their causes, environmental impacts, and mitigation strategies. Oil spills, resulting from accidents during offshore drilling, transportation, or natural seepage, pose severe ecological and societal challenges. These incidents release vast quantities of oil into marine ecosystems, leading to widespread environmental degradation. The impact of oil spills is influenced by factors such as spill volume, oil type, environmental conditions, and response effectiveness. Ecologically, oil spills harm marine life through toxic effects, habitat destruction, and interference with reproductive cycles. Birds, marine mammals, fish, and shoreline organisms suffer from oil exposure, leading to long-term population declines. The economic consequences are significant, affecting fishers, tourism, and coastal industries. The clean-up process involves mechanical removal, chemical dispersants, and controlled burns, each with its environmental trade-offs. Oil spill assessment methods encompass satellite monitoring, modeling, and ecological surveys to estimate damages and aid restoration efforts. Prevention measures include stricter regulations, technological advancements, and industry best practices. Public awareness and international cooperation are vital for enhancing spill preparedness and response. In the paper, oil spills continue to challenge environmental sustainability and economic stability. Addressing their multifaceted impacts demands an integrated approach involving mitigation, rigorous assessment, and global collaboration to prevent future disasters and safeguard our oceans and coastlines. An expansive dataset gathered from Queensland, Australia, incorporating intricate information about ships, regions, longitudes, latitudes, and pollutants, the study markedly advances the capability to identify oceanic oil spills and enhances our understanding of the resulting impact on marine life. In that, algorithms are used of machine learning techniques such as SVC and LogisticRegression. In the course of the study, machine learning techniques are applied, featuring algorithms like Support Vector Classification (SVC) and Logistic Regression. These algorithms play a crucial role in the analysis, contributing to the extraction of valuable insights from the dataset. Keywords: Bilge, Diesel, Hydraulic Oil, Types of Ship, Machine learning algorithms
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Shmoncheva, Yelena Y., Gullu V. Jabbarova, and Timur E. Abdulmutalibov. "Drilling fluids in complicated conditions: a review." Nafta-Gaz 79, no. 10 (October 2023): 651–60. http://dx.doi.org/10.18668/ng.2023.10.03.
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The review in this article focuses on various aspects of drilling extended reach (ERD) wells. Reaching extreme depths and setting world records for deviation illustrates the importance of well design and operating strategies. Studies of articles describing various locations, including Sakhalin Island in Russia and offshore Vietnam, provide insight into ERD operations. Furthermore, the challenges of drilling in specific geological conditions, such as layered sandstones and reactive clay, are considered. Particular attention is paid to issues related to wellbore instability and drilling fluid optimization. The results of technical studies highlight the key role of maintaining wellbore stability in achieving successful ERD results. The articles emphasize the importance of understanding geomechanical factors, employing optimal mud weight, lubrication, and specialized drilling fluids to counteract instability. It demonstrates that maintaining appropriate mud weights and employing specific drilling techniques are crucial for mitigating instability-related issues. The integration of mechanical and chemical approaches is advocated for effectively managing shale-related instability. The utilization of innovative materials and fluid systems is central to the successful resolution of stability-related problems. The incorporation of micronized sealing polymers in conjunction with conventional plugging materials is detailed as an effective approach to counter wellbore instability. The synergistic combination of materials, additives and mud salinity is showcased to achieve effective shale stabilization and optimize drilling time. The authors emphasize the importance of selecting the optimal composition for each well based on experience and laboratory testing and present laboratory-tested solutions that have been successfully applied in field operations. In summary, these articles collectively offer insights into a range of strategies to combat wellbore instability. They cover the use of advanced materials, innovative fluid systems, and chemical approaches to maintain wellbore stability, improve drilling efficiency, and reduce nonproductive time.
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JPT staff, _. "E&P Notes (December 2022)." Journal of Petroleum Technology 74, no. 12 (December 1, 2022): 14–16. http://dx.doi.org/10.2118/1222-0014-jpt.
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ExxonMobil, Partners Tout New Angola Block 15 Discovery ExxonMobil has made a new oil discovery with the Bavuca South-1 exploration well in Block 15 offshore Angola. The well is part of the Angola Block 15 redevelopment project targeting to deliver around 40,000 B/D of new oil production. According to ExxonMobil, the well encountered 30 m of hydrocarbon-bearing sandstone. The probe is located approximately 365 km northwest of Luanda and was drilled in 1100 m of water by the Valaris DS-9 rig. As the block’s operator, ExxonMobil is leading the installation of new technology and a multiyear drilling program aimed at adding new production volumes to help offset natural production declines. There have been 17 previous discoveries on Block 15: Hungo, Kissanje, Marimba, and Dikanza in 1998; Chocalho and Xikomba in 1999; Mondo, Saxi, and Batuque in 2000; Mbulumbumba, Vicango, and Mavacola in 2001; Reco Reco in 2002; and Clochas, Kakocha, Tchihumba, and Bavuca in 2003. ExxonMobil affiliate Esso Exploration Angola (Block 15) Limited is the operator of Block 15 and holds a 36% interest. BP Exploration (Angola) Limited holds 24%, ENI Angola Exploration BV holds 18%, Equinor Angola Block 15 AS holds 12%, and Sonangol P&P holds 10%. The National Agency for Petroleum, Gas, and Biofuels (ANPG) is the Block 15 concessionaire. Neptune Energy Begins Drilling Calypso Exploration Well Neptune Energy has spudded its Calypso exploration well 6407/88 S in the Norwegian Sea utilizing semisubmersible Deepsea Yantai. The Calypso prospect is located 14 km northwest of the Draugen field and 22 km northeast of the Njord A platform, within the Neptune-operated PL938 license. Calypso is positioned within one of Neptune’s core areas on the Norwegian Continental Shelf. In the event of a commercial discovery, Calypso could potentially be tied back to existing infrastructure. The reservoir target is the middle and lower Jurassic formations and is expected to be reached at a depth of approximately 2960 m. The drilling program comprises a main bore (6407/8-8 A) with an optional sidetrack (6407/8-8 S) based on the outcome of the exploration well. Neptune Energy operates the well with a 30% working interest. Partners include OKEA ASA, 30%; Pandion Energy AS, 20%; and Vår Energi ASA, 20%. Petrobras Strikes Oil Near Sepia Field Petrobras has a new oil find at its 4-BRSA-1386D-RJS (Pedunculo) well in the extreme northwest of the Sépia field in Brazil’s Santos Basin. The well spud in late July in a water depth of 2200 m, and the oil-bearing interval was verified by logs and fluid samples. According to Petrobras, the effective thickness of the oil column is one of the largest ever recorded in Brazil. The discovery is in the Sepia coparticipation area and comprises the Sepia block acquired by Petrobras (100%), and the Sépia-ECO block, which was acquired in December 2021 in the ANP’s second bidding round of surplus volumes. Petrobras (operator) was awarded Sépia-ECO along with partners TotalEnergies, QatarEnergy, and Petronas Petróleo Brasil Ltda., with Pré-Sal Petróleo SA as manager. The Sépia shared reservoir is currently producing 170,000 B/D. Petrobras also successfully completed the test at the pioneer well 1-BRSA-1381-SPS (Curaçao) in the pre-salt of the southwestern part of the Santos Basin. The new discovery is located 240 km from the city of Santos-SP, at a depth of 1905 m, in the Aram Block. The test evaluated a thick range of pre-salt carbonate reservoirs, in which it was possible to know its productivity through dynamic production data, according to Petrobras. During the test, oil samples were collected that will be characterized by laboratory analyses. The consortium will continue its activities in the Aram Block, aiming to evaluate the dimensions and commerciality of the new accumulation. The block was acquired in March 2020, in the sixth bidding round of the ANP, under the production-sharing regime, with Pré-Sal Petróleo SA as manager. Petrobras is the operator of the block (80% interest) in partnership with CNPC 20%. Shell, Murphy Eye Fresh Mexican Gulf Wildcats Shell is preparing to drill an exploration test in the Salina basin in offshore Mexico. According to Mexican hydrocarbons regulator CNH, the supermajor intends to spud the Jokol-1EXP wildcat in Block 28 starting in January 2023. The operator plans to use drillship Maersk Voyager for the work. The rig has been drilling the Zanderij-1 probe in Block 42 offshore Suriname and is expected to depart for Mexico soon. The Jokol-1EXP well is set to test a prospective light-oil reservoir at final depth of around 5586 m. The wellsite is roughly 40 km southwest of the Tamha-1EXP well. Meanwhile, Murphy Oil is drilling ahead on the deepwater Tulum-1EXP, where it hopes to tap 150 million BOE in reserves off the coast of Tabasco. The operator’s Mexican subsidiary, Murphy Sur, received authorization from CNH earlier this year. Murphy will use the Valaris DPS-5 semisubmersible to target lower Miocene and Oligocene formations and is drilling Tulum-1EXP as a deviated well to a depth of 5569 m. Tulum-1EXP is the second exploratory well of the Block 5 consortium led by Murphy Sur (40%), with partners PC Carigali Mexico Operations, Petronas’ Mexican subsidiary, and Wintershall Dea holding 30% each. Block 5 is in the center of the highly touted Salina Basin, a deepwater area in Mexico with significant hydrocarbon potential. CNOOC Has Certified Gas Find With Baodao 21-1 The proved gas-in-place of CNOOC’s Baodao 21-1 gas field has been certified at 50 billion m3 by the Chinese government. Baodao 21-1 gas field is in Baodao Sag, Qiongdongnan Basin, Western South China Sea in water depths ranging from 660 to 1570 m. The main gas-bearing zone is the Paleogene Lingshui formation, and the discovery is in condensate gas reservoirs. The discovery well Baodao 21-1 completed at a total depth of 5188 m, encountering 113 m of gas pay. The well is tested to produce an average of 587,000 m3 of natural gas per day. Baodao 21-1 is the first deepwater, deep-stratum large gas field in the South China Sea, realizing the biggest discovery in more than half a century in Songnan-Baodao Sag, according to CNOOC. ADNOC Sets Well-Length Record Abu Dhabi National Oil Company (ADNOC) said it set a new world record for the longest oil and gas well at its Upper Zakum Concession. Stretching 50,000 ft, the well is around 800 ft longer than the previous world record set in 2017. ADNOC Drilling drilled the well from Umm Al Anbar, one of ADNOC Offshore’s artificial islands. The extended-reach wells will tap into an undeveloped part of the giant Upper Zakum reservoir with the potential to increase the field’s production capacity by 15,000 B/D. Umm Al Anbar is one of Upper Zakum’s four artificial islands, serving as a hub for offshore drilling and operations. The producer added that its use of the artificial island concept has resulted in cost savings and environmental benefits compared to conventional approaches that traditionally require more offshore installations and infrastructure. New Tampen Area Wells Planned The Norwegian Petroleum Directorate issued to Equinor, Aker BP, and Var Energi a pair of drilling permits for exploration wells in the Tampen area of the Norwegian North Sea. The partnership has applied to drill the 34/6-6A wildcat in PL-554 using drilling rig Transocean Spitsbergen. The well is located to the northeast of the Visund field. Equinor will operate the well with a 40% working interest. Aker BP and Var Energi each hold a 30% stake. The second probe, 34/6-6S, was also permitted by the same partnership in the same license. Petronas Strengthens Partnership With TotalEnergies and Shell Through New PSC Petronas has signed a production-sharing contract (PSC) with TotalEnergies EP Malaysia, Petronas Carigali Sdn Bhd (PCSB), Sabah Shell Petroleum Company Limited (SSPC), and Shell Sabah Selatan Sdn Bhd (SSS) for Block 2K, an ultradeepwater block located off the coast of Sabah. Block SB 2K, with depths up to 3000 m, covering 1952 km2, is in the northwest ultradeepwater area within a proven hydrocarbon basin. Under the PSC terms, TotalEnergies will be the operator with a 34.9% participating interest. PCSB holds a 40% participating interest while the remaining 25.1% is equally split between the other two partners, SSPC and SSS. The signing of the PSC for Block 2K completes the licensing of the five ultradeepwater blocks off the coast of Sabah, along the newly identified Oligo-Miocene carbonate trend proven by Tepat-1 oil discovery in Block N in 2018. Block 2V was signed last year followed by Blocks 2W and X early this year. A total of four wells are expected to be drilled in these blocks in 2022 and 2023.
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Park, Jaewoo, Craig Hyslop, Da Zhou, Arjun Srinivasan, Patricia Montoya, Debra Carlo, Mike Lahey, et al. "Integrated processing and interpretation to image and derisk a carbonate reservoir clouded by shallow gas — A case study from offshore Vietnam." Leading Edge 40, no. 5 (May 2021): 357–64. http://dx.doi.org/10.1190/tle40050357.1.
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Carbonate reservoirs are increasingly becoming an important resource for hydrocarbon production because they contain the majority of remaining proven oil and gas reserves. In this context, carbonate reservoirs could represent new opportunities; however, there is still a lack of understanding of their subsurface status and characterization. Carbonate reservoirs are more difficult to evaluate than their siliciclastic counterparts because many aspects of carbonate rocks make their seismic image signature complex and difficult to interpret. Moreover, the presence of complex overburden such as shallow gas accumulation can exacerbate amplitude and phase fidelity at the reservoir, which introduces an additional imaging challenge. This makes field development of carbonate reservoirs extremely difficult because field development requires detailed delineation of characteristic karst features to avoid drilling hazards and sudden water breakthrough. In this paper, we demonstrate that a tight integration of signal processing, depth model building, and imaging, as well as near-real-time seismic interpretation feedback, is the key to success for imaging complex carbonate reservoirs with overburden challenges. Our findings show that such an integrated approach can result in a substantially better image, reduced depth uncertainty, and better delineation of karst and fractures. It can also aid in well placement and improve reservoir property modeling.
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Venugopal, Shangkar. "Operational and safety aspects of drill stem testing—getting it right." APPEA Journal 50, no. 1 (2010): 71. http://dx.doi.org/10.1071/aj09006.
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Drill stem testing (DST) is recognised by many operating oil and gas companies to be one of the most hazardous operations routinely undertaken. Well testing has a higher potential for loss of life, loss of assets, environmental catastrophe and budget overrun than any other time in the exploration operations. Therefore, it is of great importance to the industry that such operations are extremely well planned and executed. Planning a DST is an extremely complex task and requires a great deal of experience. This paper provides an insight into the techniques and procedures that are used in all the major operational and safety aspects of oil and gas DST. It uses a structured approach to guide the reader through the various best practices that are required to effectively plan and implement a DST operation under just about any circumstances worldwide, onshore or offshore. The project also includes design parameters for contingency conditions that were not normally present during equipment operations but could exist in emergency situations. Problems and solutions associated with perforation, adverse hole conditions, and high-pressure, high-temperature (HPHT) conditions are also presented. Additionally, this paper includes an overview on environmental requirements, which provides information associated with risk management and legislation.
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Abdussami, Muhammad R., Tahmid Alam, A. H. M. Iftekharul Ferdous, and Galib Nakib Rahman. "Overview and Prospect of Off-Shore Floating Nuclear Power Plant in Bangladesh." European Journal of Engineering and Technology Research 1, no. 6 (July 27, 2018): 63–67. http://dx.doi.org/10.24018/ejeng.2016.1.6.241.
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“Off-shore floating nuclear power plant (OFNP)” is a new concept in the era of secured electric power generation process though the concept of “Floating Nuclear Power Plant” and “Off-shore Power Plant” is not a new concept. We have tried to give a view of the OFNP concept to immune the effect of earthquake, tsunami on the nuclear power plant for Bangladesh. A group of researchers throughout world is also doing project on this. Sitting on two mutual technology: “light-water nuclear reactors” and “offshore oil and gas drilling platform”, this concept has a lot of aspects to reduce the effect of natural disaster. This concept describes simplified construction, low environmental impact, safety of the nuclear reactor, specialized facility of decommissioning, reliable cooling system, safely transmission of the electric power. As the demand of electricity is increasing in Bangladesh due to increased number of population, the government of Bangladesh is trying to introduce the new mode of electricity generation; Nuclear power. The concept of the OFNP might be best choice in this sector due to different factors and facilities. This paper shows the prospect of OFNP in Bangladesh.
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Solheim, A., S. S Pettersen, J. J. G Agis, P. O. Brett, B. E. Asbjørnslett, S. O. Erikstad, and S. L. Ellefmo. "EARLY STAGE DECISIONS IN MARINE SYSTEMS DESIGN FOR DEEP-SEA MINING." International Journal of Maritime Engineering 164, A4 (April 3, 2023): 357–72. http://dx.doi.org/10.5750/ijme.v164ia4.771.
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This article studies the prospects for deep seabed mining as a future viable maritime industry, and discuss the commercial, operational, and technical viability of deep seabed mining. By the use of a business development approach originating from the maritime industry, we analyse opportunities for a virtual deep seabed mining project, and identify aspects of stakeholder performance expectations, contextualised by the competitive positioning and identification of related project risks. We discuss strategies and pit-falls when positioning a deep seabed mining venture within the wider mining and metal production value chain, and use a case example in the Northern Atlantic Ocean to study the prospects for a deep seabed mining operation and subsequent system design implications. Furthermore, we contrast to well-established industries like offshore oil and gas, and traditional land-based mining. The study promotes several critical aspects and problem areas when approaching marine systems design for deep seabed mining.
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Jain, Siddarth. "Technology Focus: Mature Fields and Well Revitalization (January 2024)." Journal of Petroleum Technology 76, no. 01 (January 1, 2024): 63–64. http://dx.doi.org/10.2118/0124-0063-jpt.
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In the relentless pursuit of a sustainable energy future, the often-overlooked potential of mature oil fields emerges as a beacon of hope. Once considered as being on the brink of abandonment, aging reservoirs are proving to be valuable assets as innovative hydrocarbon recovery techniques and re-envisioning of these fields for decarbonization opportunities are transforming them into reservoirs of opportunity. The sheer scale of mature oil fields globally is staggering. Advanced technologies and techniques, championed by internal initiatives that maximize the use of available data, are breathing new life into these reservoirs. While renewable energy sources are gaining traction, the world still relies heavily on hydrocarbons for its energy needs. One of the key advantages of reusing mature oil fields is the reduction in the need for new exploration and drilling. Exploring and developing new fields can be costly both financially and environmentally. By maximizing the recovery from existing fields, the industry can significantly decrease its ecological footprint and capitalize on the infrastructure already in place. Furthermore, the economic benefits of repurposing mature oil fields are substantial. The highlighted advancements focus on storage of various gases such as hydrogen, CO2, and natural gas, capitalizing on the knowledge gained from producing these fields for decades. Mature fields provide a bridge between the present and the future, offering a pragmatic solution to meet energy demands while mitigating environmental impact. Recommended additional reading at OnePetro: www.onepetro.org. SPE 214437 Fluid Modeling of Underground Hydrogen Storage in a Depleted Natural Gas Field by Markus Hays Nielsen, Whitson, et al. IPTC 22786 Particulate Wellbore Fluid-Strengthening Methodology—Design and Application in an Offshore Vietnam Severely Depleted Sand Reservoir by Dourado Motta Marcelo, SLB, et al. SPE 213405 Characterizing Movable and Nonmovable Zones in a Mature Carbonate Reservoir: A Novel Work Flow Using Resistivity Logs by Saud Al-Otaibi, Saudi Arabian Chevron, et al. SPE 214410 A Comparative Study of Hydrogen/Natural Gas Storage in a Depleted Gas Field in the Netherlands Using Analytical and Numerical Modeling by S. Hamidreza Yousefi, TNO, et al.