Relevant bibliographies by topics / Offshore oil well drilling

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  1. Journal articles
  2. Dissertations / Theses
  3. Books
  4. Book chapters
  5. Conference papers
  6. Reports

Academic literature on the topic 'Offshore oil well drilling'

Author: Grafiati
Published: 4 June 2021
Last updated: 31 July 2024

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Journal articles on the topic "Offshore oil well drilling"

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Ganiev, R. I., Luc Deboer, A. H. Agliullin, and R. A. Ismakov. "Dual gradient drilling: a pilot test of decanter centrifuge for CAPM technology." SOCAR Proceedings, SI2 (December 30, 2021): 70–79. http://dx.doi.org/10.5510/ogp2021si200585.

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The article is about problem of drilling deepwater oil and gas wells that consists in complicating and increasing cost of their well design due to narrowing mud window at different depths. The authors analyse drilling technology developed and applied in practice of offshore drilling with a dual gradient drilling, which allows drilling significant intervals without overlapping an intermediate casing string. Based on analysis of these technologies and taking into account their disadvantages the authors proposed and tested a new drilling technology of dual gradient drilling with placement of all necessary innovative equipment on drilling platform. Keywords: managed pressure drilling; deepwater drilling; offshore drilling; dual gradient drilling; riser; oil and gas exploration in sea.
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Raharjo, Agus Denny Unggul. "HUBUNGAN STRATEGIS PADA EVOLUSI TEKNOLOGI LEPAS PANTAI DI INDUSTRI MIGAS." INTAN Jurnal Penelitian Tambang 5, no. 1 (May 31, 2022): 1–6. http://dx.doi.org/10.56139/intan.v5i1.104.

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Offshore operation in oil and gas industry defined as any drilling and production operation located or operating on a body of water, at some distance from the shore relatively to what identified as onshore operation which is generally means in land operation. Offshore drilling and production operation was a relatively new industry compare to the history of oil industry itself. Technologies take major part in development of offshore project, technologies make what impossible become possible in offshore industry. Offshore drilling and production industry can be possible because of technology innovation. However the drive to explore offshore resources come from high demand on oil and gas as well as depleted resources in onshore resources. One suggested that there is strategic interaction among entities in oil industry, as for offshore operation the strategic interaction lead to evolution of offshore technology. The strategic interaction between two relatively same profiles oil related company will depend on the cost of technology. There is tendency in oil and gas industry, if one company successful in using a kind of technology the other companies will follow the pad. Technology takes a big part in offshore drilling and production industry. The strategic interaction in offshore industry related to the cost of technology.
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Dmitrievsky, A. N., N. A. Eremin, A. D. Chernikov, and S. О. Borozdin. "Intelligent Complication Prevention Systems for Safe Well Construction." Occupational Safety in Industry, no. 6 (June 2022): 7–13. http://dx.doi.org/10.24000/0409-2961-2022-6-7-13.

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The results of many years of research on the prevention of complications in the construction of oil and gas wells using machine learning methods are presented in the article. The issues of creating prototypes of intelligent systems to prevent complications when drilling wells on land and offshore are considered. The purpose of the intelligent systems to prevent complications during well drilling is to warn the driller in advance about the possibility of a violation of the regular drilling regime. Intelligent systems for preventing complications during well construction help to increase the economic efficiency of drilling oil and gas wells. Large volumes of geodata from the stations of geological and technological measurements during drilling vary from units to hundreds of terabytes. Creation of the neural network modeling software components is aimed at revealing hidden and non-obvious patterns in the datasets, i.e. in the processed, labeled and structured information from the stations of geological and technological measurements in the tabular form. Hierarchical distributed data warehouse was formed containing real-time drilling data in WITSML format using a SQL server (Microsoft). The geodata preprocessing and loading module for the WITSML repository uses the Energistics Standards DevKit API and Energistic data objects to work with the geodata in the WITSML format. The accuracy of predicting drilling problems achieved with the help of the developed intelligent systems can significantly reduce unproductive time spent on eliminating stuck pipes, mud losses and gas, oil and water shows. Large-scale implementation of the intelligent systems to prevent complications in well drilling will ensure the achievement of a zero-carbon footprint in the environmentally friendly drilling of wells on the land and offshore.
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Carpenter, Chris. "Technical Solution Improves Safety, Efficiency of Well Construction Offshore Australia." Journal of Petroleum Technology 73, no. 10 (October 1, 2021): 46–48. http://dx.doi.org/10.2118/1021-0046-jpt.

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This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 202353, “Drilling-Performance and Risk-Management Optimization Offshore Australia: Improving Overall Safety and Efficiency of the Well-Construction Process,” by Chandrasekhar Kirthi Singam, Farshid Hafezi, and Clyde Rebello, Schlumberger, 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 emergence of real-time well construction performance-monitoring centers has improved the service delivery for operators across numerous offshore oil fields in Australia significantly. The complete paper details new technologies and work flows implemented for three Australian offshore wells, with the primary objective of improving drilling efficiency while managing associated risks. Additional objectives included optimizing daily operational performance, thus delivering time savings for the operator and highlighting areas of possible improvements. Introduction The paper describes a successful drilling campaign in a challenging field in the Timor Sea. It describes how data analysis, risk evaluation, and real-time performance monitoring can be influential in saving rig time and project success. As part of this project, a major operator in Australia decided to perform an infill drilling campaign involving three high-angle directional wells (J type) in a saturated, complex field. The campaign design stage was initiated in 2017 with a main objective of delivering the project within authority-for-expenditure (AFE) budget and with planning for all potential challenges. Technical Overview The technical solution (Fig. 1) was deployed using drilling-interpretation software and executed its work flows to achieve the required objectives.
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Li, Zhong, Lai Bin Zhang, Fan Luo, Bai Ling Zhang, and Shu Ying Tan. "Mechanical Property Analysis of Materials and Application of Buttress Thread Buckle Marine Conductor." Advanced Materials Research 233-235 (May 2011): 2043–46. http://dx.doi.org/10.4028/www.scientific.net/amr.233-235.2043.

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At present, offshore drilling operations often use buttress thread casing as surface casing. The design conception of buttress thread casing comes from the offshore drilling’s demands and this kind of casing is mainly used as surface casing. This paper has taken material mechanical experiment, numerical simulation analysis and field test, the research results show that the various parameters of buttress thread casing fully complies with the drilling design requirements and the offshore oilfield production demands. This product can reduce drilling cost effectively, improve working efficiency and safety, and realize manufacture domestically. Meanwhile, the development of this project will fill the blank of the ERW (Electrical Resistance Weld) casing in CNOOC (China National Offshore Oil Corporation), and have a broad prospect of application.
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Shestakov, Roman, Gleb Kamenskiy, Konstantin Rezanov, Stepan Zubkov, and Vyacheslav Dryakhlov. "Topside optimization methods for offshore platform mass-size characteristics: Utilizing modular drilling rigs." Journal of Applied Engineering Science 22, no. 2 (2024): 351–66. http://dx.doi.org/10.5937/jaes0-44531.

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Offshore oil and gas production is associated with many times higher capital investments in development than onshore projects. In this regard, operators often give preference to less risky and less capital-intensive onshore projects. This, in turn, slows down the development of offshore production technologies and the development of the huge resource base of the Arctic shelf. Significant influence on the value of capital costs of offshore projects is the cost of offshore field development facilities, including the cost of offshore platforms - floating or stationary offshore oil and gas production structure consisting of topside and substructure, designed to accommodate drilling and/or production equipment, utilities equipment, systems and devices required to perform the functions assigned to the structure. One of the ways to reduce capital expenditures on platform construction is to reduce its weight and size, which can be achieved by using more modern compact technological equipment, improving design and construction technologies, as well as changing the platform concept itself. One of the key and largest functional units of topside offshore platform is the drilling complex. The possibility to quit the construction of the stationary drilling module and drill the well stock by alternative means, using jack-up or modular drilling rig, could become a growth driver for the economics of offshore construction projects. In this paper, a comparative analysis of alternative drilling methods and evaluation of economic efficiency of modular drilling rig application is carried out. As a result of the study, the following main conclusions were obtained: The analysis of statistical data has shown that the cost of topside structures linearly depends on the mass and dimensional characteristics, in which regard the optimization issues are highly important; The analysis of studies has shown the following: the studies do not offer a system of specific solutions to reduce the mass-dimensional characteristics of the upper structure of the offshore platform. The development of a solution for year-round drilling of the well stock on offshore platforms without the construction of a stationary drilling complex will significantly reduce the capital costs of development.
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Feder, Judy. "Collaboration and Optimization Processes Contribute to Ultra-ERD Offshore Well Success." Journal of Petroleum Technology 73, no. 05 (May 1, 2021): 61–62. http://dx.doi.org/10.2118/0521-0061-jpt.

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This article, written by JPT Technology Editor Judy Feder, contains highlights of paper SPE 202251, “Transforming the Mindset To Drill Ultra-ERD Wells With High Tortuosity,” by Barry Goodin, SPE, Duane Selman, and Andy Wroth, Vermilion Oil and Gas, 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 complete paper describes the extensive integrated engineering collaboration and optimization process that allowed an operator to push the drilling and completion envelope to drill a pair of complex, ultra-extended-reach-drilling (ERD) wells in the mature Wandoo field in the Carnarvon Basin offshore Western Australia. The shallow reservoir depth, extreme ERD profile, and high tortuosity requirement for the wells posed significant challenges. These were overcome with extensive planning; integrated engineering designs; application of new technology; good-quality, real-time data interpretation; and strong execution support from both rig site and town. Introduction The Wandoo field, in 56 m of water off-shore Western Australia, was discovered in 1991 and subsequently developed and placed on production in 1993. The shallow unconsolidated sandstone reservoir consists of a heavily biodegraded oil column overlain by a gas cap and supported by a strong aquifer drive. Field infrastructure consists of a 15-well-slot manned production facility, Wandoo B, and a five-slot monopod, Wandoo A, which is tied back to Wandoo B by subsea in-field pipelines. In late 2018, the operator planned and executed a two-well drilling campaign consisting of two complex, ultra-ERD wells, Wandoo B15 and B16. Both wells were planned to be batch drilled for the top hole and intermediate hole sections, with the production hole sections to be drilled and completed sequentially. The primary objective for the B15 well was to recover unswept oil along the western flank of the field and track the well along the main Wandoo fault to the north to assess the structure and reserves from the northern tip of the field. The B16 well objective was to access unswept reserves through the center and down to the south of the field, essentially twinning the B11ST1 well, another ERD well drilled on an earlier campaign, to its eastern flank. To maximize recovery, both wells needed to be placed approximately 1 m below the top of the reservoir, except where overlain by the gas cap, in which case the wells were to be placed approximately 2 m below the gas/oil contact to avoid gas coning. Drilling Challenges and Solutions The first half of the complete paper presents a detailed discussion of the drilling challenges and solutions, illustrated with schematics, maps, charts, and graphs. Both Wells B15 and B16 were classified as ultra-ERD wells because the shallow true vertical depth (TVD) of the reservoir resulted in extreme stepout ratios and required highly complex well paths to access the remaining reserves. The complete paper lists various specific drilling- and systems-related challenges.
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TUDORACHE, VALENTIN-PAUL, LAZAR AVRAM, and NICULAE-NAPOLEON ANTONESCU. "Aspects on offshore drilling process in deep and very deep waters." Journal of Engineering Sciences and Innovation 5, no. 12 (June 3, 2020): 157–72. http://dx.doi.org/10.56958/jesi.2020.5.2.7.

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"Offshore is a broad concept and therefore in this article offshore refers to drilling wells of oil and gas in the hydrocarbons deposits located deep from the seabed. Oil and gas is drilled wells with help of different offshore structures, for example rigs and vessels. Offshore drilling is a complex process where a borehole is drilled through the seabed. Of course, offshore refers to energy activity located at a distance from the shore. Oil and natural gas is located below the bedrock, which makes it difficult to extract them. A limited amount of inland oil has driven oil industry to the seas to find more oil deposits. There are high financial markets in the offshore industry and that is why much money is being invested in new offshore structures all around the world. Offshore structures are constructed for many different purposes worldwide. The structures are expensive to construct but there is an opportunity to have significant financial profit. "
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Romanov, S. F. "Analysis of functionality requirements for digital assistant software of Arctic offshore drilling platforms." Transactions of the Krylov State Research Centre S-I, no. 2 (December 21, 2021): 66–69. http://dx.doi.org/10.24937/2542-2324-2021-2-s-i-66-69.

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This paper describes the study intended to work out functionality requirements of a digital assistant software for Arctic offshore drilling platforms. The study followed the method of logical analysis. The criteria used to formulate key requirements to the software functionality were based on the interview with competent experts working at marine drilling platforms and chosen as per their respective work experience in offshore drilling. Arctic developments have become especially relevant in the last years because oil and gas reserves of the Eastern Siberia and mainland fields in the Russian North are depleting, so it becomes necessary to go for offshore oil and gas in the Arctic. The progress in digital technologies is one of the ways to make Arctic oil & gas production more efficient and safe, which is especially relevant taking into account its harsh environments. Development and induction of personalized tools could improve both occupational and personal discipline of the staff manning offshore platforms, as well as optimize working hours and mitigate industrial injuries.
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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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Dissertations / Theses on the topic "Offshore oil well drilling"

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Acheampong, Theophilus. "Essays on North Sea oil and gas economics : offshore safety economics and third party access to infrastructure in the upstream oil and gas industry." Thesis, University of Aberdeen, 2017. http://digitool.abdn.ac.uk:80/webclient/DeliveryManager?pid=232397.

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This thesis explores two themes on upstream oil and gas economics centred on offshore safety economics and third party access to infrastructure in the United Kingdom Continental Shelf (UKCS). The first part involves work that explores the nexus between the offshore safety regime and safety outcomes. It contributes to the literature by explaining the post-Piper Alpha safety regime changes with regard to our understanding, framing of safety decision making and benchmarking of safety outcomes. The second part investigates third party access to infrastructure issues in the UKCS. It contributes to our understanding of how different third party access to infrastructure arrangements can be utilised to maximise economic recovery. Each chapter addresses fundamental issues of North Sea oil and gas operations through the application of microeconomic, operations research and econometric methods within a formal analytical framework. The results provide insights into decision-making complexities in the upstream oil and gas industry by guiding policy makers. Specifically, part one of this thesis looks at safety performance in the post-Piper Alpha era in the UKCS. It investigates ways through which a more comprehensive and theoretically informed framework can be used to understand the linkages that arise when dealing with safety regulations and their impacts on the offshore oil and gas industry. Our objective is to empirically ascertain the determinants of offshore hydrocarbon releases within the context of the post-Piper Alpha offshore safety regime regulations. This is done using an observed number of hydrocarbon releases linked to a population denominator data of the number of the installations present in the UKCS. Three research problems are examined: (1) the transmission mechanisms through which safety regulation influence firm and industry productivity; (2) the assessment methods utilised in measuring and benchmarking regulatory outcomes in terms of safety compliance; and (3) the extent to which safety policies contribute to enhancing safety levels in the oil and gas industry. We initially review the background and literature on offshore safety with a particular emphasis on the UKCS in Chapter 2. We also frame our research questions and underlying hypothesis here. In Chapter 3, we present our underlying empirical framework and model specifications followed by some descriptive analysis of the hydrocarbon releases data. The results of the various econometric model specifications are analysed in Chapter 4. The second part of the thesis explores how possible different ownership patterns (including access arrangements) might affect the economic viability of exploiting remaining resources in the UKCS. This section attempts to answer two critical questions namely how the impact of the separation of infrastructure and field ownership affect economic recovery and the impact of taxation on field and hub economics in a mature oil basin. We explore how possible different ownership structures and access arrangements might affect the economic viability of remaining UKCS reserves. We apply a mixed integer programming (MIP) model to field data from the Northern North Sea. Specifically, we examine how the unbundling of infrastructure and field ownership, as well as different cost sharing and tariff arrangements, affect the long-term economics of hubs and their user fields. Regarding the layout, Chapter 5 talks about access to infrastructure issues in the UKCS namely the regulatory framework for access and related legislation. It leads to the development of a conceptual framework and model based upon which extractions are made to capture the various potential market outcomes. In Chapter 6, the empirical model, which utilises the mixed integer programming approach, is discussed. The data sources and characterization, as well as the presentation of the results from the Baseline Model, are presented in Chapter 7. The analysis of the Tax Model and the Cost Sharing plus Tax Model including structure and simulated results with underlying assumptions are presented in Chapter 8. Finally, Chapter 9 leads to a thorough discussion of the results followed by conclusions and policy recommendations.
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Martinovich, Tony. "Factors influencing the incidence rates of injuries and accidents among seafarers and rig workers providing support to the WA offshore oil and gas industry." Thesis, Edith Cowan University, Research Online, Perth, Western Australia, 2013. https://ro.ecu.edu.au/theses/1084.

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The aim of this study was to identify, discuss and make recommendations regarding causal factors associated with injuries and accidents among seafarers and rig workers providing support to the WA offshore oil and gas industry. These incidents cause significant personal and economic burdens for employees, employers and the community in general. A sample of 484 participants were recruited from a workforce of 9800 employees (approximately 5%). Participants were stratified into 2 cohorts; those who had suffered injury (286 – study group) and those who had not (198 - controls). Data from the study group were stratified into oilrig workers and vessel seafarers. A one-way analysis of variance revealed that the injury incidence rate for the seafarers in the study group was significantly higher (mean 14.4 injuries) in the first quarter of each multi week work period ( "swing") (P=0.001), compared to means of 4.125 and 2.44 and 4 for the subsequent quarters. For the oil rig workers, the mean injury incidence rates across the four quarters remained similar. It was recommended that a safety officer be assigned to each vessel to support workers for the 1st quarter of each swing. Implementation of this practice has been trialled in another study leading to a reduction in the number of incidents over a 12 month period (Brown, 2009). Other factors that influenced injury incidence rates were age and level of experience, with younger and less experienced workers being more injury prone. Encouraging older, experienced workers to mentor younger employees and to manage their workload according to their physical capabilities will be a useful intervention. The implementation of these recommendations will reduce the injury incidence rate of this unique cohort of employees thus reducing the economic burden of injuries and accidents to the employee, the employer and the community in general.
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McMahon, James S. "DYNAMO systems model of the roll-response of semisubmersibles." Master's thesis, This resource online, 1991. http://scholar.lib.vt.edu/theses/available/etd-01262010-020130/.

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Silva, Luciano da. "Análise modal e controle de plataformas offshore sujeitas a perturbações persistentes." Pós-Graduação em Engenharia Elétrica, 2014. https://ri.ufs.br/handle/riufs/5020.

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A exploração offshore tem crescido muito nos últimos anos e grandes estruturas e equipamentos têm sido projetados e construídos para remover o óleo que se encontra abaixo da superfície do mar. Para plataformas offshore fixas tipo jaqueta é necessário analisar os problemas decorrentes da exposição dessas instalações ao ambiente hostil do oceano. Estas perturbações induzem vibrações excessivas nas estruturas, afetando o conforto e a estabilidade da instalação, e para combater essas vibrações uma ferramenta matemática foi utilizada para monitorar o estado da integridade da estrutura, a Transformada de Hilbert-Huang (HHT). O HHT foi utilizada com sucesso para a identificação de parâmetros modais, como frequência fundamental e fator de amortecimento da plataforma. Finalmente, uma técnica de controle de vibração ativa baseada no Controle Linear Quadrático (LQ) é implementada com o objetivo de reduzir os efeitos de perturbações oscilatórias indesejáveis causados por ondas e correntes marinhas.
The offshore exploration has grown tremendously in recent years, and large structures and equipment has been designed and built to remove the oil that lies beneath the sea surface. For fixed jacket type offshore platforms is necessary to consider the problems arising from exposure of these facilities to the hostile ocean environment. These perturbations induce excessive vibrations in the structures affecting the comfort and stability of the facility, and for to combat these vibrations a mathematical tool was used to monitor the integrity health of the structure, namely the Hilbert-Huang Transform (HHT). The HHT was used for the successfully identification of modal parameters, as fundamental frequency and damping factor of the platform. Finally, an active vibration control technique based on the Control Linear Quadratic (LQ) is implemented aiming to reduce the effects of undesirable oscillatory perturbations caused by waves and marine current.
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Chipindu, Njalo Socrates Chipongue. "Pos-analise em problemas de perfuração de poços maritimos de desenvolvimento." [s.n.], 2010. http://repositorio.unicamp.br/jspui/handle/REPOSIP/263688.

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Orientadores: Celso Kazuyuki Morooka, Jose Ricardo Pelaquim Mendes, Kazuo Miura
Dissertação (mestrado) - Universidade Estadual de Campinas, Faculdade de Engenharia Mecânica, Instituto de Geociências
Made available in DSpace on 2018-08-15T22:58:32Z (GMT). No. of bitstreams: 1 Chipindu_NjaloSocratesChipongue_M.pdf: 4694196 bytes, checksum: 6b99e27328776d4bdf9d03833efef6f0 (MD5) Previous issue date: 2010
Resumo: Os problemas na perfuração de poços de petróleo são responsáveis pela maior parte dos tempos não produtivos, elevando assim os custos diários das operações. Portanto, o estudo e o entendimento destes problemas contribuirá para a otimização da perfuração, melhorando assim as práticas ou mitigando os efeitos severos das anormalidades. O presente trabalho apresenta três procedimentos para identificação das causas dos problemas que poderão auxiliar o jovem profissional a caracterizar os mais variados problemas que ocorrem durante a perfuração de um poço. Neste escopo são abordadas apenas as ocorrências pré-classificadas como dificuldade de manobra, dificuldade de avanço, e prisão. O estudo usa dados dos boletins diários de perfuração dos poços, dados de mudlogging, dados obtidos por ferramentas de monitoramento contínuo da perfuração e outros dados como o fluido utilizado, a configuração da composição de fundo, o desgaste de broca, o gráfico do caliper, litologia e trajetória do poço. A caracterização dos problemas é feita mediante a identificação e associação de eventos que levam a formular hipóteses das prováveis causas dos problemas. Dois grupos de pesquisa (Unicamp e Genesis do Brasil) em engenharia de poço implementaram separadamente os procedimentos propostos. Os resultados foram coincidentes para a maioria trechos de poços marítimos de desenvolvimento analisados, o que atesta a eficácia dos procedimentos diagnósticos. Este estudo é importante para indústria, pois pode maximizar a eficiência na perfuração, através da minimização e/ou eliminação dos tempos não produtivos, responsáveis por avultadas perdas econômicas, além de permitir tornar mais robustas as ferramentas de acompanhamento, em tempo real, das operações de perfuração, na tomada de decisões e na melhoria do processo de planejamento de poço
Abstract: Drilling problems are accountable for the majority of the non productive times in the industry raising the daily operations costs. Therefore, the study and understanding of the problems will contribute to the drilling optimization, improving the practices or by mitigating their severe effects. The present work presents three procedures for identification of causes of drilling problems which can help the young professionals to characterize a wide range of problems that occur while drilling an oil well. In this scope they are studied only the problems pre-classified by occurrence as: problems in tripping, problem in drilling ahead and stuck pipe. The study uses data from the daily drilling reports, mudlogging data, on time monitoring tools data and mud data, Bottom Hole Assembly composition, bit wear report, caliper data, litology and well trajectory. The characterization of the problems is made by identification and association of the events that lead to formulate the hypotheses of the probable causes of the problems. Two research groups (Unicamp and Genesis do Brasil) in well engineering implemented separately the three proposed procedures. The results were coincident for the majority of the analyzed intervals of offshore development wells, demonstrating the efficacy of the proposed procedures. This work is important to the industry since it leads to the drilling efficiency maximization by minimization and/or elimination non productive times that are the main responsible for economic losses, beside the fact that these findings can be used to boost the capacity of the monitoring and logging tools as well as to support the on time decision making and to improve well planning process
Mestrado
Explotação
Mestre em Ciências e Engenharia de Petróleo
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Wang, Hong. "Near wellbore stress analysis for wellbore strengthening." Laramie, Wyo. : University of Wyoming, 2007. http://proquest.umi.com/pqdweb?did=1338926861&sid=1&Fmt=2&clientId=18949&RQT=309&VName=PQD.

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ABDU, JOAO PAULO SANSEVERINO. "SAFETY ASPECTS IN OFFSHORE OIL DRILLING WITH THE FLOATING MUD CAP DRILLING TECHNIQUE." PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIRO, 2018. http://www.maxwell.vrac.puc-rio.br/Busca_etds.php?strSecao=resultado&nrSeq=36079@1.

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Frente às dificuldades de perfurar poços em reservatórios caracterizados por carbonatos fraturados e depletados, com frequente ocorrência de massivas perdas de fluido para formação e impossibilidade de manter o retorno de fluido para superfície, foi desenvolvida a técnica FMCD- Floating Mud Cap Drilling. A técnica consiste na perfuração com bombeio contínuo de fluido pela coluna de perfuração e também pelo anular do poço, injetando todo fluido e formação cortada pela broca para o reservatório. Na técnica convencional de perfuração, o fluido é bombeado pela coluna e retorna pelo anular, sendo possível monitorar continuamente a ocorrência de kicks - influxos acidentais de hidrocarbonetos no poço No entanto, na técnica FMCD, devido à ausência de retorno de fluido no anular, torna-se necessário adotar métodos não convencionais de monitoramento e prevenção de kicks, sendo o principal método, a injeção continua de fluido pelo anular, a uma vazão determinada, que evite influxos do reservatório e migração de hidrocarbonetos para superfície, denominada vazão de segurança. Inicialmente é apresentada uma contextualização da perfuração de poços offshore com técnica convencional e técnica FMCD, associada a uma ampla revisão bibliográfica sobre a técnica, e também de modelos e experimentos de fluxo óleo-água. Por fim, como objetivo principal da dissertação, é realizado a discussão de premissas, análise da vazão de segurança e métodos de monitoramento de influxos. Contudo, é esperado que a revisão bibliográfica e análises desenvolvidas, auxiliem em futuros projetos de perfuração com a técnica FMCD- Floating Mud Cap. Drilling.
With the oil carbonate reservoirs exploration and exploitation around the world and the Brazilian coast, new challenges for well drilling are found which requires new techniques to be developed. The carbonate reservoirs can present fractures with high conductivity along its structure, often accompanied by geological faults. When associate with scenarios where the reservoirs are depleted, due to the ongoing production of these oil fields, may lead to fluid severe losses into the formation during the news well construction. For decades, in case of total loss at offshore wells drilling, the proposed solution has been to pump sealing material into the formation and, persisting the losses, to end it with a cement plug in open hole and make another attempt to drill the interval. When these procedures were not effective, the wells were often abandoned. On one side, it should be emphasized, that pumping sealant material and cement into the producing reservoir is undesirable, due to the possibility of damaging the intervals of greater permeability and production potential which may bring reduction in productivity (or injectivity) of the well. On the other side, continuing the drilling with fluid total loss may be intolerable from the operational safety point of view, as it is not possible to use conventional kick detection methods, that are mainly based on drilling fluid mass control. Facing these difficulties of drilling wells in reservoirs characterized by fractured and depleted carbonates, the FMCD (Floating Mud Cap Drilling) technique was developed. The technique consists of drilling with continuous pumping of fluid both through the drilling column and the well annulus, injecting all fluid and formation cuts into the reservoir.
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CHIEZA, CAROLINA PONTES. "DIAGNOSTICS OF OPERATIONAL PROBLEMS DURING OIL WELL DRILLING." PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIRO, 2011. http://www.maxwell.vrac.puc-rio.br/Busca_etds.php?strSecao=resultado&nrSeq=19161@1.

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COORDENAÇÃO DE APERFEIÇOAMENTO DO PESSOAL DE ENSINO SUPERIOR
A perfuração de poços de petróleo é uma operação complexa e de elevado risco e custo financeiro. Com o passar dos anos o número de poços horizontais e de longo alcance perfurados aumentou consideravelmente devido à existência de reservatórios mais profundos e de difícil acesso, além da necessidade de se obter uma melhor eficiência na extração do petróleo. Juntamente com este aumento na complexidade da perfuração surgiram problemas operacionais que, por muitas vezes, não são identificados e acabam sendo responsáveis pela maior parte do tempo não produtivo da operação elevando, assim, seus custos diários. Logo, o estudo destes problemas é de extrema importância para se garantir condições seguras de operação, além de contribuir para a otimização da mesma, mitigação dos efeitos causados e uma maior rapidez e eficácia nas tomadas de decisões. O presente trabalho apresenta uma metodologia de identificação de problemas operacionais a fim de otimizar a perfuração de poços, através da utilização de recursos computacionais, para gerar análises de previsão de torque, arraste e hidráulica e, posterior, comparação com os dados de perfuração obtidos, em tempo real, dos sensores de mudlogging e da ferramenta de PWD. A caracterização dos problemas foi realizada com base nos dados reais de poços horizontais, perfurados na Bacia de Campos, mediante a identificação de possíveis desvios importantes, que não estavam previstos, nos parâmetros de perfuração. Através da retro-análise dos dados de perfuração dos poços foi possível diagnosticar alguns problemas operacionais ocorridos durante esta operação, tais como: perda de circulação, prisão da coluna de perfuração, washout no tubo de perfuração e dificuldade de avanço causada por uma limpeza deficiente, pelo enceramento da broca e pela vibração na coluna de perfuração. Além disso, foram destacados também alguns exemplos que mostraram variações na tendência do torque em função de mudança na litologia do poço.
Drilling is a complex and a high risk process which involves high financial cost. Over the years the number of horizontal wells and extended reach wells increased, due to the existence of deeper reservoirs, which are more difficult to access, in addition to the need of having an improvement in the oil production efficiency. Along with this increased complexity of drilling, unidentified operational problems end up being responsible for most of the non-productive time and daily cost increase. Thus, analyzing such problems it is very important to ensure safe operating conditions, optimize drilling operation, control causes/effects and have a faster and efficient decision-making capability. This paper presents a methodology to identify operational problems in order to optimize drilling operation using computer resources to predict torque, drag and hydraulic effects and later on to compare with the drilling data obtained in real time from mudlogging sensors and PWD (Pressure While Drilling). Cases were based on real time data from horizontal wells drilled in Campos Basis, Rio de Janeiro, and the problems were identified with unforeseen changes in drilling parameters trend. After studying the available well data, it was possible to diagnose several operational problems occurred during drilling, such as: lost circulation, stuck pipe, drill pipe washout and difficulty in drilling due to a poor hole cleaning, bit balling and drill string stick-slip vibration. In addition, it was also highlighted some examples that showed variations in the torque trend due to lithology changes.
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PICARD, NICOLAS. "DEVELOPMENT OF NOVEL HYDRAULICS FOR OIL WELL DRILLING." University of Cincinnati / OhioLINK, 2002. http://rave.ohiolink.edu/etdc/view?acc_num=ucin1025637714.

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Ozkan, Erdal. "Performance of horizontal wells /." Access abstract and link to full text, 1988. http://0-wwwlib.umi.com.library.utulsa.edu/dissertations/fullcit/8825498.

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Books on the topic "Offshore oil well drilling"

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Haerens, Margaret. Offshore drilling. Detroit: Greenhaven Press, 2010.

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Mooney, Carla. Oil spills and offshore drilling. San Diego, CA: ReferencePoint Press, 2011.

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Gaines, Alison. The pros and cons of offshore drilling. New York: Cavendish Square Publishing, 2016.

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Contreras, David A. Offshore oil and gas development in the U.S. Hauppauge, N.Y: Nova Science Publishers, 2011.

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Publications, Hart, ed. Offshore turnkey drilling: Best practices. Houston: Hart Publications, 1997.

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Mooney, Carla. Oil spills and offshore drilling. San Diego, CA: ReferencePoint Press, 2011.

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Dareing, Don W. Mechanics of drillstrings and marine risers. New York, NY: ASME Press, 2012.

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Ruggeri, Julia. Life offshore. 2nd ed. Austin: Petroleum Extension Service, University of Texas at Austin, in cooperation with International Association of Drilling Contractors, Houston, Texas, 2008.

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Fee, Derek. Technology for developing marginal offshore oilfields. London: Elsevier Applied Science, 1986.

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(Organization), BPMIGAS. Laporan pelaksanaan RKL dan RPL COOC SES Ltd. Jakarta: BPMIGAS, 2007.

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Book chapters on the topic "Offshore oil well drilling"

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Yang, Jin. "Drilling-In Installation of Oil-Gas Well Conductor." In Installation Methods of Offshore Oil-Gas Well Conductor, 29–65. Singapore: Springer Nature Singapore, 2022. http://dx.doi.org/10.1007/978-981-19-5685-0_2.

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Kaufman, David, Katta G. Murty, and Ahmed AlSaati. "Clustering Problems in Offshore Drilling of Crude Oil Wells." In International Series in Operations Research & Management Science, 29–42. Cham: Springer International Publishing, 2020. http://dx.doi.org/10.1007/978-3-030-40212-9_4.

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Laik, Sukumar. "Offshore Well Completion." In Offshore Petroleum Drilling and Production, 337–92. Boca Raton : Taylor & Francis, a CRC title, part of the Taylor & Francis imprint, a member of the Taylor & Francis Group, the academic division of T&F Informa, plc, [2018]: CRC Press, 2018. http://dx.doi.org/10.1201/9781315157177-5.

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Sotoodeh, Karan. "Drilling and Well Completion Equipment." In Equipment and Components in the Oil and Gas Industry Volume 1, 29–65. Boca Raton: CRC Press, 2024. http://dx.doi.org/10.1201/9781003467151-2.

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Yang, Jin. "Piling Installation of Oil-Gas Well Conductor." In Installation Methods of Offshore Oil-Gas Well Conductor, 67–105. Singapore: Springer Nature Singapore, 2022. http://dx.doi.org/10.1007/978-981-19-5685-0_3.

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Yang, Jin. "Adaptability of Installation Method of Offshore Conductors." In Installation Methods of Offshore Oil-Gas Well Conductor, 163–67. Singapore: Springer Nature Singapore, 2022. http://dx.doi.org/10.1007/978-981-19-5685-0_5.

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Yang, Jin. "Jetting Installation Method of Oil-Gas Well Conductor." In Installation Methods of Offshore Oil-Gas Well Conductor, 107–62. Singapore: Springer Nature Singapore, 2022. http://dx.doi.org/10.1007/978-981-19-5685-0_4.

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Skalle, Pål, and Agnar Aamodt. "Knowledge-Based Decision Support in Oil Well Drilling." In Intelligent Information Processing II, 443–55. Boston, MA: Springer US, 2005. http://dx.doi.org/10.1007/0-387-23152-8_56.

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Yang, Jin. "Functions of the Oil-Gas Well Conductor and Wellhead Structure." In Installation Methods of Offshore Oil-Gas Well Conductor, 1–27. Singapore: Springer Nature Singapore, 2022. http://dx.doi.org/10.1007/978-981-19-5685-0_1.

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Amadi-Echendu, Joe, and Audu Enoch Yakubu. "Asset Operations: Non-productive Times During Oil Well Drilling." In Lecture Notes in Mechanical Engineering, 43–48. Cham: Springer International Publishing, 2014. http://dx.doi.org/10.1007/978-3-319-06966-1_4.

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Conference papers on the topic "Offshore oil well drilling"

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Shah, Prerak Hitesh, Harsh Tusharbhai Pandya, Harsh Sharma, and Arpit Saxena. "Offshore Drilling & Well Testing of a HPHT Gas Well: A Case Study." In SPE Oil and Gas India Conference and Exhibition. Society of Petroleum Engineers, 2012. http://dx.doi.org/10.2118/155320-ms.

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Tanjung, Erwindo, R. Saridjo, Stan M. Provance, Pat Brown, and Tim O'Rourke. "Application of Multilateral Technology in Drilling an Offshore Well, Indonesia." In SPE Asia Pacific Oil and Gas Conference and Exhibition. Society of Petroleum Engineers, 2002. http://dx.doi.org/10.2118/77829-ms.

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Kernche, Frank, D. Hannegan, E. Sammat, and Maurizio Antonio Arnone. "Managed Pressure Drilling Enables Drilling Beyond the Conventional Limit on an HP/HT Deepwater Well." In SPE Offshore Europe Oil and Gas Conference and Exhibition. Society of Petroleum Engineers, 2011. http://dx.doi.org/10.2118/142312-ms.

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Gowida, Ahmed, and Salaheldin Elkatatny. "Exploring the Potential of Laser Technology in Oil Well Drilling: Recent Advances and Future Recommendations." In Offshore Technology Conference. OTC, 2024. http://dx.doi.org/10.4043/35066-ms.

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Abstract Conventional rotary drilling techniques employed in crude oil and natural gas extraction present notable challenges and financial burdens. To mitigate these obstacles and minimize drilling expenditures, oil enterprises are investigating innovative cost-saving approaches. Laser technology has emerged as a non-invasive alternative to traditional methods, garnering attention within the oil and gas sector. This study assesses the feasibility of laser drilling as a promising departure from rotary drilling practices. The research undertakes a comprehensive examination of global studies on the utilization of lasers in oil and gas well drilling, providing insights into the technology's potential and offering recommendations for its practical integration in the oilfield. Extensive lab-scale experiments have showcased the proficiency of contemporary laser models in spalling, melting, and vaporizing various rock formations, ranging from Berea sandstone to highly resilient granite and basalt. Analyzing the rate of penetration against the required specific energy under diverse conditions facilitates an assessment of the technique's efficacy. Experimental findings indicate that fluid saturation within drilled rock does not impede the drillability rate. Advantages over conventional methods include heightened penetration rates, reduced tripping, casing, and bit costs, improved well management, and enhanced side-tracking capabilities. Consequently, laser technology promises to facilitate sustainable field operations, offering manifold benefits in operational efficiency, cost reduction, and environmental preservation. Nevertheless, technological challenges such as borehole cleaning, well control, beam downhole delivery, and complex formation conditions necessitate further exploration. The development of laser-assisted drill bits and downhole laser drilling machinery holds promise with advancing laser technology and sustained research into the technique's viability from both technical and economic standpoints. Crucial technical recommendations for laser drilling technology in the oil and gas industry encompass conducting feasibility studies, investing in research and development, validating technology through field trials, prioritizing safety and environmental concerns, performing cost analyses, instituting training programs, ensuring regulatory compliance, fostering collaboration and knowledge exchange, and continuously monitoring and enhancing performance. Adhering to these recommendations enables the industry to optimize drilling efficiency, curtail costs, and champion environmental stewardship, thereby advancing sustainable practices in oil and gas exploration.
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Moroni, Luigi, Kamil Fatkullin, and Bao Tran Thanh. "Evolution of a Versatile HTHP Water-Based Drilling Fluid Improved Drilling Efficiency Offshore Vietnam." In SPE/IATMI Asia Pacific Oil & Gas Conference and Exhibition. SPE, 2023. http://dx.doi.org/10.2118/215251-ms.

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Abstract The fast pace of exploration and production level increase over recent years has led operators to expand the horizon for exploration of hydrocarbons in more complex and exigent reservoirs which includes the high temperature and pressure (HTHP) reservoirs. Typically wells in the North of Vietnam have been drilled using a Non-Aqueous Drilling Fluid (NAF) for their lower and reservoir intervals. The challenges of multi-string design, potential of acid gas contamination, well bore stability, down hole losses and a high temperature environment require a well-engineered NAF to meet the overall well objectives. Alternatively, Water-Based Fluid (WBM) has significant environmental benefits compared to NAF. This paper presents the technical development, evolution and lessons learned from using a high performance HTHP WBM over a series of extremely challenging HPHT exploration wells Offshore Vietnam, with temperatures expected to reach 170°C (338°F) and pressures over 12,000 psi. These conditions place severe limitations on the drilling fluid design and can often lead to failures in open-hole wireline logging operations, which is probably the most important objective in an exploration well. To ensure the successful drilling, wireline logging and completion operations under the thermal conditions, the development of the HPHT WBM for these exploration wells needs to address the HTHP filtration control properties, filter cake quality, inhibition and the thermal stability of the drilling fluid. Extensive laboratory testing was performed to optimize the rheological properties for mud weights up to 18.7 ppg to ensure minimal sag tendency after static condition, while also providing excellent filter cake quality, system inhibition and hole condition to allow the well to be fully logged and evaluated. The enhancements made in the HPHT WBM design led to an improved drilling performance in drilling these challenging exploration wells. Inhibition of the reactive formations was improved with each well drilled, as was the rate of penetration and wellbore stability. Extensive logging was performed with the wellbore remaining in excellent condition throughout the long open-hole time.
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Pilko, Robert M., Nicole Rita Hart-Wagoner, Andrew J. Van Horn, and Joseph A. Scherer. "Repurposing Oil & Gas Wells and Drilling Operations for Geothermal Energy Production." In Offshore Technology Conference. OTC, 2021. http://dx.doi.org/10.4043/31090-ms.

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Abstract This paper explores a market solution for Operators’ companies to compound their investments in wells, fields, and infrastructure in a low carbon world by applying improved well design, drilling and completion technologies that are adapted to a new generation of geothermal energy production systems. The paper frames challenges posed to the upstream industry by the movement to a low carbon economy, including the climate transition risks related to societal, regulatory, and capital allocation trends. It then examines the technical challenges and solutions related to repurposing oil and gas fields and wells for geothermal energy production and makes high-level recommendations for Operators interested in accessing this new market for geothermal energy - as well as satisfying Environmental, Social and Corporate Governance (ESG) investors.
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Sun, Gang, Mohammad Solim Ullah, Yi Li, Mukesh Maheshwari, Thirayu Khumtong, Shao Chun Xiong, Wu Chang Ai, et al. "A Spectacular Cementing Record in Myanmar Offshore Deepwater Well." In IADC/SPE Asia Pacific Drilling Technology Conference. SPE, 2021. http://dx.doi.org/10.2118/201063-ms.

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Abstract Myanmar offshore is considered to be a very promising exploration and production (E&P) location for oil and gas but poses significant challenges to drilling and cementing operations. Low temperature at sea bed delays the cement compressive strength development, High pore pressure with steep gradient and low fracture pressure created a very narrow drilling margin, presence of shallow flow in riser-less section further complicated the cementing operation, low density cement with high performance is a must. With the exorbiant cost of Deepwater drilling, much needed fit for purpose cementing technology with efficient logistic support and excellence in execution became crucial. This paper elaborates the cementing challenges at different sections of a recent deep-water well in offshore Mynamar and techniques that were planned and used to address those challenges. This paper will describe in detail the cementing method, how it fit the well situation, how the cement slurry was designed then evaluated and how the logistic support and execution were carried out, resulting in a resounding success.
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Carvalho, B. C., H. R. A. Souza, S. R. Soares, M. A. Fontes, E. J. Gomes, L. S. Marinho, W. F. C. Junior, and M. R. C. M. Calderari. "Life Cycle Assessment of Oil and Gas Drilling Activities." In Offshore Technology Conference. OTC, 2024. http://dx.doi.org/10.4043/35145-ms.

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Abstract A Life Cycle Assessment (LCA) study is presented for the comparative evaluation of environmental performance across different drilling scenarios, in the context of offshore oil and gas well operations. Particular emphasis is placed on offshore and land pathways for treatment and final disposal of drilling fluids and cuttings. The LCA model was developed in accordance with ISO 14040 and 14044 standards, encompassing distinct life cycle stages: fluids manufacturing, inbound logistics, drilling operations, outbound logistics, and end-of-life treatment and disposal. Six scenarios, involving diverse combinations of water-based (WBDF) and non-aqueous (NADF) drilling fluids, and three end-of-life alternatives—offshore disposal, industrial landfill, and incineration—were systematically assessed and compared. The Life Cycle Impact Assessment (LCIA) method employed was ReCiPe (H) Midpoint 2016, and the considered impact categories were climate change, particulate matter formation, freshwater eutrophication, marine eutrophication, freshwater ecotoxicity, and marine ecotoxicity. Among the lifecycle processes, logistic operations were found to have the lowest environmental impacts across all categories. The drilling phase exhibited significant influence, particularly in climate change and particulate matter formation. The fluid formulation phase, specifically in scenarios involving WBDF, prominently affected both freshwater eutrophication, marine eutrophication, and freshwater ecotoxicity. Marine ecotoxicity was mostly influenced by the end-of-life stage in scenarios involving offshore disposal. For five of the six impact categories, the scenario with the best overall environmental performance was drilling with NADF and offshore cuttings disposal, due to the greater performance of this type of fluid in drilling processes and the reduction in environmental impacts associated with avoiding onshore treatment and final disposal. Conversely, the discharge of cuttings into the sea had a pronounced impact on the marine ecotoxicity category due to the potential toxicity of substances such as copper, barium, and zinc. Among terrestrial treatment options, scenarios involving incineration were consistently more environmentally impactful across all impact categories. The findings of this LCA study offer a robust technical-scientific foundation, facilitating informed discussions and aiding decision-making processes regarding the environmental impacts of oil well drilling operations. This pertains particularly to the choice of drilling fluids and the management of drilling waste within this industry sector.
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Oyeneyin, Mufutau B. "Cost Effective Deepwater Well Construction—A Case for Managed Pressure Drilling With Casing." In SPE Offshore Europe Oil and Gas Conference and Exhibition. Society of Petroleum Engineers, 2009. http://dx.doi.org/10.2118/123789-ms.

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Zhang, Xiaocheng, Tao Xie, Hongbo Huo, Ruibing He, Hai Lin, Xinxin Hou, and Dongsheng Xu. "Maximizing Recovery and Reducing Well Cost Using Herringbone Multilateral Horizontal Well Drilling and Completion Technology." In Gas & Oil Technology Showcase and Conference. SPE, 2023. http://dx.doi.org/10.2118/214019-ms.

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Abstract With the in-depth development of Bohai Oilfield, China National Offshore Oil Corporation (CNOOC), the water cut of some old wells become too high to produce while nearby remaining recoverable reserves are still considerable. In order to maximize recovery and reduce well construction cost, herringbone multilateral horizontal well drilling and completion technology is employed to increase drainage area of single well and make full use of well slot and old wellbore. Considering the current development of oilfield and the geological characteristics of reservoir, the technical difficulties of herringbone multilateral horizontal well drilling and completion technology including high build-up rate, easy blockage of drilling tools in the sidetracking in open hole, easy collapse and instability of sandwich wall and high requirements for drilling fluid performance are analyzed and solved. This technology has been successfully applied in three wells with total 6 branches and the production of three wells is twice higher than that of conventional horizontal wells with no water cut, which fully verified the reliability of the branch well tools and the feasibility of the technology. Herringbone multilateral horizontal well drilling and completion technology provides a new idea for the treatment of low production and low efficiency wells in a sustainable way and will be widely promoted and applied in Bohai oilfield, which can also provide reference for other high water cut oilfields.
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Reports on the topic "Offshore oil well drilling"

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Bingham-Koslowski, N., T. McCartney, J. Bojesen-Koefoed, and C. Jauer. Hydrocarbon resource potential in the Labrador-Baffin Seaway and onshore West Greenland. Natural Resources Canada/CMSS/Information Management, 2022. http://dx.doi.org/10.4095/321859.

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Exploration for hydrocarbons began in the Labrador-Baffin Seaway in the 1960s; activity along the Labrador margin is still ongoing. A moratorium on exploration activities in the Canadian Arctic was enacted in 2016, halting drilling and data acquisition in western Davis Strait and along the Baffin Island margin. The exploration for hydrocarbons along the West Greenland margin ceased in 2021. Despite the presence of all hydrocarbon system elements as well as direct indicators of at least one working hydrocarbon system (e.g. slicks and/or seeps, oil and/or gas shows), no commercially viable accumulations of hydrocarbons have been discovered in the region. Potential sea-surface hydrocarbon slicks have been identified throughout the study region using synthetic aperture radar, but only the slick offshore Scott Inlet (Nunavut) has been directly linked to seafloor hydrocarbon seepage.
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Skone, Timothy J. Oil well drilling and development. Office of Scientific and Technical Information (OSTI), July 2013. http://dx.doi.org/10.2172/1509427.

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Aldy, Joseph. The Labor Market Impacts of the 2010 Deepwater Horizon Oil Spill and Offshore Oil Drilling Moratorium. Cambridge, MA: National Bureau of Economic Research, August 2014. http://dx.doi.org/10.3386/w20409.

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Rougeot, J. E., and K. A. Lauterbach. The drilling of a horizontal well in a mature oil field. Office of Scientific and Technical Information (OSTI), January 1991. http://dx.doi.org/10.2172/6220198.

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Fowler, M. G., M. Obermajer, S. Achal, and M. Milovic. Results of geochemical analyses of an oil sample from Mizzen L-11 well, Flemish Pass, offshore eastern Canada. Natural Resources Canada/ESS/Scientific and Technical Publishing Services, 2007. http://dx.doi.org/10.4095/223887.

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Edward Marks. Use of Biostratigraphy to Increase Production, Reduce Operating Costs and Risks and Reduce Environmental Concerns in Oil Well Drilling. Office of Scientific and Technical Information (OSTI), September 2005. http://dx.doi.org/10.2172/921974.

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Allison. L51510 Field Observations of Two-Phase Flow in the Matagorda Offshore Pipeline System. Chantilly, Virginia: Pipeline Research Council International, Inc. (PRCI), May 1986. http://dx.doi.org/10.55274/r0010071.

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Offshore gas production typically involves the simultaneous flow of oil and/or condensate. The oil may he entrained in the gas rising in the vertical well from the sea-bed or may flow under its own pressure gradient; condensate may result from the reduction of pressure from well conditions to pipeline transport pressure and from cooling sea temperatures. It would be unduly expensive to build a gas-liquid separation facility on a production platform, followed by two separate pipeline transport systems for the two phases. It is therefore desirable to examine pipeline systems that carry hydrocarbon liquid and gas together. Two-phase flow of oil and gas under steady-state operation of the Matagorda Offshore Pipeline System was observed by nuclear densitometry at two onshore sites. Oil flowed into the pipeline system at an average rate of 1.6 Bbl/ MMSCF over the two-month data acquisition period; gas flow was constant at about 200 MMSCF per day.
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Coombs, Steven F. Feasibility of Optimizing Recovery & Reserves from a Mature & Geological Complex Multiple Turbidite Offshore Calif. Reservoir through the Drilling & Completion of a Trilateral Horizontal Well. Office of Scientific and Technical Information (OSTI), November 1999. http://dx.doi.org/10.2172/14435.

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Coombs, Steven F. Feasibility of Optimizing Recovery & Reserves from a Mature & Geological Complex Multiple Turbidite Offshore Calif. Reservoir through the Drilling & Completion of a Trilateral Horizontal Well. Office of Scientific and Technical Information (OSTI), November 1999. http://dx.doi.org/10.2172/14436.

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Coombs, Steven F. Feasability of Optimizing Recovery and Reserves from a Mature and Geological Complex Multiple Turbidite Offshore California Reservoir Through the Drilling and Completion of a Trilateral Horizontal Well. Office of Scientific and Technical Information (OSTI), October 1996. http://dx.doi.org/10.2172/1466.

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