Relevant bibliographies by topics / Oil well drilling rigs

Contents

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

Academic literature on the topic 'Oil well drilling rigs'

Author: Grafiati
Published: 4 June 2021
Last updated: 26 February 2023

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Journal articles on the topic "Oil well drilling rigs"

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Nae, Ion, Gabriela Cristina Ionescu, and Octavian Narcis Ionescu. "Planning, Monitoring and Controlling Assembling Activities for Oil Well Drilling Rigs." Applied Mechanics and Materials 657 (October 2014): 364–68. http://dx.doi.org/10.4028/www.scientific.net/amm.657.364.

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Lake, B. D., and V. Santostefano. "BASS STRAIT DRILLING - PREPARING FOR THE NINETIES." APPEA Journal 30, no. 1 (1990): 300. http://dx.doi.org/10.1071/aj89019.

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Future development drilling in Bass Strait will be challenged by small field sizes, thin oil columns and increasing drilling difficulty due to greater hole angle and reach. New drilling technology successfully introduced in the recent Bream, Whiting, Perch and Dolphin developments including Steerable Drilling Systems (SDS), Polycrystalline Diamond Compact (PDC) bits and Logging While Drilling (LWD) tools, coupled with the successful use of jackup rigs for miniplatform development, has given Esso the tools and confidence to meet the development challenges of the 'nineties. Bass Strait's first horizontal well has been successfully drilled and completed with further wells planned in the current Bream development. There still remain some areas requiring improvements, including hole cleaning in high angle holes. Improvements in this and other areas will further improve drilling capability.Given the right incentives Bass Strait drilling technology is well positioned for the challenge of oil development in the 'nineties.
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Brown, Alan S. "Storm Warning." Mechanical Engineering 128, no. 06 (June 1, 2006): 24–29. http://dx.doi.org/10.1115/1.2006-jun-1.

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This article focuses on measures for preventing damages to oil drilling setups post hurricanes or typhoons. According to engineers, today, it is a complex network of fixed and floating production platforms, mobile drilling units, undersea wells, and oil and gas pipelines. No single solution will ensure the safety of the entire system. The exploration wells under the drilling rigs are also vulnerable. Mobile drilling units, such as jackups and semisubmersibles, which drill test wells and then move to another location, proved especially vulnerable during Katrina and Rita. When the American Petroleum Institute rolled out its first post-Katrina recommendations in April, it took an initial step on a road that will eventually demand changes in everything from air gaps, tie-downs, and deck design to moorings, tethers, clamps, and piping supports. New standards are expected to improve the odds for newer platforms and rigs if they continue to face larger and larger hurricanes.
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Shepelev, A. A., and M. V. Kosnyreva. "GEOPHYSICAL RESEARCH AS PART OF ENGINEERING SURVEYS ON THE SHELF OF THE OKHOTSK SEA." Bulletin of Dubna International University for Nature, Society, and Man. Series: Natural and engineering sciences, no. 2 (47) (September 14, 2020): 51–59. http://dx.doi.org/10.37005/1818-0744-2020-2-51-59.

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The paper deals with the results of marine engineering surveys on the shelf of the Okhotsk Sea. According to the results of the study, potentially hazardous geological and technogenic objects were localized, and a network of buried river paleo–incisions was identified. The work performed allowed us to obtain materials that ensure the safe installation of floating drilling rigs for the period of well drilling, design and construction of oil and gas field facilities.
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Khonji, Najla Abdulaziz, and Saad M. A. Suliman. "Product Mix Optimization for an Oil Field Operating Company." Modern Applied Science 14, no. 10 (September 24, 2020): 20. http://dx.doi.org/10.5539/mas.v14n10p20.

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In this study, a mathematical model is formulated to select the optimal product mix of wells in terms of numbers and types of wells that helps to maximize profit. The optimization model comprises two main components, the first component is revenue which includes forecasting of production and oil price, and the second component is cost which includes capital and operating costs. In addition, the model considers all related constraints such as budget, production targets, surface facility limitations, drilling rigs availability and others. Time has influence on the model, since its output is not limited only to the types and numbers of wells to be drilled during the planned period, but also when each well to be drilled for the same plan. Actual planning data for three consecutive years is used for model testing. The results show that 42% to 47% cost saving can be achieved by using the model. The analysis shows that with every 10% increase in oil price, the profit increases by about 6%. Also, it shows that the number of rigs and the rig daily cost affect the profit tremendously, where by reducing these two parameters by 50% an increase of 66% in oil profit can be achieved. The study confirms that oil field operating companies can stand a better chance of maximizing their profit by using product mix optimization model to define the optimum schedule for the number of wells, type of wells and time of drilling.
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Vazquez, Jennifer, and Donald Larry Crumbley. "Flared Gas Can Reduce Some Risks in Crypto Mining as Well as Oil and Gas Operations." Risks 10, no. 6 (June 16, 2022): 127. http://dx.doi.org/10.3390/risks10060127.

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There are numerous risks associated with mining and owning cryptocurrencies, and exploring and producing oil and natural gas are highly risky, costly, and controversial. A marriage of digital mining and exploring and producing oil and natural gas has reduced the major risks and costs for both the crypto miner and the petroleum industry. On the one hand, crypto mining requires an enormous amount of electricity, which is not environmentally friendly. On the other hand, when drilling for petroleum resources, natural gas is often discovered, but due to a lack of resources or pipeline availability, a massive amount of natural gas is vented into the atmosphere or burned (called flaring). Today, however, this normally wasted gas (called stranded natural gas) is being used to create cheap electricity for mining server containers stationed near drilling rigs, which are used to create cryptocurrencies. This results in reduced CO2 emissions, lower costs for drillers, and greater royalties going to landowners.
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Leksin, V. K., V. I. Samarin, and P. N. Liskovyi. "RESULTS OF INTERPRETATION OF SEISMIC SECTIONS DURING ENGINEERING SURVEYS WITHIN OF THE SOUTH-KIRINSKOYE OIL AND GAS CONDENSATE FIELD (SHELF OF SAKHALIN ISLAND)." Engineering survey 12, no. 9-10 (April 4, 2019): 64–73. http://dx.doi.org/10.25296/1997-8650-2018-12-9-10-64-73.

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High-resolution 2D seismic is the main and optimal method in marine engineering geophysics, which for many years has worked well for the production of semi-submersible drilling rigs, self-lifting drilling rigs, construction of berthing facilities and bridges. The main objective of this method is to identify near-surface gas, faults, which are geological hazards. The method used for performing marine research is longitudinal profiling of reflected waves with a 48-fold overlap of the reflecting horizons. To obtain high-quality seismic migrated sections, we have previously developed a unified data processing algorithm for the offshore areas of the South-Kirinskoye oil and gas condensate field (Sakhalin shelf). More than 8,000 line km of seismic data were processed. The article presents the sequence of interpretation, as well as an analysis of the presence of hazards in the project wells (objects). To isolate potentially dangerous objects for each horizon, a dynamic analysis was carried out, which included the definition of the following parameters: maximum and minimum peak amplitude. The systematization and classification of amplitude anomalies was carried out according to such features as a phase change, frequency reduction, the presence of a supply channel and distortion (false deflection) of all underlying boundaries, indicating the possible presence of gas. The probable hazard levels for drilling operations were determined. All the identified anomalies in the process of interpreting seismic sections were mapped to the geological hazards to select the optimal and safe installation point for drilling a prospecting or exploration well.
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Utomo, Budi. "PENGEBORAN LEPAS PANTAI." Gema Teknologi 16, no. 3 (February 6, 2012): 113. http://dx.doi.org/10.14710/gt.v16i3.4705.

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Budi Utomo, in this paper explain that offshore drilling carried out to obtain crude oil through the oil wells. The means that must exist in the operation of offshore drilling is a bridge structure (plate form) as a place to put the drilling equipment. Known two kinds of platforms, that is platforms permanent (fixed) which stands on the feet of reinforced concrete, and the bridge is not fixed like swamp barges, drilling ship (floaters) and jack-up rig. Jack up rig is one of the offshore rigs that have the ability to elevation in accordance with a sea depth of drilling. Drilling equipment is a range of equipment that is prepared in such a way, so that such a drill rod, and all this equipment has a hole inside that allows for fluid or mud circulation. Key word: Drilling equipment
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Huang, Lu Meng, Yan Ting Zhang, Lei Zhang, and Mei Ying Liu. "Simulation Study on Drawworks Heave Compensation System of Offshore Oil Drilling." Applied Mechanics and Materials 385-386 (August 2013): 951–55. http://dx.doi.org/10.4028/www.scientific.net/amm.385-386.951.

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In order to improve the efficiency of offshore oil drilling, simplify the structure of drilling rigs, a new type of heave compensaton drawworks is put forward to realize decoupling control of motion and energy saving by hydraulic energy storage. In order to study the compensation performance of drawworks, mathematical simulation model is built, heave compensation displacement controller of fuzzy-PI and bit pressure controller of BP neural network are designed based on the high inertia load and nonlinear time-varying characteristics of the system. The simulation results show that the heave compensation maintains the absolute displacement of the hook within certain premises and reduces the effects on bit pressure by platform heave movement, automatic bit feeding keeps bit pressure steady, the bit pressure is kept in the scope prescribed by work. The research result shows that the device well meets the performance requirements of offshore drilling.
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Rao, T. Kishan, M. Shankar Lingam, Manish Prateek, and E. G. Rajan. "SUBSURFACE IMAGING USING GROUND PENETRATING RADAR FOR UNDERGROUND OIL AND MINERALS EXPLORATION." International Journal of Engineering Science Technologies 4, no. 6 (January 6, 2021): 71–79. http://dx.doi.org/10.29121/ijoest.v4.i6.2020.139.

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A drilling company operates in accordance with a contract which specifies that an oil well will be drilled to a specific depth. The average cost to find and develop an oil and gas property in the United States is $17.01/ barrels-of-oil-equivalent from 2005 to 2007. The cost for onshore development was $13.38/BOE and for offshore development was $49.54/BOE. Based on some statistics one out of five rigs drilled in an area yields oil recovery. This means $20 million has to be spent for prospecting and locating one oil well. The question that arises now is whether it is worth trying all possibilities of reducing the cost of locating an oil well to $4 million and save $16 million. Well, the research presented in this paper is aimed at showing such a possibility.
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Dissertations / Theses on the topic "Oil well drilling rigs"

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Pelley, Dean. "Performance of twin falls davit & lifeboat evacuation system in extreme seas /." Internet access available to MUN users only, 2003. http://collections.mun.ca/u?/theses,169027.

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Alkaragoolee, Mohammed Y. A. "Hybrid Modelling and Optimisation of Oil Well Drillstrings." Thesis, University of Bradford, 2018. http://hdl.handle.net/10454/16859.

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The failure of oil well drillstrings due to torsional and longitudinal stresses caused by stick-slip phenomena during the drilling operation causes great expense to industry. Due to the complicated and harsh drilling environment, modelling of the drillstring becomes an essential requirement in studies. Currently, this is achieved by modelling the drillstring as a torsional lumped model (which ignores the length of the drillstring) for real-time measurement and control. In this thesis, a distributed-lumped model including the effects of drillstring length was developed to represent the drillstring, and was used to simulate stick-slip vibration. The model was developed with increasing levels of detail and the resultant models were validated against typical measured signals from the published literature. The stick-slip model describes the friction model that exists between the cutting tool and the rock. Based on theoretical analysis and mathematical formulation an efficient and adaptable model was created which was then used in the application of a method of species conserving genetic algorithm (SCGA) to optimise the drilling parameters. In conclusion, it was shown that the distributed-lumped model showed improved detail in predicting the transient response and demonstrated the importance of including the drillstring length. Predicting the response of different parameters along the drillstring is now possible and this showed the significant effect of modelling the drillcollar. The model was shown to better represent real system and was therefore far more suited to use with real time measurements.
Iraqi Government, Ministry of Higher Education and Scientific Research.
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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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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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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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Hernæs, Marthe Pernille Voltersvik. "Human related root causes behind oil well drilling accidents." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for petroleumsteknologi og anvendt geofysikk, 2012. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-20384.

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Many accident investigation techniques and other methods used by the petroleum industry today list a set of underlying human related causes and subsequent improvement suggestions. Do these techniques address the root cause behind the problem so that the appropriate initiatives can be implemented? The focus of the present thesis was to determine the human related root cause of two major accidents in the North Sea. This in order to give recommendations to improve the safety levels in the organisation. In order to achieve the above-mentioned goals, the IPT Knowledge Model was adapted to the given accidents. The data input into the model was based on interpreted observations from former investigation reports. The analysis of the blowout on Snorre A and the well control incident on Gullfaks C resulted in 49 and 63 observations respectively. For both accidents, the Human Factor that was indicated to have the largest affect on the accidents was Training and Competency (29% for Snorre A and 19% for Gullfaks C). Lack of competence was indicated as the majority subclass. Collectively, management and supervision, or lack thereof, was also indicated as being a contributing factor to the accidents. These final results coincide with the findings in other investigation reports. However, these are more acute, indicating a specific area of improvement within the company. By increasing the competency levels within the company and ensuring that the leaders and management have the proper tools to follow-up their employees and their operations, the safety levels and culture will improve.
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Becker, Thomas Edward. "Correlations for drill-cuttings transport in directional-well drilling /." Access abstract and link to full text, 1987. http://0-wwwlib.umi.com.library.utulsa.edu/dissertations/fullcit/8712608.

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Huang, Xiaoguang. "Limit state design of oil and gas well casings." Thesis, University of Wolverhampton, 2002. http://hdl.handle.net/2436/99757.

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Books on the topic "Oil well drilling rigs"

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Ardley, Neil. Oil rigs. Ada, OK: Garrett Educational Corp., 1990.

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Oil rigs. London: Macmillan, 1989.

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Stephen, R. J. Oil rigs. London: F. Watts, 1986.

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Drilling rigs. New York: Gareth Stevens Pub., 2012.

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Jones, Beverley. High heels 'n' oil rigs. Prince George, B.C: Caitlin Press, 1995.

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How oil rigs are made. New York, N.Y: Facts on File, 1985.

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Saroi͡an, A. E. Teorii͡a i praktika raboty burilʹnoĭ kolonny. Moskva: "Nedra", 1990.

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Combden, Robert. Drilling into success: Over a decade of drilling history. Kelligrews, Nfld: AC Contracting, 2010.

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Combden, Robert. Drilling into success: Over a decade of drilling history. Kelligrews, Nfld: AC Contracting, 2010.

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Bork, K. R. The rotary rig and its components. 4th ed. Austin, Tex: Petroleum Extension Service, Division of Continuing Education, University of Texas at Austin, 1995.

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Book chapters on the topic "Oil well drilling rigs"

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Iamandei, Aurelian, and Gheorghe Miloiu. "Motor Drives of Modern Drilling and Servicing Rigs for Oil and Gas Wells." In Power Transmissions, 619–34. Dordrecht: Springer Netherlands, 2013. http://dx.doi.org/10.1007/978-94-007-6558-0_50.

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Siddique, Abdul Hasib, and Braham Barkat. "Renewable Energy Installation: Challenges and Benefits in Oil/Gas Drilling Rigs." In ICPES 2019, 157–67. Singapore: Springer Singapore, 2020. http://dx.doi.org/10.1007/978-981-15-5374-5_13.

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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. "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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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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Estes, Jack C. "Role of Water-Soluble Polymers in Oil Well Drilling Muds." In Advances in Chemistry, 155–70. Washington, DC: American Chemical Society, 1986. http://dx.doi.org/10.1021/ba-1986-0213.ch009.

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Valipour Shokouhi, Samad, Agnar Aamodt, and Pål Skalle. "Applications of CBR in Oil Well Drilling: A General Overview." In Intelligent Information Processing V, 102–11. Berlin, Heidelberg: Springer Berlin Heidelberg, 2010. http://dx.doi.org/10.1007/978-3-642-16327-2_15.

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Skalle, Paal, Jostein Sveen, and Agnar Aamodt. "Improved Efficiency of Oil Well Drilling through Case Based Reasoning." In PRICAI 2000 Topics in Artificial Intelligence, 712–22. Berlin, Heidelberg: Springer Berlin Heidelberg, 2000. http://dx.doi.org/10.1007/3-540-44533-1_71.

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Pereira, Romulo A., Arnaldo V. Moura, and Cid C. de Souza. "Comparative Experiments with GRASP and Constraint Programming for the Oil Well Drilling Problem." In Experimental and Efficient Algorithms, 328–40. Berlin, Heidelberg: Springer Berlin Heidelberg, 2005. http://dx.doi.org/10.1007/11427186_29.

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Wang, Xiu-ying, Rui-bin Zhu, Jian-jun Gong, Ge-wei Han, Jing-jing Zhang, Li-hui Zhao, Bin Zhang, Hong-rui Huo, and Hui-yu Li. "Well Structure Optimization and Drilling Matching Technology for Shale Oil in Shulu Sag." In Proceedings of the International Field Exploration and Development Conference 2021, 1468–78. Singapore: Springer Nature Singapore, 2022. http://dx.doi.org/10.1007/978-981-19-2149-0_137.

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Conference papers on the topic "Oil well drilling rigs"

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Alsheikh, Mohammed, Chinthaka Gooneratne, Arturo Magana-Mora, Mohamad Ibrahim, Mike Affleck, William Contreras, Guodong David Zhan, et al. "Internet of Things IoT Edge Computer Vision Systems on Drilling Rigs." In SPE Middle East Oil & Gas Show and Conference. SPE, 2021. http://dx.doi.org/10.2118/204757-ms.

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Abstract This study focuses on the design and infrastructure development of Internet-of-Things (IoT) edge platforms on drilling rigs and the testing of pilot IoT-Edge Computer Vision Systems (ECVS) for the optimization of drilling processes. The pilot technology presented in this study, Well Control Space Out System (WC-SOS), reduces the risks associated with hydrocarbon release during drilling by significantly increasing the success and time response for shut-in a well. Current shut-in methods that require manual steps are prone to errors and may take minutes to perform, which is enough time for an irreversible escalation in the well control incident. Consequently, the WC-SOS enables the drilling rig crew to shut-in a well in seconds. The IoT-ECVS deployed for the WC-SOS can be seamlessly expanded to analyze drillstring dynamics and drilling fluid cuttings/solids/flow analysis at the shale shakers in real-time. When IoT-ECVSs communicate with each other, their value is multiplied, which makes interoperability essential for maximizing benefits in drilling operations.
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Said, Mohammed Mokhtar, Rick Pilgrim, Geoff Rideout, and Stephen Butt. "Theoretical Development of a Digital-Twin Based Automation System for Oil Well Drilling Rigs." In SPE Canadian Energy Technology Conference. SPE, 2022. http://dx.doi.org/10.2118/208902-ms.

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Abstract Advancements in digital technology and digitalization of industrial process have opened new frontiers for the oil and gas industry. The amount of historical data generated from drilled wells over the past decades of operations is currently being digitized and processed to provide operators with the option to make more informed decisions based on previous experiences that current staff may not be aware of due to the constant loss of experience during industry downturns. The industry is combating this loss of experience through the innovative use of digitalization, integrated operations, and automation. Real time support centers operating under integrated operations business model are now utilizing digital twins (high fidelity models of the ongoing process being supported) to run forecasting simulations and compare results to digitalized historical data with the help of artificial intelligence and expert systems to aid with decision making and training junior staff. The existence of high-fidelity models, and digital twins is a solid foundation for automation. In this paper a review of the emergence of these technologies is used to identify where digital twins can be used as the foundation of automation solutions that would shift the focus of drilling crews from efficiency to operation and process safety.
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Ziatdinov, Sergey, and Titto Thomas Philip. "Step Change Transformation of Legacy Rigs to Autonomous Drilling Rigs." In Abu Dhabi International Petroleum Exhibition & Conference. SPE, 2021. http://dx.doi.org/10.2118/207551-ms.

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Abstract During the past decade, drilling automation systems have been an attractive target for a lot of operating and drilling companies. Despite progress in automation in various industries, like mining and downstream, the drilling industry has lagged far behind in the real application of autonomous technologies implementation. This can be attributed to harsh environment, high level of uncertainty in input data, and that majority of stock is legacy drilling rigs, resulting in capital intensive implementations. In the past years there have been several attempts to create fully automated rigs, that includes surface automation and drilling automation. Such solutions are very attractive, because they allow people to move out of hazardous zones and, at the same time, improve performance. However, the main deficiency of such an approach is the very high capital investment required for development of highly bespoke rigs (Slagmulder 2016). And in the current business environment, with high volatility in oil and gas prices, plus the huge negative effect of the Covid-19 crisis on the world's economic situation, it would be hard to imagine that there are a lot of companies willing to make such a risky investment. In addition to this, due to the lack of demand, the market is full of relatively new, high-performance rigs. Taking all these into account, the obvious question is whether it makes sense to invest money and time into the development of drilling automation. The answer should be yes, for three substantial reasons:Automation improves personal safety, by moving people out of danger zones;Automation improves process safety, by transferring execution from person to machine, which reduces the risk of human error;Automation improves efficiency by bringing consistency to drilling and through the use of self-learning algorithms, which allow machines to drill each successive well better than the previous. This paper will not look into surface automation, such as pipe-handling, chemical and mud handling on site. The paper is focused on the subsurface, namely on the drilling automation process, the challenges that need to be overcome to deploy a vendor agnostic system on a majority of existing rigs. A vendor agnostic system is a modification of an operator's autonomous drilling system (Rassenfoss 2011), designed to use existing rigs, BHAs, and have minimum footprint on the rigs for operational use. A vendor agnostic system will increase adoption of automated technologies and further drive improvements in operational and business performance
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Gomez, Ernesto, Ebikebena Ombe, Brennan Goodkey, and Rafael Carvalho. "Drilling Automation: The Step Forward for Improving Safety, Consistency, and Performance in Onshore Gas Drilling." In SPE Middle East Oil & Gas Show and Conference. SPE, 2021. http://dx.doi.org/10.2118/204849-ms.

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Abstract In the current oil and gas drilling industry, the modernization of rig fleets has been shifting toward high mobility, artificial intelligence, and computerized systems. Part of this shift includes a move toward automation. This paper summarizes the successful application of a fully automated workflow to drill a stand, from slips out to slips back in, in a complex drilling environment in onshore gas. Repeatable processes with adherence to plans and operating practices are a key requirement in the implementation of drilling procedures and vital for optimizing operations in a systematic way. A drilling automation solution has been deployed in two rigs enabling the automation of both pre-connection and post-connection activities as well as rotary drilling of an interval equivalent to a typical drillpipe stand (approximately 90 ft) while optimizing the rate of penetration (ROP) and managing drilling dysfunctionalities, such as stick-slip and drillstring vibrations in a consistent manner. So far, a total of nine wells have been drilled using this solution. The automation system is configured with the outputs of the drilling program, including the drilling parameters roadmap, bottomhole assembly tools, and subsurface constraints. Before drilling every stand, the driller is presented with the planned configuration and can adjust settings whenever necessary. Once a goal is specified, the system directs the rig control system to command the surface equipment (draw works, auto-driller, top drive, and pumps). Everything is undertaken in the context of a workflow that reflects standard operating procedures. This solution runs with minimal intervention from the driller and each workflow contextual information is continuously displayed to the driller thereby giving him the best capacity to monitor and supervise the operational sequence. If drilling conditions change, the system will respond by automatically changing the sequence of activities to execute mitigation procedures and achieve the desired goal. At all times, the driller has the option to override the automation system and assume control by a simple touch on the rig controls. Prior to deployment, key performance indicators (KPI), including automated rig state-based measures, were selected. These KPIs are then monitored while drilling each well with the automation system to compare performance with a pre-deployment baseline. The solution was used to drill almost 60,000 ft of hole section with the system in control, and the results showed a 20% improvement in ROP with increased adherence to pre-connection and post-connection operations. Additionally, many lessons were learned from the use and observation of the automation workflow that was used to drive continuous improvement in efficiency and performance over the course of the project. This deployment was the first in the region and the system is part of a comprehensive digital well construction solution that is continuously enriched with new capabilities. This adaptive automated drilling solution delivered a step change in performance, safety, and consistency in the drilling operations.
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Settemsdal, Stig, and Saverio Ventrelli. "Retrofitting Offshore Drilling Rigs with Islanded DC Grids and Energy Storage." In Abu Dhabi International Petroleum Exhibition & Conference. SPE, 2021. http://dx.doi.org/10.2118/207621-ms.

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Abstract The paper presents a novel approach for modernizing/retrofitting offshore drilling rig power plants with islanded direct current (DC) power grids and energy storage. The concept has been successfully applied on several offshore rigs which are in operation today and is applicable to jack-ups, semi-submersibles, drill ships, as well as other types of marine support vessels for oil and gas platforms and wind farms. The approach aims to enhance the feasibility of leveraging energy storage solutions on offshore drilling rigs and marine vessels by making use of the existing power plant footprint. Unique measures have also been incorporated into the electrical system architecture to ensure that the reliability and safety of the existing alternating current (AC)-based system are not compromised. This enables operators to capitalize on the numerous benefits of energy storage (e.g., reduced emissions, enhanced dynamic performance for drilling and dynamic positioning, etc.) without having to perform a "rip and replace" of the entire power plant and electrical infrastructure.
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Rose, Richard. "The Planning Of The Drilling And The Rig Upgrading For The HPHT Pre Khuff Well." In Middle East Oil Show. Society of Petroleum Engineers, 1995. http://dx.doi.org/10.2118/29829-ms.

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Rosa, Fabio S. N., Luis C. B. Bianco, and Paulo A. Barata. "New Well Design Using Expandable Screen Reduces Rig Time and Improves Deep Water Oil Production in Brazil." In SPE/IADC Drilling Conference. Society of Petroleum Engineers, 2003. http://dx.doi.org/10.2118/79791-ms.

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Atchison, Bryan Wade. "Automated Well Control: From Automated Detection to Automated Shut-In." In SPE/IADC Middle East Drilling Technology Conference and Exhibition. SPE, 2021. http://dx.doi.org/10.2118/202091-ms.

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Abstract Objectives April 2010 in the Gulf of Mexico and January 2017 in Oklahoma brought into sharp focus what can happen if the oil and gas industry gets well control wrong: 16 fatalities, significant environmental damage, loss of assets and reputation. Each year we have multiple blowouts and several fatality events due to a loss of well control. The oil and gas industry can improve from a personnel safety, environmental and reputation perspective. The Automation of Well Control will bring a significant step change in the area of Process Safety forwells. It prevents blowouts, reduces all influx volumes, minimising kicktolerance volumes and reducingcasing and well costs. Method A system has been developedwhich enables Automated Well Control whilst in drilling mode. Pre-determined influx rates, agreed by the operator and drilling contractor, and input by the driller are established. Once the system detects the influx, it performs a series of operations by taking control of the drilling rig equipment. The drill string is spaced out, top drive and mud pumps are stopped, and the BOP is closed. All of this occurs without the driller doing anything; however, he can intervene at any moment. Thissystem is designed as an aid to the driller and does not remove his responsibility. Results The Automated Well Control system has been tested on drilling simulators with real drillers. Comparisons tests have shown that the technology enables shut-in times faster than conventional human interface methods, with influx volumes typically 10-20% of those experienced during manual shut-in. Additionally, a full Field Trial using a traditional rigdemonstrated the effectiveness of the system, proving up the functionality under different operational requirements. The system can now be applied to any type of rig worldwide. Over 50 potential modules have been identified. Planned developments forthe system include circulatingout the kick automatically, shut-in for tripping, circulating, cementing and in-flow testing. It provides assurance for afast, safe and effective shut-in.A full Technology Qualification process has been used for this technology. Innovative Technology Over the past 20 years, technology advancements associated with simulators and cyber-rigs have enabled new technologies to be developed. One of these technologies is Automated Well Control. It is believed that this innovative system will enable a step change in the performance ofprocess safety forwell control, dramaticallyreducing major accident hazards, thereby saving millions of dollars per well, reducing environmental impact and preventing loss of life.
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Soquar, Emmanuel, and Chris van der Westhuyzen. "Slim-hole Drilling – De-risking Exploration in Remote Locations." In SPE/AAPG Africa Energy and Technology Conference. SPE, 2016. http://dx.doi.org/10.2118/afrc-2571031-ms.

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ABSTRACT Onshore exploration – both oil and gas and geothermal – typically involves the mobilisation of full sized conventional rigs. The support package includes back up and auxiliary parts, capable of drilling and fully evaluating deep large diameter conventional holes. In early stage exploration programs conducted in remote and frontier locations, the operating costs can approximate those of an offshore operation. This standard approach may be an unnecessary expense and lessons can be learned from the mining industry, which has been operating in a lower cost environment in frontier locations for over 125 years. A slim well approach is adopted not just to the well design but to team size, civil works, evaluation requirements and logistics. A smaller rig capable of drilling slim wells to the desired terminal depth (of up to 4,000 m), with complete logging and core sampling, can provide exploration companies with a cost effective solution.
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Adeola, Olatunji, Kolby Burmaster, Michael Phi, Shaun Arnold, Alexander Robinson, and Jackson Klein. "Drilling Execution and Completion Advancements Continue to Deliver for Guyana." In Offshore Technology Conference. OTC, 2021. http://dx.doi.org/10.4043/31230-ms.

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Abstract The ExxonMobil Wells organization, along with Hess Guyana Exploration Limited and CNOOC Petroleum Guyana Limited, executed a successful multi-rig campaign to achieve First Oil on the Liza Phase 1 project ahead of schedule, utilizing advanced deepwater completion technologies to deliver highly productive wells. Considering the sizable resource offshore Guyana, strategic partnerships have been established with drilling contractors and other service providers to build economies-of-scale. ExxonMobil's prior global experience is actively being leveraged in rig selection and well design. Standardization, both above and below the rotary, has allowed for increased flexibility on current and future well execution, maintaining optionality to rapidly adjust project pace. A deliberate contracting strategy with established rig providers has also opened access to top tier rigs with reduced procurement timelines, providing flexibility with total rig count and capability. With an integrated team approach focused on simulataneous operations (SIMOPS) mitigation, rig movements have been optimized within the field to prioritize the highest value work and streamline project delivery. Effective schedule integration with multiple drilling rigs and installation vessels has reduced SIMOPS downtime during Phase 1 project execution. Additionally, batch rig operations have allowed the team to capitalize on operational efficiencies. A combination of these factors led to on-time well delivery and helped the project achieve aggressive First Oil milestones. The team has implemented innovative technologies to maximize value and well reliability, including the following: integrated geosteering workflows, with Azimuthal Ultra-Deep Resistivity (AUDR), enabling maximum reservoir penetrations; a suite of low equivalent circulating density (ECD) drilling fluids that enable the drilling of narrow-margin, highly deviated wells; ExxonMobil's patented NAFPac™ openhole gravel pack technology and autonomous inflow control devices (AICDs) on stand-alone-screen completions to increase well life and reliability; and remotely operated vehicle (ROV) based tree intervention control systems and ROV actuated suspension valves allowing for offline installation of subsea trees. Additionally, the team implemented the first floating application of the NOVOS™ automated slip-to-slip drilling system. NOVOS™ has been coupled with an automated drilling advisory system (AutoDAS) and data analytics environments for continuous performance improvement. The production wells that were delivered for Liza Phase 1 have highly productive, low-skin completions averaging over 900 m in length and production rates in excess of 30 kbd/well. Advancements in completion technology and efficiency proven on Liza Phase 1 are being extended into Phase 2 development and beyond, providing additional reservoir management capability. Lastly, ExxonMobil's commitment to Guyana extends to its people. Guyanese personnel have benefitted from significant training provided by ExxonMobil and sub-contractors, and Guyanese Nationals represented approximately 40% of the workforce involved in Wells-related activities at the end of 2020.
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Reports on the topic "Oil well drilling rigs"

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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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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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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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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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