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Journal articles on the topic 'Offshore oil well drilling'
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1
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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Tudorache, V. P., M. Minescu, and N. Ilias. "PARTICULARITIES RELATED TO DRILLING OFFSHORE WELLS IN AREAS WITH VERY DEEP WATER." Neft i gaz 117-118, no. 3-4 (April 15, 2020): 93–108. http://dx.doi.org/10.37878/2708-0080/2020.015.
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The article presents an analysis of the realities faced by the operators in the oil industry, but especially the operators in the exploitation of the risers. Oil industry operators are focusing on drilling offshore wells to very deep water depths, as there are significant oil and gas resources that ensure high production. This analysis refers to the establishment of limit conditions that occur during drilling operations. We call this complex of factors the mechanics of riser. The article also refers to establishing the way of working in accordance with the API recommendations in force and obtaining theoretical results for offshore drilling in deep water. These results are the starting point for simulation with the help of specialized software and obtaining results useful for the exploitation of risers in drilling wells in deep water. Drilling activity in deep water can only be done with dynamically positioned platforms, such as semisubmersibles platforms and drillship.
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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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Grassian, David, and Daniel Olsen. "Lifecycle Energy Accounting of Three Small Offshore Oil Fields." Energies 12, no. 14 (July 17, 2019): 2731. http://dx.doi.org/10.3390/en12142731.
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Small oil fields are expected to play an increasingly prominent role in the delivery of global crude oil production. As such, the Energy Return on Investment (EROI) parameter for three small offshore fields are investigated following a well-documented methodology, which is comprised of a “bottom-up” estimate for lifting and drilling energy and a “top-down” estimate for construction energy. EROI is the useable energy output divided by the applied energy input, and in this research, subscripts for “lifting”, “drilling”, and “construction” are used to differentiate the types of input energies accounted for in the EROI ratio. The EROILifting time series data for all three fields exhibits a decreasing trend with values that range from more than 300 during early life to less than 50 during latter years. The EROILifting parameter appears to follow an exponentially decreasing trend, rather than a linear trend, which is aligned with an exponential decline of production. EROILifting is also found to be inversely proportional to the lifting costs, as calculated in USD/barrel of crude oil. Lifting costs are found to range from 0.5 dollars per barrel to 4.5 dollars per barrel. The impact of utilizing produced gas is clearly beneficial and can lead to a reduction of lifting costs by as much as 50% when dual fuel generators are employed, and more than 90% when gas driven generators are utilized. Drilling energy is found to decrease as the field ages, due to a reduction in drilling intensity after the initial production wells are drilled. The drilling energy as a percentage of the yearly energy applied is found to range from 3% to 8%. As such, the EROILifting+Drilling value for all three fields approaches EROILifting as the field life progresses and the drilling intensity decreases. The construction energy is found to range from 25% to 63% of the total applied energy over the life of the field.
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Brkić, Dejan, and Zoran Stajić. "Offshore Oil and Gas Safety: Protection against Explosions." Journal of Marine Science and Engineering 9, no. 3 (March 16, 2021): 331. http://dx.doi.org/10.3390/jmse9030331.
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Offshore oil and gas operations carry a high risk of explosions, which can be efficiently prevented in many cases. The two most used approaches for prevention are: (1) the “International Electrotechnical Commission System for Certification to Standards Relating to Equipment for Use in Explosive Atmospheres” (IECEx) and (2) European “Atmosphere Explosible” (ATEX) schemes. The main shortcoming for the IECEx scheme is in the fact that it does not cover nonelectrical equipment, while for the ATEX scheme, it is due to the allowed self-certification for a certain category of equipment in areas with a low probability of explosions, as well as the fact that it explicitly excludes mobile offshore drilling units from its scope. An advantage of the IECEx scheme is that it is prescribed by the US Coast Guard for protection against explosions on foreign mobile offshore drilling units, which intend to work on the US continental shelf but have never operated there before, with an additional requirement that the certificates should be obtained through a US-based Certified Body (ExCB). Therefore, to avoid bureaucratic obstacles and to be allowed to operate with minimized additional costs both in the US and the EU/EEA’s offshore jurisdictions (and very possibly worldwide), all mobile offshore drilling units should be certified preferably as required by the US Coast Guard.
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Norina, Natalia. "Types of offshore drilling platforms." E3S Web of Conferences 549 (2024): 07004. http://dx.doi.org/10.1051/e3sconf/202454907004.
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The Russian Energy Strategy for the period up to 2035 estimates the development of the hydrocarbon resource potential of the continental shelf of the Arctic seas as the most important geopolitical and technical challenge for the Russian oil and gas sector. An adequate response to it means sufficient production of hydrocarbons in the country beyond the time horizon of 2035. Russia’s continental shelf includes the following oil and gas bearing provinces: West Barents, East Barents, Timan-Pechora, West Siberian, Khatango-Vilyui, Laptev, East Arctic, Novosibirsk-Chukotka, Okhotsk, Baltic and Caspian regions. The first eight provinces are located in the Arctic shelf zone, which is a strategic region in the context of resource potential and opportunities for the development of available mineral resources. The estimate for the initial recoverable hydrocarbon resources is 100 billion tons of standard fuel. The methods and equipment used for drilling offshore wells (offshore drilling) are very similar to those used for onshore drilling. In contrast to onshore drilling, the functional scheme for offshore drilling is complicated by the presence of a water column between the wellhead and the drilling rig. This paper gives an overview of existing offshore drilling rigs: fixed, semi-fixed and mobile platforms. It also includes description of pros and cons of such offshore platforms.
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Asad, Muhammad Mujtaba, Razali Bin Hassan, Fahad Sherwani, Zaheer Abbas, Muhammad Saeed Shahbaz, and Qadir Mehmood Soomro. "Identification of effective safety risk mitigating factors for well control drilling operation." Journal of Engineering, Design and Technology 17, no. 1 (February 4, 2019): 218–29. http://dx.doi.org/10.1108/jedt-04-2018-0068.
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Purpose Every year, hundreds of people have died and thousands have been injured because of insufficient management of well control at oil and gas drilling and production sites. Major causes which have been reported in previous studies included uncontrollable blowouts and failure of blowout preventers because of insufficient safety practices. These onshore and offshore blowout disasters not only harm the work force but also critically affect the environment and marine life. In this research paper, a detailed quantitative survey and qualitative risk assessments (RA) have been carried out for assessing the potentially hazardous activities associated with well control along with their appropriate controls and risk reduction factors and mitigating measures in Middle East and south East Asian countries. Design/methodology/approach The sequential explanatory research design has been adopted in this study. Whereas, descriptive statistical approach has been used for the quantitative data analysis of this study. While, in-depth interview approach has been used for qualitative data collection. Similarly, what-if analysis method has been adopted in this study for the identification of effective safety and health risk mitigating factors because it provides in-depth information from health and safety environment experts. Findings The cumulative quantitative results based on the response from Saudi Arabian drilling industry have indicated that the well control operation is highly hazardous then Malaysian and Pakistani oil and gas industries. Likewise, findings from what-if analysis approach demonstrate that the drilling crewmembers have repetitively faced life threatening hazards which occur (safety and chemical) during well control onshore and offshore operation because of oil base mud, confined space at site, pinch points and falling during working on blow out preventers. According to the overall result, respondents have highly recommended engineering and administrative hazard controlling factors as most suitable for the elimination of safety and chemical hazards during well control activities. Practical implications Besides, the developed methodological framework for the identification of suitable hazard controls can also be effectively used for potential hazards reorganization and identification of suitable hazard controls for other drilling and production industries and regions for accident prevention and safety and health management. Originality/value This is a first comparative research study which has been carried out in Malaysian, Saudi Arabian and Pakistani onshore and offshore oil and gas industries for well control health and safety management and reorganization of most effective hazards mitigating factors at drilling sites.
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Brooks, Deidre. "2012 PESA industry review—exploration." APPEA Journal 53, no. 1 (2013): 141. http://dx.doi.org/10.1071/aj12012.
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The Australian exploration landscape experienced an escalation of unconventional activity in 2012. Drilling targeting shale oil and gas, basin-centred tight gas, and coal gas is on the increase compared to previous years. Drilling for onshore oil and large offshore gas continued to be a staple activity for the year although, in general, offshore, the number of wells drilled is continuing to decline, in line with previous years. A number of very large 3D seismic surveys were acquired in 2012 and this is hoped to provide many future drilling targets. Within Australia, 19 new offshore conventional petroleum exploration permits were awarded within the Commonwealth jurisdiction (compared to 24 in 2011), of which 15 are located in WA, two in Victoria, one in NT, and one in the Territory of Ashmore and Cartier Islands (NT). Onshore exploration tenures awarded in 2012 included four in WA, 14 in NT, six in Queensland, and nine conventional and six geothermal in SA. At least 25 3D and six 2D seismic surveys were acquired offshore in 2012, including some very large 3D marine surveys, the largest covering an area of 12,417 km2. Onshore seismic activity was highest in Queensland and SA where 33 and 11 surveys were acquired, respectively. Offshore, 21 conventional petroleum exploration wells were drilled during the year, which resulted in 11 announced discoveries. Two exploration wells, which were spudded late in 2011, were announced as discoveries early in 2012. Five wells, which were spudded in 2012, were still drilling at year end. This equates to a better than 50% technical success rate for offshore exploration drilling for all well results known at year end. All but two of these wells were located in WA waters, the others being located in NT and Victoria. Australia-wide onshore drilling was more active than in 2011 and, as is reflected in the seismic activity, the most wells (1,048) were drilled in Queensland (dominated by CSG drilling), followed by SA (77).
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Leusheva, Ekaterina, and Valentin Morenov. "Effect of Temperature Conditions in Arctic Offshore Oil Fields on the Rheological Properties of Various Based Drilling Muds." Energies 15, no. 15 (August 8, 2022): 5750. http://dx.doi.org/10.3390/en15155750.
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During well drilling in offshore conditions beyond the North of the Arctic Circle, there are often problems associated with deviations in the rheological parameters of the drilling mud as the temperature changes. Mud temperature in the upper part of the well in most cases is in the range up to 20 °C, whereas in the productive formation it is up to 80 °C and more. For such conditions, it is necessary to estimate the influence of temperature on the rheological parameters of drilling fluids, which is done in this paper. Compositions of water-based and hydrocarbon-based muds that may be used in the conditions of the offshore hydrocarbon fields were considered. The paper presents the authors’ formula for a drilling mud that possesses more stable rheological parameters in the temperature conditions of the offshore oil field and is more environmentally friendly. The physical properties of the newly designed drilling mud were measured with laboratory equipment. Rheological investigations were carried out under varying temperatures up to 80 °C. The results of the experiments show the newly designed drilling mud to be more stable than its hydrocarbon-based analogue. Besides, the newly developed composition has a lower content of solid phase, which is also an important parameter for the process of sea wells construction, often characterized by a narrow window of permissible pressure.
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Jayakumar, Swathika. "Technology Focus: Offshore Drilling and Completion (October 2023)." Journal of Petroleum Technology 75, no. 10 (October 1, 2023): 70–71. http://dx.doi.org/10.2118/1023-0070-jpt.
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Optimizing and continually increasing efficiencies at every stage of the drilling and completion process are central themes in the papers showcased in this feature. Innovating our way through difficult times is what the oil and gas industry excels at, especially during challenging periods. During the COVID-19 pandemic, the offshore energy industry faced immense struggles with high upfront capital investment and long lead times in uncertain circumstances with extremely low oil prices. The challenges brought about by the pandemic served as a backdrop to many of these innovations. Companies were compelled to discover creative solutions to maintain efficiency, reduce costs, and ensure safety during an era of unprecedented disruption. Innovation in advanced analytics and machine-learning algorithms is used to optimize drilling-center locations, leading to cost reduction. This development became even more critical during the pandemic as companies aimed to maximize efficiency and minimize expenses. The execution of large-scale projects such as the Johan Sverdrup development highlights innovation in project management, enabling timely and cost-effective operations in a challenging environment. The emphasis on digital solutions and fiber-optic technology in Guyana’s offshore operations illustrates the industry’s adaptation to the pandemic by enabling remote operations and real-time data collection while maintaining efficiency in a new discovery. Innovations in riserless light well intervention systems are particularly relevant during the pandemic. These systems improved efficiency and safety for offshore interventions, enabling the industry to operate with minimal personnel onboard. The focus on well-planning strategies to overcome challenges in deep depleted reservoirs includes approaches that optimize drilling in complex conditions, which is crucial when efficiency is paramount. Retrofitting autonomous inflow control devices proved an effective approach in implementing state-of-the-art technology to improve reservoir sweep and productivity. Moving forward, this innovative spirit in our industry as seen in these papers is a testament to our resilience during challenging times. In the coming years, this ability to sustainably increase recovery efficiencies to ensure energy security is crucial to shaping the future of energy production. Recommended additional reading at OnePetro: www.onepetro.org. SPE 212499 4D Radar Imaging of Wellbore Geometry While Drilling by Lars Øy, Well ID, et al. OTC 30979 Guyana Operations and First Oil by Mike F. Ryan, ExxonMobil, et al. SPE 212915 Enhancing Riserless Light Well Intervention Operability From Operator Perspective by Michael Long Ge, BP, et al. SPE 214057 Challenges of Drilling Deep Wells in a Complex Overburden With Severe Depletion and Experiences From Caspian Sea by Anwar Juma Al Saadi, Dragon Oil, et al.
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Liu, Gang, Dou Mei, and Jialin Zhang. "A Method Based on SVM Algorithm for Wellbore Collision Monitoring: Using Vibration Signal Characteristics of Bit Drilling in Different Mediums." International Journal of Signal Processing Systems 8, no. 2 (June 2020): 42–48. http://dx.doi.org/10.18178/ijsps.8.2.42-48.
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During well drilling operations of offshore oil and gas exploration, the progress that bit drills through rocks, steel casing and other mediums produces vibration signal with different characteristics. In this work, we presented a wellbore collision monitoring method that using vibration signal produced by bit penetrating in different drilling mediums to identify those unwanted cases that bit is colliding into adjacent wellbores in drilling operation. Firstly, experiments have been carried out to acquire vibration signal of bit drilling in sorts of rock, cement and steel casing mediums. Then, to dig out signal feature in different time scales, empirical mode decomposition (EMD) method was used to decompose every signal sample into several intrinsic mode functions (IMFs) and we extracted and analyzed characteristics in time and frequency domain of all signal IMFs. Finally, support vector machine classifiers were trained with feature vectors of a part of signal IMFs to realize the function of drilling mediums identification and classification. SVM Performance test results indicates that correct identification rate of those classifiers can basically reach 90%. The method presented in this paper proved to be feasible to provide a new approach to monitor wellbore collision risks for offshore drillings.
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Zheng, Wen Pei, Jian Chun Fan, Lai Bin Zhang, and Dong Wen. "Measurement and Control System of Intense-Magnetic Memory Testing Equipment for Reusable Offshore Oil Well Tubing." Key Engineering Materials 439-440 (June 2010): 1624–27. http://dx.doi.org/10.4028/www.scientific.net/kem.439-440.1624.
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Oil well tubing is used in oil extraction in offshore oil well. Under the force of tubular columns, erosion and pressure of drilling fluids, the oil well tubing usually fails in long-term service, which always leads to accidents and stagnation of production. So it’s especially necessary to detect faults in tubing. Intense-magnetic memory testing equipment for reusable offshore oil well tubing is developed for this consideration. The equipment is composed of feeding machines, baiting machines, transport machines and a detection machine. Measurement and control system decides the running sequence logic of these components and obtains fault signals of tubing. The avoidance of transport machines for oil well tubing coupling makes the transport of tubing stable. The synchronization control of transport and detection of tubing decides the accurate location of faults. The automatic switch of both detection units and measurement of fault signals makes it convenient to detect oil well tubing of multiple sizes.
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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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Shahruz Eyyubzade, Sabuhi Ahmadov, Shahruz Eyyubzade, Sabuhi Ahmadov. "CONSTRUCTION OF STATIONARY SEABED NO. 760 FOR DRILLING 10 PRODUCTION WELLS IN THE DARWIN BANK FIELD." PAHTEI-Procedings of Azerbaijan High Technical Educational Institutions 17, no. 06 (May 18, 2022): 188–92. http://dx.doi.org/10.36962/pahtei17062022-188.
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Project of construction of stationary offshore foundation No. 760 for drilling of 10 production wells in “Darwin bank” field of “Absheron oil” OGPD to project assignment prepared by “Absheron oil” OGPD according to SOCAR's protocol dated 25.06.2013 and approved by SOCAR performed accordingly. The project was developed in accordance with the current rules CniP 1.02.01-85, the conditions for the most favorable placement of drilling equipment on the platform, the experience gained in design, construction, drilling of oil and gas facilities. The project includes rigid construction fencing sections with a height of 1200 mm and removable along the perimeter of the platform to ensure safe movement of workers on the platform during drilling and operation. The feet of the support blocks are pushed 6m into the ground on the seabed, and surfs are dug from the inner pile of the foot to the project level. Anchors are released on these surfs and the internal cavities of the pits and pipes are filled with cement mortar. This means that the support block is attached to the seabed by means of combined drilling piles. Keywords: Support block, stationary seabed, well drilling, Darwin bank, Absheron oil, platform design
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Skoko, Ivica, Marinko Jurčević, and Diana Božić. "Logistics Aspect of Offshore Support Vessels on the West Africa Market." PROMET - Traffic&Transportation 25, no. 6 (December 16, 2013): 587–93. http://dx.doi.org/10.7307/ptt.v25i6.1258.
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With the rapidly increasing global energy needs, offshore oil production has become an attractive source of energy. Supplying offshore oil production installations is a complex logistics problem that hinges on many factors with significant uncertainties. So, it is critical to provide the necessary supplies and services without interruption. In a typical offshore oil production effort, oil companies charter most or all drilling units as well as offshore supply vessels (OSV). The type and duration of charter contract has direct impact on the project budget as vessels market is closely correlated with the world market crude oil price which can have daily significant fluctuations. As the region of West Africa is one of the world’s busiest offshore exploration and oil production markets employing 12% of the world’s fleet, exploring its issues, was taken to study the relations between daily OSV rates and crude oil price. The research results presented in this paper show correlation between OSV daily rates and crude oil price with broader fluctuations in crude oil price.
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Ludmila Ravane Santos da Silva, Rayssa Barcellos Paiva, Letícia Kizuka Pereira, Vitor Mena Pirola, Viviane Macharet Demberg, and Hans Schmidt Santos. "Scenario study on the choice of drilling method for oil wells in the context of the Brazilian pre-salt layer." World Journal of Advanced Research and Reviews 21, no. 3 (March 30, 2024): 1047–58. http://dx.doi.org/10.30574/wjarr.2024.21.3.0687.
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This work aims to show the techniques and operational procedures that are used on an Offshore Drilling Rig, as well as application on each step of the process to the construction of an oil and gas well to prevent operational mistakes that cause non productive time. In the present work, an analysis regarding on a “Pre-Salt” well-constructed by a conventional drilling method, as well as difficulties encountered due to the method chosen. The results observed on case study show that the correct choose of the drilling method can determine significant advance in the “Pre-Salt” wells, in order to reduce the lost time and not to affect the well construction chronology.
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Cherepovitsyn, Alexey, and Andrey Lebedev. "Drill Cuttings Disposal Efficiency in Offshore Oil Drilling." Journal of Marine Science and Engineering 11, no. 2 (February 2, 2023): 317. http://dx.doi.org/10.3390/jmse11020317.
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The relevance of the study lies in the fact that with the depletion of conventional oil and gas reserves and an increase in the global demand for hydrocarbons, the focus of the industrial sector is gradually shifting towards the resources of the Arctic, which have tremendous potential for development. However, the current industrial policy has to take into account the concept of sustainable development, or harmony between economy, ecology, and society. Therefore, the extraction of raw materials must obey the principles of the circular economy, which aims to generate closed-loop cycles that maximize the use of the resources extracted and minimize waste generation so as not to destroy fragile ecosystems. It is necessary to drill wells for the discovery of a hydrocarbon deposit on the shelf, which entails the generation of a tremendous amount of complex waste., The use of disposal methods for drilling cuttings, which must be disposed of economically and with environmental reliability, is required to solve the problem. This study compares two methods of disposing of drilling waste. Statistical modeling results and a review of the literature show that the most effective method from both economic and environmental points of view is the thermomechanical cleaning of cuttings on site. This article discusses the advantages and disadvantages of both methods. It also evaluates drilling waste management prospects and opportunities for Russian offshore fields.
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Peng, Chunyao, Wenqiang Feng, Xiaohu Luo, Shujiao Li, and Chen Riji. "An Environmentally Friendly Wbm System Can Prevent Hard Brittle Shale Instability." Scientific Contributions Oil and Gas 32, no. 2 (March 17, 2022): 133–42. http://dx.doi.org/10.29017/scog.32.2.843.
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In the Weizhou Southwest oilfields, drilling delays and suspension of wells prior to reaching the targets due to wellbore instability had occurred frequently. The hard brittle shale played a problematic role. Conventional water-based drilling fluids didn’t conquer the problematic formation due to intrinsically performance deficiencies. While Oil based drilling fluids are routinely preferred in the more technically demanding applications, they are cause for increasing concern due to offshore environmental restrictions and expensive disposal costs. An environmentally acceptable water-based drilling fluid was developed to challenge the problematic formation based on the combination of methylglucoside-silicate concept. It stabilized the reactive shale by the same mechanism as did oil-based drilling fluid in preventing shale hydration, pore pressure increase and weakening of shale by effectively developing sufficient osmotic force to offset hydraulic and chemical forces acting to cause filtration flux into the hard brittle shale. A field trial was initiated on the CNOOC 931 platform in Weizhou oilfield. The data from the pilot well showed that the novel drilling fluid exhibited excellent inhibition and lubricity which approached or even exceeded oil-based fluids.
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Lynch, Michael C. "The Macondo Oil Field Disaster." Journal of Disaster Research 6, no. 5 (October 1, 2011): 482–85. http://dx.doi.org/10.20965/jdr.2011.p0482.
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TheMacondo oil rig explosion and subsequent oil spill was the worst disaster in the US offshore oil industry since 1969. Although some worried that it reflected the greater challenges of deepwater drilling for which the industry was not prepared, investigations have shown that a variety of decisions made, primarily during the drilling of the well, caused the blowout and explosion. Apparently, a corporate culture of cost cutting led to many of these decisions, and it suggests that human failures, both in senior levels where culture is set, and at the lower levels where it affects operations, are the primary challenges that need to be overcome to reduce the likelihood of future disaster.
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Dzyublo, A. D., S. О. Borozdin, and E. E. Altukhov. "Technologies for Safe Handling of Drilling Waste during Well Construction in the Ob Bay." Occupational Safety in Industry, no. 6 (June 2021): 52–60. http://dx.doi.org/10.24000/0409-2961-2021-6-52-60.
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Development of the Russian oil and gas fields in the Arctic requires ensuring industrial and environmental safety of conduct of the operations. Large and unique oil and gas condensate fields are discovered in the southern part of the Kara Sea. The Kamennomysskoye-Sea, Severo-Kamennomysskoye, Semakovskoye, Parusovoye, etc. gas condensate fields are located in the Ob Bay of the Kara Sea. The raw material base of the Severo-Obskoye gas condensate field, unique in terms of the reserves, will become the basis for future Arctic LNG projects. Based on the published data, the initial recoverable total hydrocarbon resources in the Ob and Taz bays are about seven billion tons. Active exploration and commissioning of the already discovered fields require the large volumes of well drilling in a freezing sea, the presence of permafrost, and gas hydrates. During construction of the wells and operation of the offshore ice-resistant oil and gas production platforms, it is required to ensure the disposal of drilling waste (cuttings) and domestic water. There are two technologies for waste disposal — injection into the reservoir or into the clay formations. The first one is used in onshore fields, the second one — on the shelf. Injection into a clay reservoir is successfully used in the Lunskoye gas field on the shelf of the Sakhalin island, and on the Prirazlomnoye oil field in the Pechora Sea. The possibility of using the method and the selection of a reservoir for injecting waste into it requires a geological justification, and the reservoir should ensure a stable injectivity of the required volume. The article presents the results of modeling the injection into the formation of drilling waste, and the waste of the household activities for the Kamennomysskoe-Sea gas condensate field. Calculation was made concerning the zone of absorption of the technological waste into the designed well of the offshore ice-resistant stationary platform. Formation allocation for waste injection was made according to the data of a complex of offshore wells geophysical studies. Three packs of sandy-argillaceous rocks with high reservoir properties were selected as the object of industrial waste disposal. Сalculation was carried out related to the radius of the spread of waste (effluent) in the target reservoir considering drilling and operation of twenty five wells, the construction of which is planned for five years. The results of modeling the process of pumping industrial waste of various types into an absorption well showed that the planned volumes can be successfully disposed of in the selected objects. This will allow to ensure functioning of the marine industry and its environmental safety.
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Valitov, R. R., and Yu B. Lind. "ANALYSIS OF TECHNOLOGIES FOR COLLARING LARGE-DIAMETER SECTIONS OF OIL AND GAS WELLS." Problems of Gathering Treatment and Transportation of Oil and Oil Products, no. 3 (July 3, 2024): 22–31. http://dx.doi.org/10.17122/ntj-oil-2024-3-22-31.
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The article considers issues on construction of deep oil and gas multi-column wells with an extended trunk. Drilling of such wells is relevant, for example, on offshore fields, where drilling from the shore with a vertical deviation of over 1000 m is much more economically feasible than from floating vehicles.For drilling wells with an extended trunk and passing through zones incompatible with drilling for geological reasons, it is necessary to begin construction of a well with landing a large diameter direction – often up to 720 mm. The article analyzes the emerging problems and ways to solve them by drilling large-diameter wells and landing casing string. The results of practical experience in conducting work in the Pechora Sea and at the Astrakhan gas condensate field are summarized, on the basis of which recommendations for carrying out similar works are given.When constructing wells, especially starting with a large diameter, it is not always possible to drill a well efficiently, even with drilling equipment ideally suited to specific geological and technological conditions. And this, in turn, can lead to losses of production time and materials, and in the extreme case – to emergency works. Based on the analysis carried out, the article proposes an algorithm of technological operations for drilling wells and landing large diameter directions, which increases the probability of successful drilling to the design depth.
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Jeong, Jiho, Chaeog Lim, Byeong-Cheol Park, Jeonghoon Bae, and Sung-chul Shin. "Multi-Objective Optimization of Drilling Trajectory Considering Buckling Risk." Applied Sciences 12, no. 4 (February 10, 2022): 1829. http://dx.doi.org/10.3390/app12041829.
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Directional drilling involves three sections—vertical, curved, and horizontal—and is used for drilling offshore wells and mining unconventional resources. The initial design of a well trajectory is important because the total length of the well trajectory is associated with the drilling cost; furthermore, the drag force and torque may cause buckling and damage the drill pipe. The well trajectory should be optimized considering the length and load of drill pipes. In this study, a new method of optimizing directional well trajectory is used to formulate the objective function considering the length, drag, and torque. To verify the applicability of this method, we applied it to an actual oil well and a theoretical oil well. The results obtained show that the use of the proposed method in the initial design of drilling trajectory can reduce the torque by up to 15%, drag by 2.6%, and length by 8.5% for the two models used in this study. This method is safer as it reduces the risk of buckling compared to the design that relies on the previous designer’s experience, and it reduces the trajectory length; thus, it can save time and costs of drilling.
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Liang, Ji Wen, Chuan Shi Lu, Chong Zhang, Yi Long Xu, Chao Zhang, and Jian Guo Chen. "Creep Property Experimental Research of Offshore Unconsolidated Sand Reservoir." Applied Mechanics and Materials 638-640 (September 2014): 422–26. http://dx.doi.org/10.4028/www.scientific.net/amm.638-640.422.
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Unconsolidated sandstone is a kind of formation with low strength and large deformation property. Deeper unconsolidated sand formations have larger geostress and perform the plastic and rheological characteristics. After the borehole has been drilled into, this kind of sandstone will creep, which will cause some problems such as pipe stuck and casing deformation failure etc. Therefore, creep parameters of unconsolidated sandstone are critical for designing drilling fluid density and choosing casing material. Through indoor experiments, creep data of unconsolidated sandstone from Zhujiang group of X oil field in the west of South China Sea was get. The experiments results indicate that creep law of this sandstone conforms to Nishihara’s model, and the creep parameters were calculated based on experiments data. According to Nishihara’s model, using numerical simulation method, this paper analyzes the relationship of sandstone creep shrinkage rate with time of Zhujiang group reservoir sandstone and determines the drilling fluid density that ensures the safety of horizontal wells drilling, which has guiding significance for well design and drilling.
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Carpenter, Chris. "Multifunctional-Team Approach Achieves Extended-Reach Record Offshore Abu Dhabi." Journal of Petroleum Technology 76, no. 05 (May 1, 2024): 94–96. http://dx.doi.org/10.2118/0524-0094-jpt.
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_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 216326, “Longest Extended-Reach-Drilling Well Worldwide Drilled in Middle East, Offshore Abu Dhabi, UAE,” by Marah Mohamad Alabed, Naser Salah Alsuwaidi, and Jamie Scott Duguid, SPE, ADNOC, et al. The paper has not been peer reviewed. _ The complete paper describes the engineering design and operational practices that supported the setting of a new extended-reach world record in a mature carbonate field offshore Abu Dhabi. This accomplishment reduces the carbon footprint of the development, allows acquisition of reservoir data earlier in the development plan, and accelerates production while reducing costs. This extended-reach development program is a strong example of what can be accomplished when a multifunctional team cultivates a strategic plan to expand technical and operational capabilities in a drilling campaign. Reservoir and Development-Plan Background The 1-md oil reservoir is a carbonate dominated by packstone and grainstone rock types in terms of storage capacity. Average porosity is 18%, and thickness is 130 ft. Permeability reduces in an southeast/northwest direction, dropping below 1 md. Calcite cementation development has occurred in the westernmost areas of the reservoir because of late oil in these low structural areas. Initially, the target reservoir was drilled at 2-km well spacing with a five-spot waterflooding scheme from wellhead platform towers. Later, development was optimized by a line waterflooding scheme at 250-m well spacing by development from an environmental island. The target reservoir area was partitioned into four development areas (West A, West B, West C, and West D). The partition is based on drilling reachability from environmental islands and underlying geology. The current optimized development began in the West A reservoir area through an artificially constructed island. The remaining reservoir areas required investment of two new islands. High risk is associated with these investment decisions because these reservoir areas degrade in terms of reservoir rock properties. Additionally, an increasing trend of water saturation exists with progress in the northwest direction within the transition zone. The development plan in the West A area is based on drilling segments called AB and BC, first with over-20,000-ft laterals to achieve production buildup by target date. To test the West B area, Segment BC was extended, thus covering both West A and B areas. This option reduced drilling complexity and maximized the reservoir-production rate. Additionally, by adopting the island drilling option instead of appraising a limited area of West B, an extensive area of approximately 10 km could be appraised. To implement this option, a stepout drilling plan was executed by drilling eight extended-reach maximum-reservoir-contact wells in increments to meet the goal of appraising the West B reservoir area. These first wells were extended in increments of 1,000–2,000 ft to test the capability to drill and run completion to target a measured depth (MD) of 45,000 ft. Upon applying learnings from these pilot wells, a stepout to extending wells to 50,000 ft MD and greater was studied. Fig. 1 shows the map of the subject drilled well with an extended MD of 50,000 ft with an underlying oil-saturation map. This optimized field-development strategy has allowed for effective West B reservoir appraisal.
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Ren, Mei Peng, Xiang Fang Li, Fu Quan Shi, and Long Ma. "Research of Seabed Rescue Method of Uncontrolled Blowout in Offshore Drilling." Advanced Materials Research 616-618 (December 2012): 837–43. http://dx.doi.org/10.4028/www.scientific.net/amr.616-618.837.
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Presently, rescue equipment and method for uncontrolled blowout in offshore drilling are very rare, of which the consequences were very serious. With analysis of mechanics of materials based on shut-in water hammer pressure and wellhead pressure while rescuing, and fluid mechanics of uncontrolled blowout based CFD, a rescue equipment for uncontrolled blowout in offshore drilling has been invented, and proposing a rescue method. There are several emergency scenarios have been made. Take the “deep horizon oil rig” in the gulf of Mexico for example, the flow field properties around this equipment could be calculated by software to prove the reliability of it. The equipment is a conceptual invention which could be designed in different types according to the size and strength of original wellhead. This equipment could prevent well blowout and collect leaped oil.
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Esposte Coutinho, Priscila, Larissa Haringer Martins da Silveira, Marcio Cataldi, Fabiana Rodrigues Leta, Antônio Orestes de Salvo Castro, Cláudio Benevenuto de Campos Lima, and Gilson Brito Alves Lima. "Wavelet Transform Processing in Detecting Failures in Offshore Well Production." Latin American Journal of Energy Research 9, no. 1 (August 31, 2022): 1–11. http://dx.doi.org/10.21712/lajer.2022.v9.n1.p1-11.
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Brazil has a significant offshore oil production, which dates back to the late 1960s and is currently focused on exploring pre-salt reservoirs. The drilling technology Petrobras uses is considered a world standard: in 2020, it allowed offshore production to reach 97% of the country’s total oil production. During the process, however, unwanted events, and even operational failures may occur, which are capable of significant damage. Thus, failure detection is extremely important to prevent production losses or delays, to reduce costs and to avoid accidents. This study uses a real, public database on offshore production, and proposes using wavelet transforms to detect production failures. With the technique, we pinpointed which time intervals between measurements showed relevant variability, and then clustered the data, according to mobile averages, to shrink the record number. Using wavelet transforms, we analyzed which variables could be used as predictors of production failures and identified the temperature read by the Temperature and Pressure Transducer sensor (T-TPT) and the pressure at the Production Choke sensor (P-PCK) as possible predictor variables. We also observed the creation of a filtered series, averaged from the original data series, which maintained its variability, showing the viability of record regrouping in shorter series.
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Kumar, Rajesh, S. Ramanan, and J. L. Narasimham. "Redevelopment of a Matured Multilayered Carbonate Offshore Field Through High Technology Horizontal and Multilateral Wells." SPE Reservoir Evaluation & Engineering 10, no. 05 (October 1, 2007): 453–57. http://dx.doi.org/10.2118/97520-pa.
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Summary Oil productivity from Mumbai High field, an offshore multilayered carbonate reservoir, increased significantly through the implementation of a major redevelopment program. Geoscientific information available from approximately 700 exploratory and develop- ment wells drilled in the field during nearly 25 years was incorporated during geological and reservoir simulation modeling of the field. High-technology drilling (viz. horizontal/multilaterals for the new development wells) was adopted on field scale to effectively address typical complexity of the layered carbonate reservoirs. Since the commencement of the project in 2000, approximately 140 new wells were drilled, mostly with horizontal and multilateral drainholes. Besides these, more than 70 suboptimal producers were also converted as horizontal sidetracks under brownfield development. The horizontal sidetracks were drilled as long-drift sidetrack (LDST), extended-reach drilling (ERD), LDST-ERD, short-drift sidetrack (SDST), and medium-radius drainhole (MRDH) types of wells through the application of innovative and emerging drilling technologies with nondamaging drilling fluids, whipstocks to kick off sidetrack wells, rotary-steering systems, and expandable tubulars to complete horizontal sidetracks in lower layers. With the implementation of this project, the declining trend was fully arrested and a significant upward trend in production has been established. Introduction The field redevelopment process requires the intergration of reservoir-development strategies, facility options, and drilling and production philosophies to maximize oil and gas recovery from a matured field. A significant number of case studies are available on mature field revitalization using a multidisciplinary team concept, exhaustive geo-scientific data analysis, and new drilling technologies (Chedid and Colmenares 2002; Clark et al. 2000; Dollens et al. 1999; Kinchen et al. 2001). Advancements in drilling and completion technology have enabled construction of horizontal wells with longer wellbores, more-complex well geometry, and sophisticated completion designs. Horizontal wells provide an effective method to produce bypassed oil from matured fields. In the early 1980s, this technology was in the development stage and was used in limited applications. By the 1990s, the technology had matured, and its acceptance in the industry had increased significantly. Performance of horizontal/multilateral wells, risk assessment of horizontal-well productivity and comparison of horizontal- and vertical-well performance in different fields is available in literature (Babu and Aziz 1989; Brekke and Thompson 1996; Economides et al. 1989; Joshi 1987; Joshi and Ding 1995; Mukherjee and Economides 1991; Norris et al. 1991; Vij et al. 1998). A significant number of horizontal/multilateral development wells were drilled as a part of redevelopment of Mumbai High, a matured multilayered carbonate offshore field in Western India. The details of new technologies applied and performance of these new high-technology wells are presented in this paper. Besides comparison of well productivity of horizontal and conventional sidetrack wells, this paper presents some technical issues faced.
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Dinara Huseynova, Ruslan İbrahimli, Dinara Huseynova, Ruslan İbrahimli. "METHODS FOR HIGHLY EFFICIENT DEVELOPMENT OF OFFSHORE RIVERINE OILFIELDS." PAHTEI-Procedings of Azerbaijan High Technical Educational Institutions 42, no. 07 (May 25, 2024): 25–39. http://dx.doi.org/10.36962/pahtei42072024-03.
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The geological reservoir conditions of offshore fluvial oilfields in the Bohai region are characterized by their complexity, including thin reservoir layers, significant lateral variations, and poor connectivity. These conditions pose challenges in deploying production wells, finely describing reservoirs, and optimizing resource allocation. This study has developed several techniques to address these challenges effectively. These include fine description and quantitative characterization of reservoirs in areas with few wells, regional sedimentation analysis and identification of individual river reservoirs, optimization of well networks for single sand bodies, and a rolling technique for tapping potential in fluvial oilfields. The effectiveness of these techniques has been confirmed through their application in the development of 11 oilfields in Bohai, resulting in the addition of newly discovered reserves amounting to 5 billion tons during rolling development evaluations. The fine description technology has achieved a drilling accuracy rate of 98%, while the recognition technique for individual river reservoirs in fluvial environments has increased the recovery rate by an average of 3%. Moreover, the rolling development technique has enabled rapid resource transformation around the oilfields, facilitating the efficient development of oil and gas resources. The Bohai oilfield, situated in the Bohai Sea, is part of the offshore Bohai Bay Basin. After four decades of exploration and development, this field has produced significant oil reserves from the Neogene Minghuazhen and Guantao formations. In 2012, these reserves constituted 56.3% of the Bohai oilfield's total proven oil reserves, underscoring the critical role of efficient development strategies for these reservoirs in maintaining and enhancing oil production. These formations have undergone extensive fracturing due to recent tectonic activities, resulting in a highly broken structure and complex fault blocks. Post-Neogene, the Bohai Sea became a major drainage center for the Bohai Bay Basin, fostering not only traditional fluvial sedimentary systems but also shallow water delta systems, primarily around distributary channels or underwater channels. The fluvial oilfields discussed in this paper include reservoirs from both meandering and braided river systems, as well as parts of shallow water delta distributary channels. The reservoirs typically exhibit curved strip, ribbon, and dendritic shapes, and feature thin reservoir layers with substantial lateral variation. This complexity is further compounded by interactions between water and oil beds, leading to a distinct "one sand body, one oil reservoir" scenario. To effectively develop these fluvial oilfields, the research employs advanced techniques. These include detailed reservoir description and quantitative characterization in areas with sparse well distribution, study of regional sedimentary evolution and identification of individual river reservoirs, optimization of well networks for single sand bodies, and a rolling technique to tap potential in fluvial oilfields. These methods are essential for overcoming the geological challenges and optimizing oil extraction in such complex environments. The development of offshore fluvial oilfields encounters specific challenges, largely due to differences in the approach and conditions compared to onshore oil field development. For onshore fields in China, the development strategy typically evolves progressively, beginning with the establishment of a basic well pattern. This initial phase is followed by integrated geological and reservoir studies to determine optimal development and infill drilling patterns. In contrast, offshore oilfields are constrained by several factors that complicate their development. High operational costs limit the number of exploratory wells that can be drilled, resulting in sparse well patterns and consequently less data for making informed decisions. Additionally, the physical limitations of offshore platforms — such as available space, the lifespan of the platform, and finite well slot resources — prevent frequent adjustments to the drilling plan. To navigate these challenges and achieve efficient development, offshore oilfields require robust preliminary research. This involves a comprehensive and detailed geological description of the reservoirs, which forms the basis for strategic deployment of development wells. By adapting the well deployment strategy to the specific geological characteristics and constraints of offshore environments, developers can enhance the effectiveness and efficiency of oil extraction from these complex reservoirs. Keywords: geological reservoir condition, fluvial oilfields, geological challenges, seismic data, conventional method
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Johns, Rhodri, and Patrick Despland. "2013 PESA industry review: exploration." APPEA Journal 54, no. 1 (2014): 431. http://dx.doi.org/10.1071/aj13043.
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Exploration activity in Australia in 2013 occurred across a broad spectrum of conventional and unconventional plays. Competition for acreage was buoyant with large tracts of key onshore basins either licensed or under application. Offshore, there were new awards on the western Australian margin and in the Bight Basin off SA. Offshore 3D seismic acquisition was reduced from anomalously high levels in 2012. Onshore 2D seismic acquisition was at historic highs and onshore 3D was the most ever recorded. Overall drilling levels were maintained despite a decline offshore. Of 13 offshore wells drilled, six were discoveries. Sixty-nine exploration wells (excluding CSG wells) were drilled onshore. Fifty addressed conventional, and 19 were unconventional shale or basin-centered gas targets. Sixty of the 69 wells were drilled in the Cooper/Eromanga Basin where conventional oil and gas exploration yielded 11 oil and six gas discoveries. Drilling and fraccing campaigns in the Nappamerri Trough unconventional gas plays provided early encouraging results. 213 exploration and appraisal CSG wells were drilled in the CSG basins of Queensland and NSW. In Queensland a record total of 1,317 CSG wells were drilled in fiscal year 2012/2013. Shale gas exploration activity was increasingly focused on the Palaeozoic and Proterozoic Basins of Western, Central and Northern Australia with major oil and gas companies involved in joint ventures preparing for drilling in 2014. The results of these programmes will have an important bearing on the future direction of exploration in these plays.
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Dzublo, A. D., A. I. Ermolaev, G. M. Geresh, and V. E. Perekrestov. "Shallow gas influence of on design decisions for the development of gas condensate fields on the shelf of the Arctic and subarctic seas." Arctic: Ecology and Economy 14, no. 2 (June 2024): 192–204. http://dx.doi.org/10.25283/2223-4594-2024-2-192-204.
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The article discusses issues related to shallow gas influence on design decisions for the development of offshore oil and gas condensate fields. The authors show the presence and distribution of shallow gas accumulations in the upper part of the geological section and its influence on the quality of seismic surveys. The release of shallow gas has caused many serious accidents at offshore drilling rigs and oil and gas production platforms. The main danger of shallow gas deposits is when drilling intervals for the conductor and surface casing due to the lack of blowout equipment at the wellhead. The authors analyze the areal and depth distribution of shallow gas in the Arctic and subarctic seas, and find out that small deposits of several hundred meters in size are most common. The main methods of detecting and studying shallow gas accumulations above gas-bearing structures are high-resolution seismic exploration, drilling of engineering-geological wells and pilot holes with well logging. The researchers reveal the main features of the wave pattern indicating the gas saturation in the upper part of the section. They present the main technical solutions for the development of the Lunsky, Kirinsky and Yuzhno-Kirinsky oil and gas condensate fields located on the self of Sakhalin Island and suggest changes in design solutions during their development in view of the shallow gas presence in the upper part of the geological section. The authors substantiate the need to create Russian software systems and methods of automated design for developing offshore oil and gas fields in the Arctic, taking into account geological and geophysical uncertainty, the shallow gas presence and technical factors.
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Morenov, Valentin, Ekaterina Leusheva, and Tianle Liu. "Development of a Weighted Barite-Free Formate Drilling Mud for Well Construction under Complicated Conditions." Polymers 13, no. 24 (December 19, 2021): 4457. http://dx.doi.org/10.3390/polym13244457.
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Construction of oil and gas wells at offshore fields often involves high formation pressure and the presence of swellable clay rocks in the section. In addition, productivity preservation is also an important aspect. For this purpose, it is necessary to reduce the solids content of the drilling mud. The purpose of this work is to develop, improve, and study compositions of weighted drilling muds with low content of solids, on the basis of organic salts of alkali metals and polymers for the construction of wells prone to rock swelling and/or cavings, as well as drilling fluids for drilling-in the formation. In order to achieve the set goal the following is required: Analysis of existing drilling muds of higher density for drilling wells in unstable rock intervals and for drilling in the productive formation; analysis of experience in using drilling systems on the formic acid salts base and substantiation of requirements for flushing fluids during well construction; development and investigation of drilling mud compositions on the formate base; and the evaluation of inhibiting effect of systems containing organic salts, polymer reagents, and calcium carbonate on clay samples. The developed drilling mud is characterized by a high inhibiting ability that allows minimized mud-weighting by the natural solid phase. This reduces the volume of prepared mud and facilitates the regulation of its properties by reducing the dispersion of drilled cuttings; it eliminates problems related to hydration and the swelling of active clay rocks; and stabilizes unstable argillites prone to caving. The low solids content, low filtration rates, and inhibitory nature of the mud allows high stability of the rheological properties of the mud, and preserves oil and gas reservoir productivity under conditions of elevated formation pressure.
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Noussia, Kyriaki. "Global Offshore Energy Installations: Implications for Environmental Pollution Liability Insurance in Relation to Major Oil Spill Incidents." European Energy and Environmental Law Review 32, Issue 2 (March 1, 2023): 100–111. http://dx.doi.org/10.54648/eelr2023005.
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Post the Deepwater Horizon (DWH) incident, offshore energy insurance underwriters reassessed their risk exposures in response to newly perceived operational risks involving blowouts, fires, explosions, lost control of well and other non-hurricane risks. Already in the aftermath of the DWH incident, it has been noted that it would be crucial to consider the willingness of the global offshore energy insurance market to participate in efforts to establish and fix a new liability limit for environmental pollution liability insurance. In relation to the approach followed by the USA administrations, this has been fragmented, with the current administration in office introducing a moratorium on new oil and gas leasing on federal lands and waters and in terms of its policy relating to its climate agenda. Against this background, this article describes the insurance implications of environmental pollution liability in case of offshore drilling operations incidents (such as the DWH) resulting in major oil spills. In doing so it discusses in detail the legal framework and the position in the EU and draws a comparison with other jurisdictions. It also contains proposals for future measures so as to be able to offer better insurance coverage for such offshore drilling disasters, such as the introduction and collection of data on damages, or an EU wide and an international agreement especially focusing on offshore-related incidents with a transboundary character, as well as a mechanism to facilitate early compensation payments to potentially vulnerable victims.
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Amaechi, Chiemela Victor, Ahmed Reda, Harrison Obed Butler, Idris Ahmed Ja’e, and Chen An. "Review on Fixed and Floating Offshore Structures. Part I: Types of Platforms with Some Applications." Journal of Marine Science and Engineering 10, no. 8 (August 5, 2022): 1074. http://dx.doi.org/10.3390/jmse10081074.
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Diverse forms of offshore oil and gas structures are utilized for a wide range of purposes and in varying water depths. They are designed for unique environments and water depths around the world. The applications of these offshore structures require different activities for proper equipment selection, design of platform types, and drilling/production methods. This paper will provide a general overview of these operations as well as the platform classifications. In this paper, a comprehensive review is conducted on different offshore petroleum structures. This study examines the fundamentals of all types of offshore structures (fixed and floating), as well as the applications of these concepts for oil exploration and production. The study also presents various design parameters for state-of-the-art offshore platforms and achievements made in the industry. Finally, suitable types of offshore platforms for various water depths are offered for long-term operations. An extension of this study (Part II) covers sustainable design approaches and project management on these structures; this review helps designers in understanding existing offshore structures, and their uniqueness. Hence, the review also serves as a reference data source for designing new offshore platforms and related structures.
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Chen, Ye, Youcheng Zheng, Bo Zeng, Yu Fan, Pengcheng Wu, Xudong Wang, and Chengyu Xia. "Study on Simulation Law of Cuttings Migration in Shale Gas Horizontal Wells." Scientific Programming 2022 (July 14, 2022): 1–10. http://dx.doi.org/10.1155/2022/6057641.
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Inland and offshore oil exploitation, large displacement, and horizontal well are more and more widely used, which can significantly improve the oilfield exploitation efficiency and economic benefits. However, in the complex drilling process, the debris particles generated in the large displacement and horizontal well section drilling are deposited in the lower low-speed area of the lower part of the ring empty shaft. It will cause underground accidents such as complex moving, drilling, increased resistance, drilling column fracture, and so on, which will seriously affect the efficiency and economic benefits of drilling. This paper addresses the problem of annular debris accumulation and the characteristics of high-density drilling fluid and uses the CFD-DEM (discrete cell method) method to simulate the debris movement process in the well eye based on the coupling of FLUENT and EDEM software. The edge calculation is used to provide strong resource allocation and calculation force support for this paper, fully consider the influence of the interaction between drilling fluid, debris particles, and drilling rod and well wall, and explore the influence law of the eccentric ring space of the conventional steel drill pipe.
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Carpenter, Chris. "Technology Focus: Extended-Reach and Complex Wells (May 2021)." Journal of Petroleum Technology 73, no. 05 (May 1, 2021): 58. http://dx.doi.org/10.2118/0521-0058-jpt.
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In selecting papers for this feature, reviewer Stéphane Menand of Helmerich and Payne has identified a trio of papers that investigates new approaches toward familiar issues encountered when drilling complex well types. Whether considering the customization of drilling approaches in Middle Eastern carbonate reservoirs, implementing a collaborative work flow in tackling high-tortuosity wells offshore Western Australia, or researching the ability of a fibrous material to effect hole cleaning as opposed to polymeric sweeps, the authors of these papers understand that technical expertise may not be completely realized if it is not applied to problems in original ways. In carbonate reservoirs, the goal of drilling extended-reach wells is set against the geological makeup of such formations, the complexity of which adds significant uncertainty to geosteering and well placement. The authors of paper SPE 203335 develop a work flow that makes possible the customization of drilling scenarios through an emphasis on mechanical specific energy, as well as the use of an optimized borehole-assembly design. The work flow helped deliver what the authors write is the longest well in the Middle East offshore Abu Dhabi. In a similar vein, the authors of paper SPE 202251 describe a challenging scenario involving an ultraextended-reach well in a mature field offshore Western Australia. The project overcame shallow water depth and a high tortuosity requirement by implementing an integrated plan that used a reservoir-mapping-while-drilling service. The authors stress that this technology, coupled with active collaboration between specialists, town, and rig site, allowed the project to achieve the desired oil-column thickness with zero collision incidents. Highly deviated wells often face problems resulting from ineffective hole cleaning. Paper SPE 203147 studies the properties of a fibrous material when compared with the hole-cleaning performance of common polymeric pills. The authors write that the fibrous material proved effective, in part because of a unique characteristic in which a spiderweb-like network of fibers is created that does not allow cuttings to settle easily in complex wells. In addition, the material is environmentally friendly. All three papers approach well- established problems in the critical industry sector of extended-reach drilling with innovation and confidence. Enjoy the papers and be sure to search SPE’s OnePetro online library for more fresh approaches to the technical challenges posed by these well types. Recommended additional reading at OnePetro: www.onepetro.org. SPE 196410 - Analysis of Friction-Reduction System During Drilling Operation at a High-Inclination Well on Field X by Rizqiana Mudhoffar, Tanri Abeng University, et al. SPE 197257 - Successful Management of Collision Risk in an Extended-Reach Well by Manchukarn Naknaka, Mubadala Petroleum, et al. SPE 202730 - Challenges in Drilling and Completion of Extended-Reach-Drilling Wells With Landing Point Departure of More Than 10,000 ft in Light/Slim Casing Design by Nitheesh Kumar Unnikrishnan, Abu Dhabi National Oil Company, et al.
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Gaidaichuk, Viktor, Lyudmyla Levkivska, and Maryna Lazareva. "Forecasting supercritical behavior of drill strings in horizontal wells." Strength of Materials and Theory of Structures, no. 110 (June 26, 2023): 118–30. http://dx.doi.org/10.32347/2410-2547.2023.110.118-130.
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The determining factor in the current changes in the world energy balance and its structure, as well as the global development of the oil and gas industry, is currently the technological factor. As a result, fundamentally new categories of horizontal and inclined wells appeared and developed. They give a multiple increase in flow rates, as they increase the production area many times over. They are used in the development of offshore projects, in swampy and very difficult areas, to increase oil recovery, restoration of inactive wells.
New technologies based on the method of horizontal drilling have revolutionized the practice and theory of world oil production, as they have allowed the destruction of offshore oil and gas fields without the construction of expensive offshore foundations and platforms.
When drilling horizontal wells, as a rule, the main cause of emergencies is the loss of stability of the drill string, its bifurcation protrusion and the maximum frictional interaction with the well wall. The issues of theoretical modeling of the phenomenon of unstable protrusion of columns are associated with significant difficulties, the main of which is due to the need to set the Sturm-Liouville boundary value problem on a large length of drill string. Because for deep wells, the drill string becomes geometrically similar to a human hair, many traditional mathematical methods used to integrate solving equations become poorly convergent in these cases.
Based on the theory of curvilinear flexible rods, the problem of theoretical modeling of supercritical states of drill strings taking into account their contact interaction with the walls of oil and gas wells is set. Analytical solutions of the problem are constructed, which determine the critical values of external tensile or compressive longitudinal force and torque at a given difference in the diameters of the cavity and the drill string, the zones of supercritical states of drill strings are established.
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Stickland, Peter. "Oil and gas exploration in Australia in 2014—a year of extremes." APPEA Journal 55, no. 1 (2015): 163. http://dx.doi.org/10.1071/aj14012.
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In 2014, explorers in Australia experienced a range of highs and lows. There have been discoveries in new play types such as Phoenix South–1 in the Roebuck Basin, offshore WA, as well as discoveries that rejuvenate mature basins such as Seneco–3 in the onshore Perth Basin and a number of wells demonstrating unconventional gas flows in the Cooper Basin. Exploration lows include the inevitable unsuccessful wells, the general low level of drilling activity both offshore and in some states, frustrations at approval delays and constraints—particularly in NSW and Victoria—and the sharply contracting business environment towards the end of 2014 as the oil price rapidly fell to its lowest levels in five years. This PESA review looks in detail at the trends and highlights for oil and gas exploration both onshore and offshore Australia in 2014; not just outcomes with the drill bit, but also leading indicators such as seismic data acquisition and permit awards. It also seeks to be insightful and to make conclusions about the condition of oil and gas exploration in Australia, as well as comment on future implications for the industry.
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Mackie, Steve. "Australian exploration review 2016." APPEA Journal 57, no. 2 (2017): 363. http://dx.doi.org/10.1071/aj16254.
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In 2016, explorers in Australia were called upon to demonstrate realistic optimism. The year clearly demonstrated that during an industry contraction, such as that seen by the upstream oil and gas industry since the oil price crash of late 2014, near field conventional exploration still produces discoveries. These include Shefu, Muruk, Davis, Outtrim and Spartan. Amungee NW demonstrated unconventional gas flows in the Beetaloo Basin. As usual, new reservoirs were discovered in appraisal programs such as at Roc and Phoenix South. Exploration lows, however, were the general mood with the inevitable unsuccessful wells, decreases in permit awards and associated work programs, the general low level of drilling activity both offshore and onshore, frustrations at approval delays and constraints and the still contracting business environment. This Petroleum Exploration Society of Australia review looks in detail at the trends and highlights for oil and gas exploration both onshore and offshore Australia during 2016; not just outcomes with the drill bit, but also leading industry health indicators such as drilling, seismic data acquisition and permit awards. It also seeks to be insightful and to make conclusions about the condition of oil and gas exploration in Australia, as well as comment on future implications for the industry.
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Innes, Gareth, Jan Thore Eia, and Steinar Nesse. "Case Study: Drill-Cuttings Treatment Alternatives—A Comparative Emissions Assessment." Journal of Petroleum Technology 74, no. 02 (February 1, 2022): 47–50. http://dx.doi.org/10.2118/0222-0047-jpt.
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The offshore oil and gas industry has always been cognizant of its impact on the marine environment. The choices that operators make in how they operate, including the disposal of drill cuttings, must address an increasing number of environmental and climate targets in addition to those related to health, safety, and cost. As a typical well will produce approximately 1000 metric tons of oil-based drill cuttings, quantifying greenhouse-gas (GHG) emissions associated with the disposal and treatment of drill cuttings has become an essential step to achieving net-zero ambitions. Since 1991 (1993 for fields in production), strict regulations relating to the discharge of oil-based drill cuttings have been in force under the OSPAR (Oslo/Paris) Convention. Those regulations banned the practice of discharge to sea of untreated oil-based drill cuttings and led to a situation where they were generally shipped to shore for treatment and disposal. In 2020, TWMA engaged DNV, the independent energy expert and assurance provider, to undertake a comparative study between the company’s offshore thermal drill-cuttings treatment solution and conventional alternatives including “skip and ship,” bulk transfer, and cuttings reinjection (CRI) used on the Norwegian Continental Shelf (NCS). It is the first paper to show a direct emissions comparison between offshore processing and alternative methods implemented. The study assessed the carbon dioxide (CO2) footprint and nitrogen dioxide (NOx) emissions for each of the different alternatives. The values were then used to create an interactive emissions calculator that can easily be applied to specific projects to clarify the actual potential for emissions reduction within the drilling waste management process. Background Technological improvements, as well as cost focus on existing solutions, have meant that offshore thermal drill-cuttings treatment has been widely adopted in many offshore basins as one of the safest and most cost-effective approaches. In Norway, which was the subject of the study, adoption of the technology has been slower than in other countries, with onshore thermal treatment of oil-based cuttings applied as the predominant technique, while some fields use offshore slurrification and injection into dedicated disposal wells. However, the cost of drilling new disposal wells and the track record of successful offshore thermal projects in other countries have improved the frame conditions for the use of offshore thermal treatment of cuttings on the NCS. It has also been demonstrated, in an earlier independent comparative study by Carbon Zero (SPE 207519), that the carbon footprint of skip and ship to shore of drill cuttings is 53% higher than that of drill-cuttings treatment at the wellsite (SPE 202639).
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Rylance, Martin. "Technology Focus: Offshore Drilling and Completion (October 2021)." Journal of Petroleum Technology 73, no. 10 (October 1, 2021): 45. http://dx.doi.org/10.2118/1021-0045-jpt.
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Communication and prediction are symmetrical. Communication, in effect, is prediction about what has happened. And prediction is communication about what is going to happen. Few industries contain as many phases, steps, and levels of interface between the start and end product as the oil and gas industry—field, office, offshore, plant, subsea, downhole, not to mention the disciplinary, functional, managerial, logistics handovers, and boundaries that exist. It therefore is hardly surprising that communication, in all its varied forms, is at the very heart of our business. The papers selected this month demonstrate how improved communication can deliver the prediction required for a variety of reasons, including safety, efficiency, and informational purposes. The application of new and exciting ways of working, partially accelerated by recent events, is leading to breakthrough improvements on all levels. Real-time processing, improved visualization, and predictive and machine-learning methods, as well as improvements in all forms of data communication, are all contributing to incremental enhancements across the board. This month, I encourage the reader to review the selected articles and determine where and how the communication and prediction are occurring and what they are delivering. Then perhaps consider performing an exercise wherein your own day-to-day roles—your own areas of communication, interfacing, and cooperation—are reviewed to see what enhancements you can make as an individual. You may be pleasantly surprised that some simple tweaks to your communication style, frequency, and format can deliver quick wins. In an era of remote working for many individuals, it is an exercise that has some value. Recommended additional reading at OnePetro: www.onepetro.org. OTC 30184 - Augmented Machine-Learning Approach of Rate-of-Penetration Prediction for North Sea Oil Field by Youngjun Hong, Seoul National University, et al. OTC 31278 - A Digital Twin for Real-Time Drilling Hydraulics Simulation Using a Hybrid Approach of Physics and Machine Learning by Prasanna Amur Varadarajan, Schlumberger, et al. OTC 31092 - Integrated Underreamer Technology With Real-Time Communication Helped Eliminate Rathole in Exploratory Operation Offshore Nigeria by Raphael Chidiogo Ozioko, Baker Hughes, et al.
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Thatcher, M., and D. B. Marietta. "SUBSEA PRODUCTION FOR WELLS DRILLED FROM JACKUP DRILLING UNITS." APPEA Journal 27, no. 1 (1987): 357. http://dx.doi.org/10.1071/aj86030.
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Subsea production systems have been an accepted method of developing offshore oil and gas fields since the installation of the first subsea trees in the early 1960s offshore California. Generally subsea completions have been done from floating drilling vessels on wells with subsea wellhead equipment. A number of wells have been completed subsea by bottom supported jackup rigs on wells drilled using mudline suspension equipment. The subsea completion equipment and methods utilised to adapt mudline suspension wells for a subsea production tree are described. This method of completion offers important benefits as it allows completion of wildcat or delineation wells, it can be used in areas of small, scattered reservoirs, and it can be used in conjunction with floating production systems. The cost associated with these subsea completions is roughly equivalent to those of standard subsea completions from floating vessels. An overview of a typical completion system is presented and compared.