Academic literature on the topic 'Mars (Offshore oil platform)'
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Journal articles on the topic "Mars (Offshore oil platform)"
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Madon, Mazlan, and John Jong. "Geothermal Gradient And Heat Flow Maps Of Offshore Malaysia: Some Updates And Observations." Bulletin of the Geological Society of Malaysia 71 (May 31, 2021): 159–83. http://dx.doi.org/10.7186/bgsm71202114.
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An update of the geothermal gradient and heat flow maps for offshore Malaysia based on oil and gas industry data is long overdue. In this article we present an update based on available data and information compiled from PETRONAS and operator archives. More than 600 new datapoints calculated from bottom-hole temperature (BHT) data from oil and gas wells were added to the compilation, along with 165 datapoints from heat flow probe measurements at the seabed in the deep-water areas off Sarawak and Sabah. The heat flow probe surveys also provided direct measurements of seabed sediment thermal conductivity. For the calculation of heat flows from the BHT-based temperature gradients, empirical relationships between sediment thermal conductivity and burial depth were derived from thermal conductivity measurements of core samples in oil/gas wells (in the Malay Basin) and from ODP and IODP drillholes (as analogues for Sarawak and Sabah basins). The results of this study further enhanced our insights into the similarities and differences between the various basins and their relationships to tectonic settings. The Malay Basin has relatively high geothermal gradients (average ~47 °C/km). Higher gradients in the basin centre are attributed to crustal thinning due to extension. The Sarawak Basin has similar above-average geothermal gradients (~45 °C/km), whereas the Baram Delta area and the Sabah Shelf have considerably lower gradients (~29 to ~34 °C/km). These differences are attributed to the underlying tectonic settings; the Sarawak Shelf, like the Malay Basin, is underlain by an extensional terrane, whereas the Sabah Basin and Baram Delta east of the West Baram Line are underlain by a former collisional margin (between Dangerous Grounds rifted terrane and Sabah). The deep-water areas off Sarawak and Sabah (North Luconia and Sabah Platform) show relatively high geothermal gradients overall, averaging 80 °C/km in North Luconia and 87 °C/km in the Sabah Platform. The higher heat flows in the deep-water areas are consistent with the region being underlain by extended continental terrane of the South China Sea margin. From the thermal conductivity models established in this study, the average heat flows are: Malay Basin (92 mW/m2), Sarawak Shelf (95 mW/m2) and Sabah Shelf (79 mW/m2). In addition, the average heat flows for the deep-water areas are as follows: Sabah deep-water fold-thrust belt (66 mW/m2), Sabah Trough (42 mW/m2), Sabah Platform (63 mW/m2) and North Luconia (60 mW/m2).
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Balogun, Abdul-Lateef, Abdul-Nasir Matori, and Kelvin Wong Toh Kiak. "DEVELOPING AN EMERGENCY RESPONSE MODEL FOR OFFSHORE OIL SPILL DISASTER MANAGEMENT USING SPATIAL DECISION SUPPORT SYSTEM (SDSS)." ISPRS Annals of Photogrammetry, Remote Sensing and Spatial Information Sciences IV-3 (April 23, 2018): 21–27. http://dx.doi.org/10.5194/isprs-annals-iv-3-21-2018.
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Environmental resources face severe risks during offshore oil spill disasters and Geographic Information System (GIS) Environmental Sensitivity Index (ESI) maps are increasingly being used as response tools to minimize the huge impacts of these spills. However, ESI maps are generally unable to independently harmonize the diverse preferences of the multiple stakeholders’ involved in the response process, causing rancour and delay in response time. This paper’s Spatial Decision Support System (SDSS) utilizes the Analytic Hierarchy Process (AHP) model to perform tradeoffs in determining the most significant resources to be secured considering the limited resources and time available to perform the response operation. The AHP approach is used to aggregate the diverse preferences of the stakeholders and reach a consensus. These preferences, represented as priority weights, are incorporated in a GIS platform to generate Environmental sensitivity risk (ESR) maps. The ESR maps provide a common operational platform and consistent situational awareness for the multiple parties involved in the emergency response operation thereby minimizing discord among the response teams and saving the most valuable resources.
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Barile, Nadia B., Mariaspina Scopa, Sara Recchi, and Eliana Nerone. "Biomonitoring of coastal marine waters subject to anthropogenic use: development and application of the biosensor Mosselmonitor®." Ovidius University Annals of Chemistry 27, no. 2 (December 1, 2016): 81–86. http://dx.doi.org/10.1515/auoc-2016-0013.
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Abstract The overall objective of this study was to develop a biological early warning system (Mosselmonitor®) on offshore platform to detect critical environmental situations. The experiment was conducted on oil off-shore platform called Rospo Mare B. This structure is located in the area in front of Molise coast line (Italy, Adriatic Sea), characterized by a depth of about 77 m and a bathymetry between 65 and 80 m. The Mosselmonitor® works with eight mussels connected via specific sensors to PC for recording opening values of valves. A probe was installed inside the instrument to daily control of water pH, dissolved oxygen, salinity and temperature. Water samples are weekly analyzed for heavy metals, organochlorine pesticide and suspended matter. During the entire observation period, closure alarms were predominantly detected (99.9%) and a decrease of 65% in alarms maximum duration was recorded from the fifth week. During the first month, none changes in water physico-chemical parameters were observed so that affect the bivalves behavior. The only chemical parameter steadily detected in water was copper; its average concentrations were of 10 ppb. Detected alarms were not comparable to those recorded in the first month: this observation could be explained considering that mussels will be adapted to copper constant presence.
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Lemberger, Marcus, James Stockley, and Tim Gibbons. "Browse to Bonaparte stratigraphic evaluation." APPEA Journal 53, no. 2 (2013): 483. http://dx.doi.org/10.1071/aj12094.
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After an initial 2010 stratigraphic, depositional environment and facies determination study of 75 wells in the Browse Basin, TGS has pushed this high-resolution project north into the Bonaparte Basin area. The study incorporates a further 165 wells located across the Ashmore Platform, Vulcan Sub-basin, Londonderry High, Malita and Calder Grabens, Sahul and Flamingo synclines, Laminara and Flamingo highs, Sahul Platform, Troubadour Terrace, and offshore Petrel Sub-basin areas. This multi-basin project has combined all the selected relevant public data into one interpretation study and is delivered in an integrated environment—wells are standardised and sequences interpreted. Once depositional environment and facies are allocated, multi-element maps are produced showing how the basin environments change through time and structural evolution. Stratigraphic interpretation has determined 37 sequences and 32 associated facies maps. Both Browse Basin (140,000 km2) and Bonaparte Basin (270,000 km2) are relatively less explored and at different ages in their exploration life-cycle. Both have proved to be oil and gas bearing across numerous different stratigraphic ages with a wide range of trapping and reservoir methods. This study aims to further aid North West Shelf exploration by delineating, among other facets, the presence or otherwise of rocks with reservoir and seal potential and by identifying structural elements such as the Petrel Sub-basin salt diapirs. This regional well data stratigraphic approach has been used across all the UK and Norway continental shelf hydrocarbon provinces. TGS sees the Australian North West Shelf as a province where this approach will further assist sub-surface understanding, and hence exploration success.
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Piquet, Rosélia Périssé da Silva. "O lugar do regional na indústria do petróleo." Revista Brasileira de Estudos Urbanos e Regionais 14, no. 1 (May 31, 2012): 51. http://dx.doi.org/10.22296/2317-1529.2012v14n1p51.
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O presente texto tem o propósito de discutir uma questão candente do debate energético da atualidade: um país seria abençoado por dispor de ricas reservas de petróleo e gás ou as fartas rendas provenientes de sua exploração produziriam uma espécie de “maldição” por limitarem a expansão de outros setores produtivos? A avaliação dos impactos dessa indústria é complexa, por existirem profundas distinções entre os processos de mudança que é capaz de provocar no plano nacional ou nas áreas em que se localiza. O texto é centrado na análise das fases de exploração e produção, onde ocorrem os maiores investimentos e se registram os mais significativos efeitos multiplicadores dessa indústria, tendo como referência o caso brasileiro. Existindo ainda no Brasil a peculiaridade das principais ocorrências serem na plataforma continental marítima, com marcada concentração da produção na Bacia de Campos, os impactos regionais da indústria são analisados tomando-se o caso da região Norte Fluminense como base empírica de referência. Palavras-chave: indústria de petróleo; investimentos petrolíferos; impactos regionais; Norte Fluminense; efeitos multiplicadores. Abstract: This text aims to discuss a weighty issue of the current energy debate: having rich reserves of oil and gas would be a blessing for a country or the hefty revenues of the exploration of these resources would produce some kind of “curse” by limiting the expansion of other productive sectors? The evaluation of the impacts of this industry is complex for existing deep differences between the changing processes that they can be able to cause in a national level or in the areas they are located in. The text is focused in the phases of exploration and production, in which occur the major investments and are noticed the most significant multiplying effects of this industry, having the Brazilian case as reference. As Brazil has the peculiarity of having the main occurrences in the offshore continental platform, with stressed concentration of the production in Campos Bay, the regional impacts of the industry are analyzed having the case of the North of Rio de Janeiro State as an empirical database of reference. Keywords: oil industry; oil investments; regional impacts; North of Rio de Janeiro State; multiplying effects.
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Torres, Sarah Barrón, Luiz Bevilacqua, Fernando Pellon de Miranda, and Carlos Henrique Beisl. "DETECTION OF SEEPAGE SLICKS IN CANTARELL COMPLEX (GULF OF MEXICO) USING POLARIMETRIC SAR DATA OF RADARSAT-2." Revista Brasileira de Geofísica 36, no. 2 (July 4, 2018): 137. http://dx.doi.org/10.22564/rbgf.v36i2.928.
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ABSTRACT. The occurrence of oil seeps on the sea surface from active petroleum systems has been extensively documented by radar imaging using SAR (Synthetic Aperture Radar). Polarimetry is consolidating in the oil industry as a sophisticated technique for the study of marine seeps. The Cantarell Complex, located in the Gulf of Mexico, is currently the most prolific natural seep site in the world. This paper aims to add to the discussion on the physical properties of seepage slicks from full polarimetric data (quad-pol) from RADARSAT-2 satellite. The fact that the research was based on two images (ID#02 and ID#04) acquired at the same place and with the same mode of operation but with a time lapse between acquisitions and different incidence angles allowed to evaluate the influence of the imaging geometry on target signatures. To this end, samples of four classes (sea, offshore platform, oil and false targets) were collected. The data of the samples were afterwards shown in graphs and plotted in the classification plan of Cloude & Pottier – entropy (H) vs. alpha angle (¯α) – for backscattering mechanism analysis. Such elements made it possible to certify that (i) the sea is a Bragg-type surface regardless the incidence angle, (ii) platforms have double-bounce scattering, but small incidence angles are inadequate for their characterization, (iii) false targets (associated in ID#02 to regions of little wind) are moderately random/quasi deterministic surfaces, and (iv) oil behaves either as a Bragg (19.0◦–22.7◦ incidence angle range) or as a random/anisotropic surface (33.7◦–36.7◦ incidence angle range). Keywords: H-¯α diagram, incidence angle, radar imaging, marine seeps.RESUMO. A ocorrência de exsudações de óleo na superfície do mar a partir de sistemas petrolíferos ativos vem sendo extensivamente documentada por imageamento utilizando sistemas SAR (Synthetic Aperture Radar). A polarimetria está se consolidando na indústria do petróleo como uma técnica sofisticada para o estudo de seeps marinhos. O Complexo de Cantarell, situado no Golfo do México, é atualmente o local de exsudação natural de óleo mais prolífico do globo terrestre. Este trabalho visou contribuir com a discussão acerca das propriedades físicas de escapes de óleo a partir dos dados polarimétricos completos (quad-pol) do satélite RADARSAT-2. O fato da pesquisa valer-se de duas imagens (ID#02 e ID#04) adquiridas no mesmo local e modo de operação, mas com intervalo entre as aquisições e diferentes ângulos de incidência, possibilitou avaliar a influência da geometria de imageamento na assinatura dos alvos. Com esse propósito, foram geradas amostras de quatro classes (mar, plataforma, óleo e falso alvo), que tiveram os dados posteriormente relacionados em gráficos e no plano de classificação de Cloude & Pottier – entropia (H) vs. ângulo alfa (¯α) – para análise do mecanismo de espalhamento. Tais elementos permitiram atestar que (i) o mar é uma superfície do tipo Bragg independente do ângulo de incidência, (ii) as plataformas têm espalhamento double-bounce, mas baixos ângulos são inadequados para sua caracterização, (iii) falsos alvos (associados em ID#02 a regiões de baixo vento) são superfícies moderadamente aleatórias/quase determinísticas, e (iv) o óleo comporta-se ou como Bragg (19,0◦–22,7◦), ou como uma superfície aleatória/anisotrópica (33,7◦–36,7◦).Palavras-chave: Diagrama H-¯α, ângulo de incidência, imagem de radar, seeps marinhos.
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LIU, Hongbing, Guoming CHEN, Tao LYU, Hong LIN, Benrui ZHU, and Ao HUANG. "Wind-induced response of large offshore oil platform." Petroleum Exploration and Development 43, no. 4 (August 2016): 708–16. http://dx.doi.org/10.1016/s1876-3804(16)30083-0.
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Sage, Drew, Michael Bieganski, and Andrew Grant. "Lean offshore platform design." APPEA Journal 57, no. 2 (2017): 635. http://dx.doi.org/10.1071/aj16077.
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Current industry practices of prescriptive design and duplication of previous work on offshore oil and gas facilities have often caused relatively simple design requirements to be executed as large, maintenance-heavy, expensive platforms. The question of whether equipment is technically justified is rarely asked, and the potential benefits of minimised systems are rarely realised. By adopting lean design thinking, where all equipment must be technically justified as essential to operation before being included on the platform, the benefits are twofold. First, personal safety is improved because less equipment is required to be maintained offshore, meaning fewer offshore man-hours. Second, significant cost savings can be achieved because less offshore equipment means smaller platforms. This paper outlines the design, operating, manning and maintenance philosophies that form the basis for lean design thinking, and the effect this thinking has on both offshore man-hours and facility costs. Two case studies have been undertaken to evaluate the quantifiable differences between conventional platform design and lean platform design. Aker Solutions’ Lean Semi has been compared with a conventional semisubmersible platform to show that substructure weight savings of up to 30% are achievable; in addition, Aker Solutions’ Hybrid Compression Facility has been compared with a conventional compression platform to show that topsides weight savings of more than 50% are achievable.
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Valenti, Michael. "A Drier Way To Clean Turbines." Mechanical Engineering 120, no. 03 (March 1, 1998): 98–100. http://dx.doi.org/10.1115/1.1998-mar-7.
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A high-pressure injection system that needs less water to clean gas turbines than conventional methods can reduce equipment maintenance costs for aircraft, offshore platforms, and power plants. Gas Turbine Efficiency (GTE) in Jarfalla, Sweden, has developed a high-pressure injection system that cleans turbines using atomized droplets and needs 90 percent less liquid than previous methods. With this technique, the operators of offshore oil platforms, power plants, refineries, and aircraft in several countries are reducing the purchase costs of new fluids, the disposal costs of spent cleaning fluids, and maintenance downtime. In creating their washing system, designers considered the differences in cleaning aviation and stationary engines. The turbine-washing system is available in mobile versions for aircraft engines and permanently installed versions, for the off-line cleaning of stationary turbines. GTE also designed two models to serve the very small and very large turbines. The GTE 30 A services the small turbines, ranging from 0.5 to 10 megawatts, that are used in industrial, power-generation, marine, and test-cell applications as well as turboprop aircraft, turbofan craft, and helicopters.
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Ervina Efzan, Mohd Noor, and S. Kesahvanveraragu. "Review on Pipelines in Offshore Platform Processing System." Applied Mechanics and Materials 695 (November 2014): 684–87. http://dx.doi.org/10.4028/www.scientific.net/amm.695.684.
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Pipelines are essential for transporting energy utilities such as oil, natural gas and coal for the nation. Similarly, pipelines are the only medium installed at offshore region to convey oil, gas, chemicals and water. Currently, corrosion is being a major problem for offshore pipeline occurrences around the world. Hence, this paper discussed on the pipelines in offshore platform and the corrosion of corresponding pipeline materials.
Dissertations / Theses on the topic "Mars (Offshore oil platform)"
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ROCHA, CAMILA CAMPOS MARIN. "THERMODYNAMICS ANALYSIS FOR CO2 CAPTURE AND REINJECTION FROM GAS PROCESSING IN AN OFFSHORE OIL AND GAS PRODUCTION PLATFORM." PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIRO, 2015. http://www.maxwell.vrac.puc-rio.br/Busca_etds.php?strSecao=resultado&nrSeq=26612@1.
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PETRÓLEO BRASILEIRO S. A.O presente trabalho apresenta uma análise termodinâmica dos processos de captura e reinjeção de CO2, que se tornaram indispensáveis à produção de óleo e gás nas instalações de petróleo offshore no Brasil desde o início do desenvolvimento dos campos do pré-sal. O petróleo dos reservatórios da camada pré-sal da Bacia de Santos apresenta uma particularidade importante, quando comparado com o petróleo dos campos pós-sal do Brasil. A composição do gás natural do pré-sal apresenta grande teor de CO2, podendo ultrapassar 15 por cento, enquanto que a composição típica do gás natural dos campos pós-sal apresenta teor de CO2 abaixo de 1 por cento. Isto exige que equipamentos e operações de processamento do petróleo sejam mais complexos, pois devem ser capazes de: (i) separar o CO2 do gás produzido, (ii) comprimir as correntes de CO2 e de gás natural com baixo teor de CO2 e enviá-las para seus diversos destinos (reinjeção, gas lift, exportação etc.). Consequentemente, com a introdução destes novos processos para captura e injeção do CO2, houve aumento da demanda energética nestas unidades. Este trabalho visa estudar os processos envolvidos na captura e reinjeção de CO2, uma vez que utilizam novas técnicas e tecnologias pouco divulgadas na literatura acadêmica. Busca, também, contribuir para o cálculo do consumo adicional energético nas plataformas de produção de petróleo offshore, tipo FPSO, devido à inclusão da captura e reinjeção de CO2. E, por último, apresenta uma breve análise do impacto ambiental que tais processos podem causar, considerando a emissão de poluentes atmosféricos, como CO2 e CH4, principalmente.
This work presents a thermodynamic analysis of carbon dioxide (CO2) capture and reinjection processes, which have become indispensable for oil and gas production, particularly in the Brazilian offshore pre-salt fields. In comparison to the Brazilian post-salt reservoir, the petroleum from the Santos Basin pre-salt reservoir has a much larger CO2 content, which can exceed 15 percent, as opposed to less than 1 percent in the post-salt case. This peculiarity demands more complex operational equipment and processes that: (i) separate the CO2 from the produced gas; (ii) compress both the CO2 and low content CO2 natural gas streams and (iii) direct them to their subsequent destinations (reinjection, gas lift, exportation etc.). Consequently, these new capture and injection processes increase the energy demand on these production units. The present study aims to describe the processes involved in the CO2 capture and reinjection, since there is a lack of references in the literature about these new techniques and technology. Furthermore, it contributes to the evaluation of the additional energy consumption of an offshore Floating, Production, Storage and Offloading unit (FPSO), due to the inclusion of processes related to the capture and reinjection of CO2. Finally, a brief analysis is made on the environmental impact from these processes, considering the additional emission of atmospheric pollutants such as CO2 and CH4.
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Okara, Ikpe Chikwe. "Harmonic domain modelling and analysis of the electrical power systems of onshore and offshore oil and gas field /platform." Thesis, University of Glasgow, 2014. http://theses.gla.ac.uk/5593/.
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This thesis first focuses on harmonic studies of high voltage cable and power line, more specifically the harmonic resonance. The cable model is undergrounded system, making it ideal for the harmonics studies. A flexible approach to the modelling of the frequency dependent part provides information about possible harmonic excitations and the voltage waveform during a transient. The power line is modelled by means of lumped-parameters model and also describes the long line effect. The modelling depth and detail of the cable model influences the simulation results. It compares two models, first where an approximate model which make use of complex penetration is used and the second where an Bessel function model with internal impedance is used. The both models incorporate DC resistance, skin effect and their harmonic performances are investigated for steady-state operating condition. The methods illustrate the impotance of including detailed representation of the skin effect in the power line and cable models, even when ground mode exists. The cable model exhibit lower harmonics comparable to overhead transmission lines due to strong influence of the ground mode. Due to the application of voltage source converter (VSC) technology and pulse width modulation (PWM) the VSC-HVDC has a number of potential advantages as compared with CSC-HVDC, such as short circuit current reduction, independent control of active power and reactive power, etc. With these advantages VSC-HVDC will likely be widely used in future oil and gas transmission and distribution systems. Modular multilevel PWM converter applies modular approach and phase-shifted concepts achieving a number of advantages to be use in HVDC power transmission. This thesis describes the VSC three-phase full-bridge design of sub-module in modular multilevel converter (MMC). The main research efforts focus on harmonic reduction using IGBTs switches, which has ON and OFF capability. The output voltage waveforms multilevel are obtained using pulse width modulation (PWM) control. The cascaded H-bridge (CHB) MMC is used to investigate for two-level, five-level, seven-level, nine-level converter staircase waveforms. The results show that the harmonics are further reduced as the sub-module converter increases. The steady-state simulation model of the oil platform for harmonic studies has been developed using MATLAB. In order to save computational time aggregated models are used. The load on the platforms consists of passive loads, induction motors, and a constant power load representing variable speed drives on the platforms. The wind farm consists of a wind turbine and an induction machine operating at fixed speed using a back-to-back VSC. Simulations are performed on system harmonics that are thought to be critical for the operation of the system. The simulation cases represent large and partly exaggerated disturbances in order to test the limitations of the system. The results show low loss, low harmonics, and stable voltage and current. With the developments of multilevel VSC technology in this thesis, multi-terminal direct current (MTDC) systems integrating modular multilevel converters at all nodes may be more easily designed. It is shown that self-commutated Voltage Source Converters (VSC) is more flexible than the more conventional Current Source Converter (CSC) since active and reactive powers are controlled independently. The space required by the equipment of this technology is smaller when compared to the space used by the CSCs. In addition, the installation and maintenance costs are reduced. With these advantages, it will be possible for several oil and gas production fields connected together by multi-terminal DC grid. With this development the platforms will not only share energy from the wind farms, but also provide cheaper harmonic mitigation solutions. The model of a multi-terminal hypothetical power system consisting of three oil and gas platforms and two offshore wind farm stations without a common connection to the onshore power grid is studied. The connection to the onshore grid is realized through a High Voltage Direct Current (HVDC) transmissions system based on Voltage Source Converter (VSC) technology. The proposed models address a wide array of harmonic mitigation solutions, i.e., (i) Local harmonic mitigation (ii) semi-global harmonic mitigation and (iii) global harmonic mitigation. In addition, a computationally-efficient technique is proposed and implemented to impose the operating constraints of the VSC and the host IGBT-PWM switches within the context of the developed harmonic power flow (HPF). Novel closed forms for updating the corresponding VSC power and voltage reference set-points are proposed to guarantee that the power-flow solution fully complies with the VSC constraints. All the proposed platform models represent (i) the high voltage AC/DC and DC/AC power conversion applications under balanced harmonic power-flow scenario and (ii) all the operating limits and constraints of the nodes and its host modular converter (iii) three-phase VSC coupled IGBT-PWM switches.
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Bidgoli, Ali Allahyarzadeh. "Simulation and optimization of primary oil and gas processing plant of FPSO operating in pre-salt oil field." Universidade de São Paulo, 2018. http://www.teses.usp.br/teses/disponiveis/3/3150/tde-13122018-150547/.
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FPSO (Floating, Production, Storage e Offloading) plants, similarly to other oil and gas offshore processing plants, are known to be an energy-intensive process. Thus, any energy consumption and production optimization procedures can be applied to find optimum operating conditions of the unit, saving money and CO2 emissions from oil and gas processing companies. A primary processing plant of a typical FPSO operating in a Brazilian deep-water oil field on pre-salt areas is modeled and simulated using its real operating data. Three operation conditions of the oil field are presented in this research: (i) Maximum oil/gas content (mode 1), (ii) 50% BSW oil content (mode 2) and (iii) high water/CO2 in oil content (mode 3). In addition, an aero-derivative gas turbine (RB211G62 DLE 60Hz) with offshore application is considered for the heat and generation unit using the real performance data. The impact of eight thermodynamic input parameters on fuel consumption and hydrocarbon liquids recovery of the FPSO unit are investigated by the Smoothing Spline ANOVA (SS-ANOVA) method. From SS-ANOVA, the input parameters that presented the highest impact on fuel consumption and hydrocarbon liquids recovery were selected for an optimization procedure. The software Aspen HYSYS is used as the process simulator for the screening analysis process and for the optimization procedure, that consisted of a Hybrid Algorithm (NSGA-II +SQP method). The objective functions used in the optimization were the minimization of fuel consumption of the processing and utility plants and the maximization of hydrocarbon liquids recovery. From SS-ANOVA, the statistical analysis revealed that the most important parameters affecting the fuel consumption of the plant are: (1) output pressure of the first control valve (P1); (2) output pressure of the second stage of the separation train before mixing with dilution water (P2); (3) input pressure of the third stage of separation train (P3); (4) input pressure of dilution water (P4); (5) output pressure of the main gas compressor (Pc); (6) output petroleum temperature in the first heat exchanger (T1); (7) output petroleum temperature in the second heat exchanger (T2); (8) and dilution water temperature (T3). Four input parameters (P1, P2, P3 and Pc), three input parameters (P3, Pc and T2) and three input parameters (P3, Pc and T2) correspond to 96%, 97% and 97% of the total contribution to fuel consumption for modes 1, 2 and 3, respectively. For hydrocarbon liquids recovery of the plant: Four input parameters (P1,P2,P3 and T2), three input parameters (P3, P2 and T2) and three input parameters (P3, P2 and T2) correspond to 95%, 97% and 98% of the total contribution to hydrocarbon liquids recovery for modes 1, 2 and 3, respectively. The results from the optimized case indicated that the minimization of fuel consumption is achieved by increasing the operating pressure in the third stage of the separation train and by decreasing the operating temperature in the second stage of the separation train for all operation modes. There were a reduction in power demand of 6.4% for mode 1, 10% for mode 2 and 2.9% for mode 3, in comparison to the baseline case. Consequently, the fuel consumption of the plant was decreased by 4.46% for mode 1, 8.34% for mode 2 and 2.43% for mode 3 , when compared to the baseline case. Moreover, the optimization found an improvement in the recovery of the volatile components, in comparison with the baseline cases. Furthermore, the optimum operating condition found by the optimization procedure of hydrocarbon liquids recovery presented an increase of 4.36% for mode 1, 3.79% for mode 2 and 1.75% for mode 3 in hydrocarbon liquids recovery (stabilization and saving), when compared to a conventional operating condition of their baseline.As plantas FPSO (Floating, Production, Storage e Offloading) , assim como outras plataformas de processamento offshore de petróleo e gás, são conhecidas por terem processos com uso intensivo de energia. Portanto, qualquer aplicação de procedimentos de otimização para consumo de energia e/ou produção pode ser útil para encontrar as melhores condições de operação da unidade, reduzindo custos e emissões de CO2 de empresas que atuam na área de petróleo e gás. Uma planta de processamento primário de uma plataforma FPSO típica, operando em um campo de petróleo em águas profundas brasileiras e em áreas do pré-sal, é modelada e simulada usando seus dados operacionais reais: (i) Teor máximo de óleo / gás (modo 1), (ii) 50 % de teor de BSW no óleo (modo 2) e (iii) teor elevado de água / CO2 no óleo (modo 3). Além disso, uma turbina a gás aeroderivativa (RB211G62 DLE 60Hz) para aplicação offshore é considerada para a unidade de geração da potência eletrica e calor, através dos seus dados reais de desempenho. O impacto de oito parâmetros termodinâmicos de entrada no consumo de combustível e na recuperação de hidrocarbonetos líquidos da unidade FPSO são investigados pelo método SS-ANOVA (Smoothing Spline ANOVA). A partir do SS-ANOVA, os parâmetros de entrada que apresentaram o maior impacto no consumo de combustível e na recuperação de hidrocarbonetos líquidos foram selecionados para aplicação em um procedimento de otimização. Os processos de análise da triagem (usando SS-ANOVA) e de otimização, que consiste em um Algoritmo Híbrido (método NSGA-II + SQP), utilizaram o software Aspen HYSYS como simulador de processo. As funções objetivo utilizadas na otimização foram: minimização do consumo de combustível das plantas de processamento e utilidade e a maximização da recuperação de hidrocarbonetos líquidos. Ainda utilizando SS-ANOVA, a análise estatística realizada revelou que os parâmetros mais importantes que afetam o consumo de combustível da planta são: (1) pressão de saída da primeira válvula de controle (P1); (2) pressão de saída do segundo estágio do trem de separação (e antes da mistura com água de diluição) (P2); (3) pressão de entrada do terceiro estágio do trem de separação (P3); (4) pressão de entrada da água de diluição (P4); (5) pressão de saída do compressor principal de gás (Pc); temperatura de saída de petróleo no primeiro trocador de calor (T1); (7) temperatura de saída de petróleo no segundo trocador de calor (T2); e (8) temperatura da água de diluição. Os parâmetros de entrada de P1, P2, P3 e Pc correspondem a 95% da contribuição total para a recuperação de hidrocarbonetos líquidos da planta para os modos 1. Analogamente, os três parâmetros de entrada P3, Pc e T2 correspondem a 97% e 98% do contribuição total para o consumo de combustível para os modos 2 e 3, respectivamente. Para a recuperação de hidrocarbonetos líquidos da plant, os parâmetros de entrada de P1, P2, P3 e T2 correspondem a 96% da contribuição total para o consumo de combustível para o modo 1. Da mesma forma, os três parâmetros de entrada P3, P2 e T2 correspondem a 97% e 97% da contribuição total para a recuperação de hidrocarbonetos líquidos para os modos 2 e 3, respectivamente. Os resultados do caso otimizado indicaram que a minimização do consumo de combustível é obtida aumentando a pressão de operação no terceiro estágio do trem de separação e diminuindo a temperatura de operação no segundo estágio do trem de separação para todos os modos de operação. Houve uma redução na demanda de potência de 6,4% para o modo 1, 10% para o modo 2 e 2,9% para o modo 3, em comparação com o caso base. Consequentemente, o consumo de combustível da planta foi reduzido em 4,46% para o modo 1, 8,34% para o modo 2 e 2,43% para o modo 3, quando comparado com o caso base. Além disso, o procedimento de otimização identificou uma melhora na recuperação dos componentes voláteis, em comparação com os casos baseline. A condição ótima de operação encontrada pelo procedimento para otimização da recuperação de hidrocarbonetos líquidos apresentou um aumento de 4,36% para o modo 1, 3,79% para o modo 2 e 1,75% para modo 3, na recuperação líquida de hidrocarbonetos líquidos (e estabilização), quando comparado com as condições operacionais convencionais das suas baseline.
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Papa, Fabio Del. "Modelos tecnológicos para planejamento e gestão operacional em terminais especializados em apoio logístico para operações offshore." Universidade de São Paulo, 2013. http://www.teses.usp.br/teses/disponiveis/3/3143/tde-21022017-093145/.
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O presente trabalho tem como objetivo apresentar uma descrição dos modelos tecnológicos aplicáveis em terminais \"OffShore\", especializados em apoio logístico às unidades marítimas de extração de petróleo. Com a expansão do setor petrolífero brasileiro, o apoio logístico ganhou uma importância considerável, tendo em vista o aumento no número de unidades marítimas e a distâncias, superiores a 200 km da costa brasileira. Os terminais \"OffShore\" desempenham um papel importante no elo de transição entre as unidades marítimas e o transporte terrestre e precisam buscar eficiência e rapidez nos seus serviços para atingir índices de produtividade compatíveis com expectativa de aumento na movimentação de carga. A inserção da inteligência computacional permite a otimização dos tempos de espera dos caminhões, a diminuição do tempo de operação das embarcações e do tempo de atendimento dos caminhões, das taxas de ocupação dos equipamentos e otimiza o arranjo da carga no estoque. Um terminal \"OffShore\" é um sistema com vários componentes interligados entre si, consequentemente a ineficiência de um componente interfere em toda cadeia logística do terminal.The current work aims to show a description of the technological models applicable to OffShore terminals, specialized in logistic support to the maritime units of oil extraction. With the expansion of the Brazilian oil industry, logistics has gained considerable importance in view of the increase in the number of marine units and distances greater than 200 km from the Brazilian coast. The Offshore terminals play an important role in link units transition between sea and land transport, and must seek efficiency and speed in its services to achieve productivity levels consistent with expected increase in cargo handling. The integration of computational intelligence enables optimization of waiting times of trucks, reducing the operating time of vessels and the service time of the trucks, the occupancy rates of the equipment and the arrangement optimizes the load on the stock. A Offshore terminal is a system with several components interconnected, hence the inefficiency of one component affects the entire logistics chain in the terminal.
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Durand, Alice. "L'exploration et l'exploitation des hydrocarbures en mer et la protection de l'environnement." Thesis, Grenoble, 2014. http://www.theses.fr/2014GREND015.
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L’explosion de la plateforme de forage Deepwater Horizon qui s’est produite dans le Golfe du Mexique en 2010, à l’origine d’une catastrophe écologique sans précédent dans l’histoire des Etats-Unis, nous a conduit à nous interroger sur l’encadrement international de l’activité d’exploration et d’exploitation des hydrocarbures en mer et la protection de l’environnement. Parce que cette activité qui est exercée sur le plateau continental des états, génère des pollutions opérationnelles et accidentelles, et parce que la pollution marine ne connait pas les frontières, l’encadrement international d’une telle activité est de rigueur. L’activité qui a débuté à la fin du XIXe siècle a connu un véritable essor vers les années 70. A ce moment là, les états prennent conscience de la nécessité de protéger l’environnement. Dans le même temps, un régime international encadrant l’activité se développe entre les années 70 et les années 90. Se distingue alors le régime de prévention du régime de réaction. Dans un premier temps l’activité doit répondre à des exigences de prévention. Il n’existe toutefois pas un instrument universel exclusivement dédié à cette activité, de telle sorte que l’on observe un éclatement du régime au travers d’instruments directement applicables à vocation universelle et régionale, complétés par des instruments indirectement applicables relatifs à la protection de l’environnement. Malgré cet éclatement il en ressort que les principaux aspects constituant le cycle de vie de l’activité, partant de la délivrance de permis d’exploration et d’exploitation au démantèlement des plateformes en passant par le contrôle de l’activité sont relativement bien encadrés. Mais malgré cet encadrement nous ne sommes pas à l’abri de la survenance d’une pollution contre laquelle il faudra lutter.Dans ce second temps les états ont donc développé un régime de réaction en réponse aux pollutions opérationnelles et accidentelles. Concernant les pollutions opérationnelles, l’on voit en marge des régimes de prévention déjà existants et imposant certains seuils, se dessiner une lutte empirique contre ces pollutions, essentiellement à l’échelle régionale. Les états prennent conscience que les seuils de pollutions opérationnelles doivent être indéniablement plus contraignants. Concernant la lutte contre les pollutions accidentelles, les états disposent d’un régime international relativement satisfaisant puisqu’une série d’instruments prévoit les mesures imposées aux états que ces derniers doivent prendre en cas de survenance d’une pollution mais surtout parce qu’un instrument universel est dédié à cette problématique. L’existence d’un tel régime ne signifie par pour autant que les états doivent s’en contenter et doivent de cette manière en permanence faire évoluer le droit en vue d’un meilleur encadrement, telle qu’a su le faire l’Union européenne en adoptant en 2013 sa directive sur les accidents majeursThe deepwater Horizon oil rig explosion in 2010 in the Gulf of Mexico was the most important ecological catastrophe of the United States of America. This event inspired us to study the current international law about the hydrocarbon exploration and exploitation at sea and the protection of the environment. Because this activity takes place on the continental shelf it leads to operational and accidental pollutions, because marine pollution does not have frontiers, therefore legal international control of this activity is necessary.The activity which begun at the end of the nineteenth century, knew a real development around the 70's. At that moment, States became aware of the necessity to protect the environment. At the same time, an international settlement supervising the activity is emerging from the 70's to the 90's. Thus we can distinguish the prevention settlement from the react settlement. First of all the activity must respond to the prevention requirements. Notwithstanding, there is no universal treaty exclusively dedicated to this activity. That is why we do observe a splited settlement through universal and regional treaties directly applicable, completed by treaties indirectly applicable relating to environmental protection. Despite this splitting, we observe that principal aspects constituting the life cycle of the activity, from exploration and exploitation delivery permitted to decommissioning of paltforms, are well controled.Despite this control, a pollution can occur against which one we have to fight.That is why in the second time States developped a react settlement in response to the operational and accidental pollutions. About operational pollutions, we observe around the current preventional settelement which sets limits, developing some new limits through an empirical struggle, essentially at the regional level. States become aware that the limits imposed for operational pollution have to be more restrictive.With reference to the accidental pollutions, a current international settlement is quite satisfactory since various treaties and particularly an universal treaty, decree measures to States, which they fullfil if pollutions occure. This kind of instrument do not significate that States do not have to make the law progress. Indeed the law needs to evoluate permanentaly that is why UE adopted a directive about major accidents.At the same time react settlement not only means fighting pollution but also identifying the liable of the pollution and repare the damage, specifically the per se ecological damage
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Nassif, Alaa Abdullah. "Organisational and social aspects, specific safety measures, cultural conditions impact on risk sources control, and general safety on manned offshore oil platform facilities in Saudi Arabia." Thesis, University of Salford, 2003. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.402046.
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Tabella, Gianluca. "Subsea Oil Spill Risk Management based on Sensor Networks." Master's thesis, Alma Mater Studiorum - Università di Bologna, 2019.
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This thesis consists of the evaluation of sensor-based risk management against oil spills using an underwater distributed sensor network. The work starts by highlighting the importance of having a performing leak detection system both from an environmental, safety and economic point of view. The case study is the Goliat FPSO in the Barents Sea which has to meet requirements dictated by Norwegian authorities to prevent oil spills. The modeled network is made of passive acoustic sensors monitoring the subsea manifolds. These sensors send their local 1-bit decision to a Fusion Center which takes a global decision on whether the leakage is occurring. This work evaluates how the choice of adapted Fusion Rules (Counting Rule and Weighted Fusion Rule) can affect the performances of the leak detection system in its current geometry. It will also be discussed how different thresholds, selected for a specific FR or sensor test, can change the system performance. The detection methods are based on statistical signal processing adapted to fit this application within the Oil&Gas field. The work also proposes some new leak localization methods developed so they can be coupled with the proposed leak detection methods, giving a coherent set of operations that the sensors and the FC must perform. Performances of detection techniques are assessed balancing the need for high values of True Positive Rate and Precision and low values of False Positive Rate using indexes based both on the ROC curve (like the Youden's Index) and on the PR curve (the F-scores). Whereas, performances of localization techniques will be assessed on their ability to localize the spill in the shortest time; if this is not possible, parameters like the difference between the estimated and the real leak position will be considered. Finally, some tests are carried out applying the different sets of proposed methods.
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Kalb, Benedikt Michael. "Digital transformaion in the oil and gas industry : how do unmanned aerial vehicles, specifically drones, contribute to improving the offshore inspection process of oil and gas platforms?" Master's thesis, 2019. http://hdl.handle.net/10400.14/29025.
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Regular inspections of oil and gas (O&G) platforms are vital for production, maintenance, safety, and the environment. Due to their location, offshore O&G facilities are exposed to hazardous and extreme conditions. In order to advance digitalization in the O&G sector, high-tech robots must be integrated. Traditional inspection methods, like Rope Access, Scaffolding, and Manned Helicopters imply significant challenges such as building scaffolding, sending inspection teams into hazardous environments, production downtime and high financial costs. Past research has identified how the introduction of unmanned aerial vehicles (UAVs) can meet the challenges by reducing costs, increasing safety conditions, increasing efficiency and improving accuracy. This dissertation presents the current state of research in the offshore O&G industry, identifies and quantifies cost and time factors. It compares the traditional inspection methods to the UAV inspection method by applying qualitative and quantitative methods of primary data gathering from industry expert interviews and secondary company data. This research shows that switching to UAV inspection allows a worldwide saving potential of
USD 12B and market potential of USD 13M per inspection cycle. The complete Visual Inspection, including Flare, Underdeck, and Drilling Derrick is on average seven times faster than traditional methods. Introducing UAV inspection improves safety, as drone pilots operate up to 500m away from high-risk areas on the platform. Combining high-tech drones and AI-based software allows to generate a huge amount of data and build complete 3D models which can be reproduced continuously to detect trends in the state of the platform and apply Predictive Maintenance.Inspeções regulares das plataformas de petróleo e gás (O&G) são vitais para a produção, manutenção, segurança e ambiente. Devido à sua localização, as instalações de O&G offshore estão expostas a condições extremas. Métodos tradicionais de inspeção (acesso por corda, andaimes, helicópteros tripulados) implicam desafios significativos: construção de andaimes, envio de equipas para ambientes perigosos, tempo de inatividade de produção, e altos custos financeiros. Pesquisas anteriores mostraram como a introdução de veículos aéreos não tripulados (UAVs) pode colmatar desafios: redução de custos, aumento de condições de segurança, de eficiência e de precisão. Esta dissertação apresenta o estado atual da pesquisa na indústria de O&G offshore, identifica e quantifica os fatores de custo e tempo, compara os métodos de inspeção tradicionais com o método de inspeção UAV, aplicando métodos qualitativos e quantitativos de coleção de dados primários de entrevistas com especialistas da indústria e dados secundários da empresa. Esta pesquisa mostra que mudar para inspeção UAV permite um potencial de economia mundial de USD 12B e potencial de mercado de USD 13M por ciclo de inspeção. A inspeção visual completa é, em média, sete vezes mais rápida do que os métodos tradicionais. A introdução da inspeção UAV melhora a segurança: os pilotos de drones operam até 500m de distância, na plataforma. A combinação de drones de alta tecnologia e software baseado em IA permite gerar uma elevada quantidade de dados e construir modelos 3D que podem ser reproduzidos continuamente para detetar tendências no estado da plataforma e aplicar a Manutenção Preditiva.
Books on the topic "Mars (Offshore oil platform)"
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Publications, Hart. Shell's Mars mission: A deepwater odyssey. Houston: Hart Publications, 1999.
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Pelletier, James Laurence. Offshore oil platform & support vessels, foreign. Augusta, Me: Marine Techniques, 1997.
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Pelletier, James Laurence. Offshore oil platform & support vessels, foreign. 2nd ed. Augusta, Me: Marine Techniques, 1998.
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Offshore oil platform & support vessels, foreign. Augusta, Me: Marine Techniques, 1996.
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Williams, Jack. Investigation of fatal rental crane support brace failure Main Pass Block 255 "A" platform, OCS-G 07825, May 5, 2002: Gulf of Mexico off the Louisiana coast. New Orleans: U.S. Dept. of the Interior, Minerals Management Service, Gulf of Mexico OCS Regional Office, 2002.
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(Canada), Royal Commission on the Ocean Ranger Marine Disaster. Report two : safety offshore Eastern Canada. Ottawa: The Royal Commission, 1985.
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Williams, Jack. Investigation of flash explosion and injuries, south Timbalier block 151, production platform OCS 00463, June 15, 2002, Gulf of Mexico, off the Louisiana coast. New Orleans: U.S. Dept. of the Interior, Minerals Management Service, Gulf of Mexico OCS Regional Office, 2003.
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Williams, Jack. Investigation of flash explosion and injuries, south Timbalier block 151, production platform OCS 00463, June 15, 2002, Gulf of Mexico, off the Louisiana coast. New Orleans: U.S. Dept. of the Interior, Minerals Management Service, Gulf of Mexico OCS Regional Office, 2003.
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Williams, Jack. Investigation of flash explosion and injuries, south Timbalier block 151, production platform OCS 00463, June 15, 2002, Gulf of Mexico, off the Louisiana coast. New Orleans: U.S. Dept. of the Interior, Minerals Management Service, Gulf of Mexico OCS Regional Office, 2003.
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International Workshop on Offshore Lease Abandonment and Platform Disposal: Technology, Regulation, and Environmental Effects (1996 New Orleans, La.). Proceedings: An International Workshop on Offshore Lease Abandonment and Platform Disposal--Technology, Regulation, and Environmental Effects : Doubletree Hotel, New Orleans, Louisiana, April 15, 16, and 17, 1996. Baton Rouge, LA: Center for Energy Studies, Louisiana State University, 1997.
Find full textBook chapters on the topic "Mars (Offshore oil platform)"
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Kilbane, John J. "Determining the Source of H2S on an Offshore Oil Production Platform." In Microbiologically Influenced Corrosion in the Upstream Oil and Gas Industry, 351–60. Boca Raton : Taylor & Francis, CRC Press, 2017.: CRC Press, 2017. http://dx.doi.org/10.1201/9781315157818-17.
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Sebastiani, G. "MARELAB — An advanced offshore laboratory platform for oceanological research and field testing of new underwater technologies." In The European Oil and Gas Conference, 399. Dordrecht: Springer Netherlands, 1991. http://dx.doi.org/10.1007/978-94-010-9844-1_53.
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do Nascimento, Alexandre Rocha, and Andréa Regina Nunes de Carvalho. "Evaluation of the Effects Produced by the Commissioning Procedures on Offshore Oil Platform Operability." In Operations Management for Social Good, 519–28. Cham: Springer International Publishing, 2019. http://dx.doi.org/10.1007/978-3-030-23816-2_51.
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Skovhus, Torben Lund. "Workflow of Transportation, Sampling, and Documentation of Topsides Pipework with a Leak from an Offshore Oil Platform." In Failure Analysis of Microbiologically Influenced Corrosion, 451–57. Boca Raton: CRC Press, 2021. http://dx.doi.org/10.1201/9780429355479-28.
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Duque, Santiago Echeverri, and Idriss El-Thalji. "Intelligent Maintenance Maturity of Offshore Oil and Gas Platform: A Customized Assessment Model Complies with Industry 4.0 Vision." In Engineering Assets and Public Infrastructures in the Age of Digitalization, 653–63. Cham: Springer International Publishing, 2020. http://dx.doi.org/10.1007/978-3-030-48021-9_73.
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Yeats, Philip A., B. A. Law, and T. G. Milligan. "The Distribution of Dissolved and Particulate Metals and Nutrients in the Vicinity of the Hibernia Offshore Oil and Gas Platform." In Produced Water, 147–61. New York, NY: Springer New York, 2011. http://dx.doi.org/10.1007/978-1-4614-0046-2_6.
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"multi(ple)-well (offshore) (oil drilling) platform." In Dictionary Geotechnical Engineering/Wörterbuch GeoTechnik, 899. Berlin, Heidelberg: Springer Berlin Heidelberg, 2014. http://dx.doi.org/10.1007/978-3-642-41714-6_133137.
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Samie, Naeim Nouri. "Disciplines Involved in Offshore Platform Design." In Practical Engineering Management of Offshore Oil and Gas Platforms, 25–212. Elsevier, 2016. http://dx.doi.org/10.1016/b978-0-12-809331-3.00002-8.
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Samie, Naeim Nouri. "Systems and Equipment for Offshore Platform Design." In Practical Engineering Management of Offshore Oil and Gas Platforms, 213–346. Elsevier, 2016. http://dx.doi.org/10.1016/b978-0-12-809331-3.00003-x.
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"The Feasibility of Wind and Solar Energy Application for Oil and Gas Offshore Platform." In Climate Change and the Future of Sustainability, edited by Y. Tiong, M. Zahari, S. Wong, and S. Dol, 281–96. Apple Academic Press, 2016. http://dx.doi.org/10.1201/b21182-18.
Full textConference papers on the topic "Mars (Offshore oil platform)"
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Ferraro, M., M. C. Fossi, S. Casini, and L. Marsili. "The Bio-Mare Project: Ecotoxicological Assessment of Mediterranean Offshore Platform Areas using Biomarkers." In SPE International Conference on Health, Safety, and Environment in Oil and Gas Exploration and Production. Society of Petroleum Engineers, 2004. http://dx.doi.org/10.2118/86713-ms.
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Pericard, Yaël, and Karl H. Halse. "Collision Study Between a Ship Section Moving Sideways and an Oil Platform." In ASME 2017 36th International Conference on Ocean, Offshore and Arctic Engineering. American Society of Mechanical Engineers, 2017. http://dx.doi.org/10.1115/omae2017-61799.
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Over the last decades, the need for overseas transportation of both people and goods has gradually increased. At the same time, several offshore activities as oil and gas exploration, wind power parks as well as fish farms have bloomed. As a consequence of the increased traffic and activities, the risk of accidents became noticeable. This paper presents a study of the collision between a Platform Supply Vessel (PSV) and an oil platform. Even if such accidents are seldom, their consequences are disastrous, for the ship owner as well as the oil-platform company. Beyond the economic consequences, some lives have been lost due to the ship - structure collisions. These problems are inducing to investigate the possibility of developing protective systems in order to save lives of the concerned persons. Structural impact analyses can be carried out to give a scientific foundation for an evaluation of the consequences of a possible collision. This study is based on Non-Linear Finite Element Analysis (NLFEA) of the interaction between the PSV and the platform. Due to heavy calculations, only the ship section located close to the crash zone has been modelled and additional masses have been included on each side of this section in order to get the correct ship inertia. These additional masses correspond to the mass of the remaining part of the ship structure. Moreover, the sideways ship motion is modelled with a prescribed initial velocity, and does not contain hydrodynamic response calculations. The NLFEA software package HyperWorks is used to perform the numerical simulations. As a way to reduce the consequences of a ship platform collision, a shock absorber called “crash box” is proposed mounted on the platform column to absorb the kinetic energy and thus decrease the effect in both ship and platform. 4 case studies are performed in order to compare the results with and without the crash box. Presented results are based on the deflection, resultant forces due to the contacts and absorption of the kinetic energy. The results demonstrate that penetration of the oil platform into the ship structure can be decreased by 96% if the crash box is used. Similar systems such as tires are currently used but this crash box should be investigated with an inner structure using “honeycomb” shape in order to maximise the absorption.
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Clauss, Gu¨nther F. "The Conquest of the Inner Space: Design and Analysis of Offshore Structures." In ASME 2008 9th Biennial Conference on Engineering Systems Design and Analysis. ASMEDC, 2008. http://dx.doi.org/10.1115/esda2008-59035.
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Spectacular missions to the moon, the Mars and to other planets of our solar system has boosted public attention to the outer space for the last five decades. During the same period mankind has also conquered the inner space — with fantastic innovations and fabulous inventions — however, hidden under the sea surface, and hence widely unnoticed. While searching for new promising oil and gas fields the offshore industry operates in water depths that have never been explored before. Production systems already reach down to 2000 m, and will probably conquer greater water depths during the next years. Extreme environmental conditions in addition to these enormous water depths call for special solutions. This paper deals with recent developments of offshore deepwater production technology, e.g. SPARs, TLPs, Compliant Towers and huge mono-buoys. After a short survey of the development in ocean engineering from the first shallow water platforms in the Gulf of Mexico in 1947 to today’s deepwater production systems off the Brasilian coast the paper summarizes the principles of platform dynamics in waves to illustrate the advantages of specific design characteristics.
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Sidarta, Djoni E., Ho-Joon Lim, Johyun Kyoung, Nicolas Tcherniguin, Timothee Lefebvre, and Jim O’Sullivan. "Detection of Mooring Line Failure of a Spread-Moored FPSO: Part 1 — Development of an Artificial Neural Network Based Model." In ASME 2019 38th International Conference on Ocean, Offshore and Arctic Engineering. American Society of Mechanical Engineers, 2019. http://dx.doi.org/10.1115/omae2019-96288.
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Abstract Artificial Intelligence (AI) has gained popularity in recent years for offshore engineering applications, and one such challenging application is detection of mooring line failure of a floating offshore platform. For most types of floating offshore platforms, accurately detecting any mooring line damage and/or failures is of great interest to their operators. This paper demonstrates the use of an Artificial Neural Network (ANN) model for detecting mooring line failure for a spread-moored FPSO. The ANN model representation, in terms of its input variables, is based on assessing when changes in a platform’s motion characteristics are in-fact indicators of a mooring line failure. The output of the ANN model indicates the status condition for the mooring lines (intact or failed). This ANN model only requires GPS / DGPS monitoring data and does not require data on the environmental conditions at the platform. Since the mass of an FPSO changes with the stored volume of oil, the vessel’s mass is also an input variable. The ANN training uses the results from numerical simulations of a spread-moored FPSO with fourteen mooring lines. The numerical simulations create the FPSO’s response to a range of metocean conditions for 360-degree directions, and they cover several levels of vessel draft (mass). Furthermore, the simulations cover both the intact mooring configuration and the full permutation where each of the fourteen mooring lines is modeled as broken at the top. The global performance analysis of the FPSO is presented in a different paper (Part 2 of these paper series). The training of the ANN model employs a back-propagation learning algorithm and an automatic method for determining the size of ANN hidden layers. The trained ANN model can detect mooring line failure, even for vessel draft (mass), sea states and environmental directions that are not included in the training data. This demonstrates that the ANN model can recognize and classify patterns associated with mooring line failure and separate such patterns from those associated with intact mooring lines under conditions not included in the original training data. This study reveals a great potential for using an ANN model to monitor the station keeping integrity of a floating offshore platform with changing storage, or mass status, and to detect mooring line failure using only the vessel’s mass and deviations in the platform’s motions derived from GPS / DGPS data.
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de Sousa, Fernando Jorge Mendes, Marcos Queija de Siqueira, Claudio Marcio Silva Dantas, Lui´s Volnei Sudati Sagrilo, and Isai´as Quaresma Masetti. "Riser Analysis of a New Dry Completion Concept for a Monocolumn Platform." In ASME 2011 30th International Conference on Ocean, Offshore and Arctic Engineering. ASMEDC, 2011. http://dx.doi.org/10.1115/omae2011-49864.
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In recent years, PETROBRAS has developed the concept of a monocolumn platform to be used as a floating production unit in deep and ultra-deep water oil fields. This platform, referred as MonoBR, is characterized by low heave and pitch induced motions, even in hurricane conditions, allowing its use as an alternative for locations such as Campos Basin and the Pre-Salt Area in Brazil, and also for the Gulf of Mexico. Despite their low vertical motions, this platform is not generally regarded as a dry completion unit. However, PETROBRAS and two public institutions in Brazil, UFRJ/COPPE and USP/POLI, have studied and designed an innovative mechanism to be installed in MonoBR, called Inverted Cup, which is a sliding floating body installed inside the MonoBR moonpool. In such way, the platform transmits only horizontal motions and rotations to the Inverted Cup; the heave responses of both bodies are decoupled. The Inverted Cup is then designed and dimensioned to receive dry completion X-mas trees and risers. The aim of this paper is to present the results of the riser analysis performed under this new concept — Inverted Cup system — to allow dry completion in the MonoBR. The environmental conditions refer to fields in the Gulf of Mexico and in the Tupi Field (Pre-Salt). The results point to a technically feasible mechanism to allow dry completion, according to adopted criteria.
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Halkyard, John, Rizwan Sheikh, Thiago Marinho, Shan Shi, and Matthew Ascari. "Current Developments in the Validation of Numerical Methods for Predicting the Responses of an Ocean Thermal Energy Conversion (OTEC) System Cold Water Pipe." In ASME 2014 33rd International Conference on Ocean, Offshore and Arctic Engineering. American Society of Mechanical Engineers, 2014. http://dx.doi.org/10.1115/omae2014-24636.
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Ocean Thermal Energy Conversion (OTEC) was a subject of intense research in the late 1970s and early 1980s in response to a historical jump in oil prices from the 1973 oil embargo. The principal author for this paper first met Prof. Paulling as a participant in a National Research Council (NRC) Panel to review OTEC Technology around 1982. Prof. Pauling had authored a frequency domain program to analyze the coupled response of a platform and OTEC pipe. The author was involved in model tests to validate the program. The United States (U.S.) Department of Energy (DoE) and National Oceanic and Atmospheric Administration (NOAA) had sponsored this work, along with the development of other numerical methods. Shortly after the NRC completed its review, oil prices fell and interest in renewable energy, including OTEC, evaporated. Fast forward to the 2000s, the price of oil skyrocketed again, and OTEC research saw a rebirth. Lockheed Martin and others have been working on new OTEC designs over the course of the last several years. As was the case thirty-five years ago, the cold water pipe remains a key technical challenge. A commercial scale OTEC plant requires a pipe diameter of about 10-meter (m) and a length of 1,000m to pump about half the average discharge of the Colorado River from the deep ocean to the surface and through heat exchangers. Because of the large effective mass of the CWP and entrained water, the dynamic response of the OTEC CWP and the platform can only be considered as a coupled system. This conclusion is not new, but is worth repeating and doubly important to consider when the supporting platform is a semi-submersible as opposed to a large water plane ship shaped vessel. A new generation of software is available to analyze the cold water pipe-platform responses, including the important effect of the fluid flow inside the pipe and the local effects at the connection of the pipe to the platform. The DoE and Lockheed Martin recently sponsored a 1:50 scale wave basin model test of a commercial OTEC platform with an elastically scaled model of a 10m pipe. The purpose of the test was to validate the use of current software for the large CWP diameters in the designs of a pilot or commercial systems in the near future. This paper will briefly review past work on the OTEC cold-water pipe and present the current state of the art in numerical modeling and the results of the model tests recently completed. It will include recommendations for further experimental and numerical work to be prepared for the future design of OTEC systems.
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Xia, Jinzhu, Quanming Miao, Nicholas Haritos, and Beverley Ronalds. "Hydroelastic Modeling of a Compliant Offshore Tower: Formulation." In ASME 2003 22nd International Conference on Offshore Mechanics and Arctic Engineering. ASMEDC, 2003. http://dx.doi.org/10.1115/omae2003-37278.
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Offshore oil and gas can be produced using a variety of platform types. One option, the compliant offshore tower, has proven to be an economic solution in moderately deep water (300–600m). In this paper, the wave-induced global dynamic responses of a compliant tower in wind, current and waves are studied in the context of fluid-structure interaction. A beam undergoing transverse and axial motion models the vertical member of the tower. The beam is supported by a linear-elastic torsional spring at the bottom end and a point mass and a buoyant chamber is located at the top free end. The fluid forces on the beam are modeled using the Morison equation while the hydrodynamic forces on the chamber are obtained based on the three-dimensional diffraction-radiation theory. By applying Hamilton’s variation principle, the equations of motion are derived for the coupled fluid-structure interaction system. The non-linear coupled system equations that emanate from this new approach can then be solved numerically in the time domain.
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Lamas, Francisco, Miguel A. M. Ramirez, and Antonio Carlos Fernandes. "Yaw Galloping of a TLWP Platform Under High Speed Currents by Analytical Methods and its Comparison With Experimental Results." In ASME 2017 36th International Conference on Ocean, Offshore and Arctic Engineering. American Society of Mechanical Engineers, 2017. http://dx.doi.org/10.1115/omae2017-61909.
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Flow Induced Motions are always an important subject during both design and operational phases of an offshore platform life. These motions could significantly affect the performance of the platform, including its mooring and oil production systems. These kind of analyses are performed using basically two different approaches: experimental tests with reduced models and, more recently, with Computational Fluid Dynamics (CFD) dynamic analysis. The main objective of this work is to present a new approach, based on an analytical methodology using static CFD analyses to estimate the response on yaw motions of a Tension Leg Wellhead Platform on one of the several types of motions that can be classified as flow-induced motions, known as galloping. The first step is to review the equations that govern the yaw motions of an ocean platform when subjected to currents from different angles of attack. The yaw moment coefficients will be obtained using CFD steady-state analysis, on which the yaw moments will be calculated for several angles of attack, placed around the central angle where the analysis is being carried out. Having the force coefficients plotted against the angle values, we can adjust a polynomial curve around each analysis point in order to evaluate the amplitude of the yaw motion using a limit cycle approach. Other properties of the system which are flow-dependent, such as damping and added mass, will also be estimated using CFD. The last part of this work consists in comparing the analytical results with experimental results obtained at the LOC/COPPE-UFRJ laboratory facilities.
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Kumar, Kundan, and R. M. Chandima Ratnayake. "Maintenance Regime Minimum (MRM): State of the Art — Maintaining Offshore Platforms Before Decommissioning." In ASME 2017 36th International Conference on Ocean, Offshore and Arctic Engineering. American Society of Mechanical Engineers, 2017. http://dx.doi.org/10.1115/omae2017-61271.
Full textAbstract:
It is a mandatory requirement to maintain offshore oil and gas (O&G) production and process platforms during the engineering down period (i.e. the period from the end of the design/operational life to decommissioning). Decommissioning of the offshore production and process (OP&PPs) involves cessation of operations, withdrawal of the facility from service, transformation into an out-of-service state, deactivation and removal. There are several energy sources (i.e. pressure, chemical substances, electrical and mechanical instrumentation, telecom equipment, navigation radar system, gravity, heat/cold, biological substances, etc.), which need to be maintained and/or deactivated until the platform is decommissioned. This manuscript first maps the current state of the art in relation to the maintenance of OP&PSs before decommissioning. Then, the ‘Maintenance Regime Minimum’ (MRM) approach is proposed to perform comparative analysis in order to identify and select the optimal maintenance hours within the decommissioning strategy, based on cost (e.g. man hours required), safety, and environmental challenges. The manuscript also illustrates how the MRM approach focuses on potential decommissioning alternatives in relation to the optimization of maintenance hours and challenges involved in different tags throughout the functional hierarchy. The results of a case study on two topside systems (i.e. in relation to two alternatives) are also presented.
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Syverud, Elisabet, Lars E. Bakken, Kyrre Langnes, and Frode Bjo̸rna˚s. "Gas Turbine Operation Offshore: On-Line Compressor Wash at Peak Load." In ASME Turbo Expo 2003, collocated with the 2003 International Joint Power Generation Conference. ASMEDC, 2003. http://dx.doi.org/10.1115/gt2003-38071.
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On-line compressor wash is discussed for a RB211 compressor driver running at peak load at the Statoil Heidrun offshore platform. The oil field’s economy is directly linked to oil production; however, the production rate is limited by driver and gas compressor capacity. From this perspective, the power output and gas turbine uptime become decisive economic factors. The economic potentials related to successful on-line washing are given. This work is based on a series of trials with on-line compressor washing over a two-year period. Results include effect of different on-line washing procedures and washing fluids. The field test campaign has shown no significant improvements with on-line compressor washing at peak load. Understanding the gas turbine performance deterioration is of vital importance. Trending of its deviation from the engine baseline (datum maps) facilitates load-independent monitoring of the gas turbine’s condition. Peak load turbine response to compressor deterioration is analyzed. Instrument resolution and repeatability are key factors that sometimes are more important than absolute accuracy in condition trending. As a result of these analyses, a set of monitoring parameters is suggested for effective diagnostics of compressor degradation in peak load operation. Avenues for further research and development are suggested as our understanding of the deterioration mechanisms at peak load remains incomplete.
Reports on the topic "Mars (Offshore oil platform)"
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Glenn, L. A., and J. Barker. Rarefaction Shock Wave Cutter for Offshore Oil-Gas Platform Removal Final Report CRADA No. TC02009.0. Office of Scientific and Technical Information (OSTI), September 2017. http://dx.doi.org/10.2172/1396196.
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