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1
Williamson, Paul E. "Managing technical advice for regulation : the case of petroleum exploration and production /." Canberra : University of Canberra, 2007. http://erl.canberra.edu.au/public/adt-AUC20070820.123307/index.html.
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Thesis (PhD) -- University of Canberra, 2007.<br>Thesis submitted to fulfil the requirements of the unit of Masters Thesis in Administration, and complete the requirements for the degree of Master of Arts in Administration, University of Canberra, July 2007. Bibliography: leaves 177-205.
2
Liadey, Dickson M. "Spatial Ontology for the Production Domain of Petroleum Geology." Digital Archive @ GSU, 2012. http://digitalarchive.gsu.edu/geosciences_theses/46.
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ABSTRACT
The availability of useful information for research strongly depends on well structured relationships between consistently defined concepts (terms) in that domain. This can be achieved through ontologies. Ontologies are models of the knowledge of specific domain such as petroleum geology, in a computer understandable format. Knowledge is a collection of facts. Facts are represented by RDF triples (subject-predicate-object). A domain ontology is therefore a collection of many RDF triples, which represent facts of that domain. The SWEET ontologies are upper or top-level ontologies (foundation ontologies) consisting of thousands of very general concepts. These concepts are obtained from of Earth System science and include other related concepts. The work in this thesis deals with scientific knowledge representation in which the SWEET ontologies are extended to include wider, more specific and specialized concepts used in Petroleum Geology. Thus Petroleum Geology knowledge modeling is presented in this thesis.
3
Shar, Abdul Majeed. "Petrophysical properties of fault rock : implications for petroleum production." Thesis, University of Leeds, 2015. http://etheses.whiterose.ac.uk/10434/.
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Faults can have significant impact on reservoir productivity. Understanding the factors that controls the fluid flow properties of fault rocks provides a sound basis to assess the impact of faults on reservoirs productivity. Therefore, different aspects that affect the fluid flow within siliciclastic fault formations were investigated in this research project. Fault rock samples from a number of locations were analysed including: (i) core samples from central and southern North Sea fields; (ii) and outcrop samples from the 90 Fathom fault, Northumberland, UK and Miri airport road exposure, Malaysia as well as the Hopeman fault from Invernesshire, UK. The impact of faults on fluid flow was assessed by integrating the data from QXRD analysis, microstructural examination, X-ray tomography, mercury porosimetry for pore size distribution, absolute and relative permeability measurements as well as capillary pressure tests. Single phase and multiphase flow properties which were conducted at a range of stresses are the most comprehensive collection of high quality fault rock data. The permeability measurements made using gas gave higher values than with brine, which in turn gave higher values that when measured using distilled water permeability. The differences in permeability could be the results of clay particles swelling; mobilisation and retaining within the confined pore throats, although these effects depend on the rock mineralogy and pore fluid composition. Moreover, the permeability stress sensitivity was investigated. The results showed that at low confining stresses the permeability of the fault rock core samples showed high sensitivity to stress, whereas at higher confining stresses the permeability was less pronounced to stress. This might be due to the core damage effects and the microfractures formed due to stress release, which were observed from SEM images. The pore radius calculated from gas slippage parameters at low confining pressures was in the same order of magnitude as the micro fracture width. The micro cracks could be easily closed due to stress increase hence resulted in reduction of permeability. Overall, the stress sensitivity of fault rocks from outcrop is less than that from core. This is consistent with the idea that stress sensitivity is mainly the result of the presence of grain boundary microfractures formed as core is brought to the surface. This indicates that permeability measurements made on outcrop samples may be more reliable. Another key finding was that the published permeability data (e.g. Fisher and Knipe, 2001) compared with present study data which is obtained at in-situ stress using formation compatible brines showed that the published data may not be inaccurate as the use of distilled water gives lower permeability than brines and low stresses resulted in higher permeability than in-situ stress measurements. Therefore, the results indicate that two different laboratory practices used in previous studies partially cancel each other out so that the existing data is yet valuable. The effective gas permeability were also measured at a range of stresses and it was observed that the samples with lower absolute permeabilities were more stress sensitive to stress than high permeable samples. The relative permeability results obtained were incorporated into a specific example of synthetic reservoir model. These suggested that faults formed within low permeability sands might act as a barrier to fluid flow.
4
Hamzah, Razali Bin. "Erosion-corrosion modelling of materials used in petroleum production." Thesis, Cranfield University, 1994. http://dspace.lib.cranfield.ac.uk/handle/1826/3630.
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Experimental erosion/corrosion modelling was performed on C-Mn steels and corrosion resistant alloys commonly used in petroleum production. A graded commercial sand of 50-30b pm size range, similar to sands produced from typical oil/gas fields was used to simulate the erosive medium. The experimental conditions such as the sand flux, particle velocity, pressure and temperature, were chosen based on typical field operating conditions for corrosion, erosion and erosion-corrosion tests imposed on the materials. The corrosion environment was created by feeding in CO2 gas with atomised water into the test chamber. A centrifugal erosion rig (45) with necessary modifications to suit wet and dry test conditions was used in the experiments. The rig was capable of generating over 150 m/s particle velocity and could operate at high temperatures to generate consistent results. Results show that (a) there was a soft thin layer of corrosion products formed on the C-Mn specimens even at 20°C which can easily be removed by the impacting particles , (b) the scale growth rate kinetics were found to be parabolic and vary between 8x10-3 pun'/h to 50x10-3 iim2/h depending on the material and temperature, (c) the process of metal recession consists of the removal and regrowth of soft corrosion scale at low flux and low velocity, and erosion of substrate at high flux and high velocity, (d) the erosion-corrosion rates were found to vary between 2- 30 times over the pure erosion rates under the same conditions, depending on the sand flux, particle velocity and temperature. An existing computer simulation model (46) was used to simulate the conditions observed from the experiments. Some improvements were incorporated into the programme and the final model is capable of predicting the erosion and erosion-corrosion rates applicable to petroleum production.
5
Grodal, Evert Olaus. "Designing primary hydrocarbon production separation systems : a mathematical programming formulation." Thesis, Georgia Institute of Technology, 2000. http://hdl.handle.net/1853/12084.
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6
Li, Wenkai. "Modeling oil refinery for production planning, scheduling and economic analysis /." View abstract or full-text, 2004. http://library.ust.hk/cgi/db/thesis.pl?CENG%202004%20LI.
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7
Alvarado, Martin Guillermo. "Quantification of uncertainty during history matching." Texas A&M University, 2003. http://hdl.handle.net/1969/463.
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8
Johannessen, Kjetil. "Norwegian Continental Shelf Petroleum Pipe-It Integrator & Production Forecaster." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for petroleumsteknologi og anvendt geofysikk, 2012. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-19520.
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This thesis summarizes and concludes my master thesis research work. The main objective of this research was to develop a rigorous and generic forecast model for all the fields on the Norwegian Continental Shelf based on publically available data and free software. Pipe-It Norwegian Continental Shelf Integrator and Forecaster solution provides the opportunity to forecast oil and gas production rate and economics for all assets on the Norwegian Continental Shelf. The solution is automatically synchronized with an on line database, that is maintained by the Norwegian Petroleum Department. The solution currently contains 87 fields and handles thousands of application launches in parallel. The results can be filtered and aggregated for multiple engineering purposes, like the impact of new discoveries on future production rates and economics.
9
ALMEIDA, MAYRON RODRIGUES DE. "APPLYING GENETIC ALGORITHMS TO THE PRODUCTION SCHEDULING OF A PETROLEUM." PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIRO, 2001. http://www.maxwell.vrac.puc-rio.br/Busca_etds.php?strSecao=resultado&nrSeq=1740@1.
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COORDENAÇÃO DE APERFEIÇOAMENTO DO PESSOAL DE ENSINO SUPERIOR<br>O objetivo desta dissertação é desenvolver um método de
solução baseado em Algoritmos Genéticos (GAs) aliado a um
Sistema Baseado em Regras para encontrar e otimizar as
soluções geradas para o problema de programação da produção
de Óleos Combustíveis e Asfalto na REVAP (Refinaria do Vale
do Paraíba). A refinaria é uma planta multiproduto, com
dois estágios de máquinas em série - um misturador e um
conjunto de tanques, com restrição de recursos e operando
em regime contínuo. Foram desenvolvidos neste trabalho dois
modelos baseados em algoritmos genéticos que são utilizados
para encontrar a seqüência e os tamanhos dos lotes de
produção dos produtos finais. O primeiro modelo proposto
utiliza uma representação direta da programação da produção
em que o horizonte de programação é dividido em intervalos
discretos de um hora. O segundo modelo proposto utiliza uma
representação indireta que é decodificada para formar a
programação da produção. O Sistema Baseado em Regras é
utilizado na escolha dos tanques que recebem a produção e os
tanques que atendem à demanda dos diversos centros
consumidores existentes. Um novo operador de mutação -
Mutação por Vizinhança - foi proposto para minimizar o
número de trocas operacionais na produção. Uma técnica para
agregação de múltiplos objetivos, baseado no Método de
Minimização de Energia, também foi incorporado aos
Algoritmos Genéticos. Os resultados obtidos confirmam que
os Algoritmos Genéticos propostos, associados com o Método
de Minimização de Energia e a Mutação por Vizinhança, são
capazes de resolver o problema de programação da produção,
otimizando os objetivos operacionais da refinaria.<br>The purpose of this dissertation is to develop a method,
based on Genetics Algorithms and Rule Base Systems, to
optimize the production scheduling of fuel oil and asphalt
area in a petroleum refinery. The refinery is a multi-
product plant, with two machine stages - one mixer and a
set of tanks - with no setup time and with resource
constrains in continuous operation. Two genetic algorithms
models were developed to establish the sequence and the lot-
size of all production shares. The first model proposed has
a direct representation of the production scheduling which
the time interval of scheduling is shared in one hour
discrete intervals. The second model proposed has a indirect
representation that need to be decoded in order to make the
real production scheduling. The Rule Base Systems were
developed to choice the tanks that receive the production
and the tanks that provide the demand of the several
consumer centers. A special mutation operator -
Neighborhood Mutation - was proposed to minimize the number
of changes in the production. A Multi-objective Fitness
Evaluation technique, based on a Energy Minimization
Method, was also incorporated to the Genetic Algorithm
models. The results obtained confirm that the proposed
Genetic Algorithm models, associated with the Multi-
objective Energy Minimization Method and the Neighborhood
Mutation, are able to solve the scheduling problem,
optimizing the refinery operational objectives.<br>El objetivo de esta disertación es desarrollar un método de
solución utilizando Algoritmos Genéticos (GAs) aliado a un
Sistema Basado en Reglas para encontrar y optimizar las
soluciones generadas para el problema de programación de la
producción de Aceites Combustibles y Asfalto en la REVAP
(Refinería del Valle de Paraíba). La refinería es una
planta multiproducto, con dos estados de máquinas en serie -
un mezclador y un conjunto de tanques, con restricción de
recursos y operando en régimen contínuo. En este trabajo se
desarrollaron dos modelos basados en algoritmos genéticos
que son utilizados para encontrar la secuencia y los
tamaños de los lotes de producción de los productos
finales. El primer modelo propuesto utiliza una
representación directa de la programación de la producción
en la cuál el horizonte de programación se divide en
intervalos discretos de un hora. El segundo modelo, utiliza
una representación indirecta que es decodificada para
formar la programación de la producción. EL Sistema Basado
en Reglas se utiliza en la selección de los tanques que
reciben la producción y los tanques que atienden a la
demanda de los diversos centros consumidores. Un nuevo
operador de mutación - Mutación por Vecindad - fue
propuesto para minimizar el número de cambios operacionales
en la producción. le fue incorporado a los Algoritmos
Genéticos una técnica para la agregación de múltiples
objetivos, basado en el Método de Minimización de Energía.
Los resultados obtenidos confirman que los Algoritmos
Genéticos propuestos, asociados al Método de Minimización
de Energía y la Mutación por Vecindad, son capazes de
resolver el problema de programación de la producción,
optimizando los objetivos operacionales de la refinería.
10
Cozby, Raymond. "Fracture Conductivity and Its Effects on Production Estimation in Shale." Thesis, University of Louisiana at Lafayette, 2017. http://pqdtopen.proquest.com/#viewpdf?dispub=10243460.
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<p> The shale boom has introduced new technology into the oil and gas industry. It has created a new source of energy and has helped create a surplus in volume. With the recent decrease in oil prices, engineers must be creative and again use technology to make wells more productive. This study is done to observe the role of fracture conductivity in a hydraulically fractured well using a commercially available software. This will allow for engineers to improve fracking techniques. From this, it helps to consider the reliability of simulation software. </p><p> A typical well in the Eagle Ford Shale formation was selected to model. Completion data was gathered for a horizontal well that had seventeen fracture stages. In the simulation models, the fracture fluid volume was held constant to honor the original well production data. The fracture conductivity was studied using two different methods. The first involved observing one single fracture using different combinations of fracture conductivity throughout the fracture length. The second method incorporated the entire well and observed interactions between fractures with different altered fracture conductivities. Only one fracture was used per stage based off an existing fracture model. Production data with respect to time was analyzed and compared to real time field data. </p><p> After production results were analyzed, it can be seen that the models give a reliable representation of a horizontal well in the Eagle Ford Shale. When viewing the results of the single fracture stage, the cumulative productions are very similar, and when comparing the entire well with seventeen stages, the cumulative production begins to change slightly from model to model. Still, the difference in models does not merit an endorsement of a new completion technique for fracture conductivity. The results indicate that infinite acting flow takes over because of the low permeability reservoir. </p><p>
11
Moridifarimani, Fazel. "The distortionary effect of production sharing contract in upstream petroleum industry." Thesis, University of Dundee, 2018. https://discovery.dundee.ac.uk/en/studentTheses/d6b5fe43-62d8-4e3f-88ba-3c34653d46bd.
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There is a vast literature on the distortionary effects of the tax-royalty system, while the effects of Production Sharing Contract (PSC) is largely understudied. Moreover, economic studies typically oversimplify the physics of the field and consequently end up with models which do not necessarily fully reflect the reality. In this study, we build a dynamic optimisation model which nests the physics of the reservoir and investigates the distortionary effects of a PSC.
12
Ausen, Håvard. "A Study in MINLP-class Optimization Problems for Simulated Petroleum Production." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for teknisk kybernetikk, 2012. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-18435.
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To aid in faster and better decision making it is interesting to couple advanced simulators with optimization tools.Most simulators however does not offer gradients, therefore derivative-free methods must be used. In this thesis optimization of and oil and gas field with free routing is considered. By embedding the structural information in the optimization problem and approximating the simulators by polynomials a MINLP problem is formed which can be solved by gradient based solvers. This approach requires that the polynomial models are updated frequently to fit the simulators. Each update requires several simulations and creates a trade-off between robustness and computation time. Different updating strategies for the models are considered in this thesis. By solving a separate optimization problem to update the models the MINLP problem can be formulated as a convex problem which is solved in a branch and bound framework and with an interior-point. Two approaches to updating the models in respect to the branch and bound method are explored, and it is found to be more robust to update the models for each node of the branch and bound tree, ensuring a local fit before branching.
13
Rangel, Erik. "An evaluation of Mexico's declining oil production and waning petroleum reserves." Thesis, Monterey, California. Naval Postgraduate School, 2011. http://hdl.handle.net/10945/5793.
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Approved for public release; distribution is unlimited<br>rather than invested in exploration projects, infrastructure modernization, or process efficiency improvement. Decades of severe financial constraints placed on Pemex by the Mexican government, coupled with a weak corporate culture, have left Pemex unable to deal effectively with the oil production crisis at hand. This thesis examines the factors that explain why Mexican oil production has dwindled, despite the government's tremendous economic and political incentives to preserve revenues generated by oil rents.
14
OLIVEIRA, MARCIUS FERRARI DUARTE DE. "EVALUATION OF A SUBSEA MULTIPHASE PUMPING SYSTEM APPLIED ON PETROLEUM PRODUCTION." PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIRO, 2003. http://www.maxwell.vrac.puc-rio.br/Busca_etds.php?strSecao=resultado&nrSeq=4130@1.
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PETRÓLEO BRASILEIRO S. A.<br>CENTRO DE PESQUISAS LEOPOLDO AMÉRICO MIGUEZ DE MELLO<br>Um sistema de produção e escoamento de petróleo, quando
equipado com manifold submarino, viabiliza a produção
conjunta de poços de diferentes capacidades de produção. O
equilíbrio conseguido na produção desses poços se faz à
custa do estrangulamento (choking) dos poços de mais alta
capacidade de produção, de forma a propiciar um equilíbrio
com aqueles de mais baixa capacidade de produção.
Naturalmente as vazões atingidas nessa forma sinérgica
são menores do que aquelas que seriam atingidas com a
produção em separado desses poços mas, tais menores vazões
são economicamente mais atraentes devido às economias
atingidas nos custos de investimento (e.g., redução do
comprimento total de linhas de produção e do número de
risers) e das esperadas e normalmente ocorrentes reduções
de custo operacional nesses sistemas. Entretanto, a partir
da disponibilidade da tecnologia de bombeamento multifásico
submarino, na qual se torna possível diretamente transferir
energia à misturas multifásicas (óleo, gás e água) em
produção, viabiliza-se o estabelecimento de um novo e mais
atraente tipo de equilíbrio nesses sistemas. Tal novo
equilíbrio, possível pelo uso de sistemas de bombeamento
multifásico instalados em manifold submarinos de
produção, deve propiciar níveis de produção governados
inclusive pelos limites impostos pela engenharia de
reservatórios e não mais tão somente pelas características
físicas dos sistemas (seções de escoamento, distâncias,
lâminas d`água, propriedades dos fluidos etc.). A esta
forma inédita de obtenção de um novo e mais alto patamar de
equilíbrio da produção, a literatura vem utilizando a
denominação Estrangulamento Positivo (Positive Choking).
Assim, baseados no aumento das vazões de produção -
antecipação de produção - e no potencial aumento dos
fatores de recuperação - maiores volumes produzidos -
acredita-se ser tal técnica economicamente atraente quando
aplicada em sistemas de produção ainda em implementação, ou
mesmo, na implantação da mesma em sistemas já instalados. O
propósito desta tese é o de contribuir na análise técnica e
econômica da inédita aplicação de um sistema de bombeamento
multifásico submarino num sistema de produção equipado com
manifold.<br>A subsea oil production system allows simultaneous
production of several wells with different flow rates when
the system has a subsea manifold. In order to balance the
different flow rates, the higher production wells have
their flow rates reduced via a choking system. As a result,
the total flow is lower than the summmation of all
individual well flow rates. But, this combined and lower
production has a very attractive economics, as it requires
lower capital expenditures, mainly due to the shorter
overall length of flowlines and lower number of risers and,
also due to the expected lower operational costs. Nowadays,
however, with the availabity of the technology of subsea
multiphase pumping system, which enables the transfer of
energy to multiphase mixtures (oil, gas and water) under
production, becomes possible to achieve an even higher and
more attractive plateau in these petroleum production
systems. This new equilibrium plateau, made possible by the
technology of subsea multiphase pumping, will lead
to production levels that will attempt to take benefit of
all reservoir allowance and then extending the primary
production limit imposed by the production system
characteris tics (e.g., flowline length, water depth,
produced fluid properties etc.). This novel scheme that
allows obtaining a now and higher production level is
being called in the literature as Positive Choking.
Therefore, based on the resultant aspects of production
flow rate increase - production anticipation - and
on the potentially higher recovery factors - larger
produced volumes - is what drives the belief that such
technology can be economically attractive to new
production systems being installed or even in those already
in operation. The purpose of this work is to contribute in
the technical and economical evaluation of Multiphase
Pumping System application on a subsea production system
equipped with a manifold.
15
Firincioglu, Tuba. "Bubble point suppression in unconventional liquids rich reservoirs and its impact on oil production." Thesis, Colorado School of Mines, 2013. http://pqdtopen.proquest.com/#viewpdf?dispub=3558341.
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<p> The average pore size in producing unconventional, liquids-rich reservoirs is estimated to be less than 100 nm. At this nano-pore scale, capillary and surface disjoining force interactions, such as van der Waals, structural, and adsorption, affect the phase behavior that is not considered to be significantly, different than in conventional reservoirs. In this dissertation, a comprehensive discussion of the thermodynamics required to model phase behavior of unconventional, liquids-rich reservoirs is presented. Three oil compositions from different unconventional reservoirs are used to generate results. </p><p> The impact of confinement manifests itself in the form of reduction of the liquid pressure at which the first gas bubble forms when compared to the bulk fluid measurements in PVT cells. It is shown that the suppression of the bubble-point pressure impacts the saturated portion of the liquid formation volume factor and extends the undersaturated portion of the curve. The equilibrium gas composition is different for each supersaturation level and the gas is composed of lighter components as the supersaturation, i.e., the bubble-point suppression, increases. The minimum radius of the pore that is required to form a specified size bubble is also investigated and the range of pore sizes required under different assumptions is reported. </p><p> The impact of this phase behavior deviation on the flow of confined fluids is investigated using a black-oil simulator, COZSim, which evaluates gas and oil fluid properties at corresponding phase pressures. The simulator was independently developed in a DOE project with the capability to incorporate the findings of this research. The results of the analysis show that there is a difference in gas production and gas saturation distribution in the reservoir with and without the confinement impact on the PVT properties. The produced GOR is lower when the confinement is considered due to the bubble-point suppression. These results indicate that the use of bulk fluid measurements in modeling and predicting the performances of nano-porous unconventional reservoirs may result in significant underestimation of the reservoir potential. </p>
16
Mora, Carlos A. "Comparison of computation methods for CBM production performance." [College Station, Tex. : Texas A&M University, 2007. http://hdl.handle.net/1969.1/ETD-TAMU-1958.
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Hill, Mark Thomas. "The British North Sea : the importance of and factors affecting tax revenue from oil production /." Diss., CLICK HERE for online access, 2003. http://contentdm.lib.byu.edu/ETD/image/etd336.pdf.
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Dema, Perisuo. "Structuring of reserve based finance for petroleum production in Nigeria : contractual, regulatory and tax issues." Thesis, University of Aberdeen, 2014. http://digitool.abdn.ac.uk:80/webclient/DeliveryManager?pid=214822.
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Trabelsi, Racha. "Development of an Integrated System to Optimize Block 276 Production Performance." Thesis, University of Louisiana at Lafayette, 2017. http://pqdtopen.proquest.com/#viewpdf?dispub=10246387.
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<p> Integrating Techlog, Petrel, Eclipse, and COMSOL is a game changer and led to a better understanding of a very complex undercompacted and overpressurized sand in Block 276. Different reservoir simulation sensitivity runs on P1-sand indicated that putting a new well in block (2,34) under pure depletion will yield the highest incremental oil recovery of about 38%. The sensitivity runs included dumpfloods, waterfloods, and artificial lift. COMSOL has also shown that formation overlying the salt dome is hotter than other portions of the reservoir and that planning a new well on the western flank of the accumulation was the right decision. COMSOL has also shown that overpressurization is driven by undercompaction but that heat conduction from the dome and underlying diapirs affected pore pressure by 3 to 15%.</p><p>
20
Storvold, Vegard Svarlien. "Optimization of investment decisions and production planning in aging offshore petroleum fields." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for industriell økonomi og teknologiledelse, 2012. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-20969.
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This thesis suggests that an optimization model can be used as decision support when different subsea solutions are evaluated in order to increase hydrocarbon recovery and production lifetime of a field. The Marlim field in Campos Basin outside the coast of Brazil is used as a case, which is a field described as an aging field with increasing water production and declining profitability. The objective for the model is to maximize the net present value of a production asset by evaluating the installation of subsea boosters, subsea water separators and alternative routing solutions. The case consists of a well cluster of four wells that is routed through a subsea manifold connected to a FPSO through a riser. This case is similar to many of the production assets in the Marlim field, making the model applicable on other cases in the field as well. To solve this problem, a mixed integer linear program is developed. The nonlinear functions are approximated with piecewise linearization by a SOS2 formulation, where the set of breakpoints are generated in a multiphase flow simulator. Binary variables with time period indexes are introduced to say what type of technology should be installed, and when it should be installed. The time horizon in the model is ten years with a yearly resolution. The problem turns out to be quite challenging to solve if the detail level in the linear approximations and the time periods becomes too high. The problem is however solved nicely for a detail level found to be sufficient to provide useful results. The model suggest that there is a large potential for improving an asset’s NPV by installing new subsea processing equipment for enhanced production. The improvement consists of increased production and better usage of today’s infrastructure and topside installations, as well as increased system flexibility to mitigate uncertainty.
21
Garolera, Vinent Daniel. "Zero-thickness interface elements in petroleum geomechanics : sand production and hydraulic fracture." Doctoral thesis, Universitat Politècnica de Catalunya, 2017. http://hdl.handle.net/10803/667505.
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This thesis describes the extension of the Finite Element Method with zero-thickness interface elements (FEM+z) to 3D, large and complex problems in geomaterials, with special interest in petroleum geomechanics. This general objective has led to specific developments and applications such as the 3D code implementations and parallelization, and the specific petroleum geomechanics studies, both the macroscale (hydraulic fracture) and microscale (sand production).
The extension to 3D of the hydro-mechanical formulation of double node zero-thickness interface elements proposed earlier, has been developed and implemented in the computer code, with satisfactory results in the verification examples. From the theoretical viewpoint, the formulation is generalized via the definition of \quotes{transport} matrices for both mechanical and hydraulic formulations, so that the two levels of the formulation can be separated: the nodal variables of the interface element, and the mid-plane variables. The formulation described is successfully validated with benchmarking examples based on analytical expressions of a hydraulic fracture.
The parallelization of the code DRAC is achieved through the implementation of public domain library PETSc. The new code structure is conceived to perform a correct subdivision of tasks associated to each processor. For this purpose, a domain decomposition strategy has been implemented, which is crucial for an efficient matrix generation and assembly. The results obtained show a good degree of parallelization, demonstrated with a cube benchmark test.
The applications to hydraulic fracture have served a dual purpose. First, the examples of a single fracture have been used to validate the proposed formulation, since it has been possible to compare the results with the predictions of analytical expressions such as GDK or PKN, and to other numerical results from the literature. Second, the examples of multiple interacting fractures have shown the capabilities to analyze large and complex cases. The studies performed have shown a number of relevant aspects of multiple fracturing such as the effect of geometry (distance between injections) and the effect of in situ stresses.
Finally the thesis is devoted to the micromechanical analysis of sand production, including the generation and testing of micromechanical models based on the use of zero-thickness interface elements. Micromechanical (mesoscopic level) analysis with FEM+z has been successfully used to model the mechanical behavior of rock materials, using a similar approach as used previously for other heterogeneous materials. The rock grains are modeled as a group of continuum elastic elements and the cement (or matrix) is modeled with zero-thickness interfaces. This kind of modeling has been successfully used in uniaxial and triaxial compression test simulations. These numerical tests have been used for calibration purposes, comparing the macroscopic results obtained with the existing laboratory data. Due to the availability of experimental data, the simulation of sand production has been focused on the modeling of the hollow cylinder test. The simulations have been divided into two parts.
First, using a prototype material, the sensitivity of the method to geometric and microstructural variations has been analysed, and the effect of the perforation size is clearly observed. The second part deals with the analysis of a real case of rock sanding, that includes micromechanical tests for parameter calibration and the simulation of sand production. The results, despite the intrinsic variability of the samples, have shown a satisfactory agreement with average experimental results, both in terms of the rock sanding initiation and of sand production.<br>En aquesta tesi es presenta l'extensió del mètode d'elements finits amb elements junta d'espessor zero (FEM+z) a casos en 3D, per geometries grans i amb fenòmens complexos de fracturació per geomaterials, amb especial interès en la geomecànica del petroli. Aquest objectiu general ha donat lloc al desenvolupament i la generació aplicacions específiques, com ara les implementacions del codi a 3D i la paral·lelització, i els estudis específics de geomecànica del petroli, tant a macroescala (fractura hidràulica) com a microescala (producció de sorra). L'extensió a 3D de la formulació hidromecànica d'elements junta de doble nus proposada anteriorment, s'ha desenvolupat i implementat en el codi de càlcul, amb resultats satisfactoris en els exemples de verificació. Des del punt de vista teòric, la formulació s'ha generalitzat mitjançant la definició de matrius de transport per les dues formulacions, la mecànica i la hidràulica, de manera que es poden separar els dos nivells de la formulació: les variables nodals de l'element junta i les variables del pla mig. La paral·lelització del codi DRAC s'ha assolit mitjançant la implementació de la llibreria en codi lliure PETSc. La nova estructura del codi s'ha concebut per tal de realitzar una subdivisió correcta de les tasques associades a cada processador. Així, s'ha implementat una estratègia de descomposició de dominis, que és fonamental per a la generació i assemblatge de matrius de manera eficient. Els resultats obtinguts mostren un bon grau de paral·lelització. Les aplicacions de fractura hidràulica han tingut un doble propòsit. En primer lloc, s'han utilitzat els exemples d'una sola fractura per tal de validar la formulació proposada, ja que s'han pogut comparar els resultats amb les prediccions d'expressions analítiques com GDK o PKN i altres resultats numèrics de la literatura. En segon lloc, els exemples d'interacció entre fractures múltiples han demostrat la capacitat d'analitzar casos grans i complexos. Els estudis realitzats han mostrat una sèrie d'aspectes rellevants de la fractura múltiple, com l'efecte de la geometria (distància entre les injeccions) i l'efecte de les tensions in situ. Per finalitzar, la tesi presenta l'anàlisi micromecànic de la producció de sorra, que inclou la generació i la verificació dels models micromecànics basats en l'ús d'elements junta d'espessor zero. L'anàlisi micromecànic (nivell mesoscòpic) fet amb FEM+z s'ha utilitzat amb èxit per modelitzar el comportament mecànic de les roques. Els grans de roca es modelen com un grup d'elements elàstics de continu i el ciment (o matriu) es modelitza amb les juntes d'espessor zero. Aquest tipus de modelització s'ha utilitzat amb èxit en les simulacions d'assaigs a compressió uniaxial i triaxial. Les simulacions numèriques han servit per calibrar els paràmetres del model, comparant els resultats macroscòpics obtinguts amb les dades del laboratori existents. Degut a la disponibilitat de dades experimentals, la simulació de la producció de sorra s'ha centrat en la modelització de l'assaig de cilindres buits. Les simulacions s'han dividit en dues parts. En primer lloc, mitjançant l'ús d'un material prototip, s'ha analitzat la sensibilitat del mètode a les variacions geomètriques i microestructurals, on s'observa clarament l'efecte de mida de la perforació. La segona part ha tractat l'anàlisi d'un cas real de producció de sorra, que inclou assaigs micromecànics per la cal·libració dels paràmetres i la simulació de la producció de sorra. Els resultats, tot i la variabilitat intrínseca de les mostres, han demostrat un semblança satisfactòria amb els resultats experimentals, tant pel que fa a la iniciació com a la producció de sorra.
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Williamson, Paul Edwin, and n/a. "Managing Technical Advice for Regulation: The Case of Petroleum Exploration and Production." University of Canberra. Business & Government, 2007. http://erl.canberra.edu.au./public/adt-AUC20070820.123307.
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Governments, the community and industry expect public policy to be implemented
effectively and efficiently, particularly when that policy and regulation affects the
economic well being and environmental values of the nation. The offshore petroleum
exploration and production industry is a case where public policy and regulation are
attracting national focus through discussions on the timing of world peak oil production
and the future of national and global oil and gas production. An overseas history of
famous environmental disasters associated with petroleum exploration and production
and transportation also ensures a specific focus on the environmental regulation of the
industry.
This study elaborates the history and characteristics of the offshore petroleum E&Pindustries in Australia and the US, and the systems and processes used to provide
technical advice that informs and advises the regulation of those industries. The study
then analyses the management of technical advice for government regulation of the
offshore petroleum exploration and production (E&P) industry in Australia using the US
equivalent as benchmark. Further, the analysis develops a model that incorporates
strategic and operational elements of such advice. Strategic elements include openness,
transparency and accountability, and operational elements include use of expertise,
timeliness and peer communication.
The study illustrates the relative challenges to providing technical advice under
Australia�s Westminister form of government which can be less open, transparent and
accountable when compared to the US Congressional form of government. The study
also shows the greater use of expertise and peer communication associated with the more
extensive petroleum research effort in the US, reflecting the greater age and size of its
petroleum industry.
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Al-Farsi, Afkar Nadhim. "Radiological aspects of petroleum exploration and production in the sultanate of Oman." Queensland University of Technology, 2008. http://eprints.qut.edu.au/29817/.
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This thesis is a study of naturally occurring radioactive materials (NORM) activity concentration, gamma dose rate and radon (222Rn) exhalation from the waste streams of large-scale onshore petroleum operations. Types of activities covered included; sludge recovery from separation tanks, sludge farming, NORM storage, scaling in oil tubulars, scaling in gas production and sedimentation in produced water evaporation ponds. Field work was conducted in the arid desert terrain of an operational oil exploration and production region in the Sultanate of Oman.
The main radionuclides found were 226Ra and 210Pb (238U - series), 228Ra and 228Th (232Th - series), and 227Ac (235U - series), along with 40K. All activity concentrations were higher than the ambient soil level and varied over several orders of magnitude. The range of gamma dose rates at a 1 m height above ground for the farm treated sludge had a range of 0.06 0.43 µSv h 1, and an average close to the ambient soil mean of 0.086 ± 0.014 µSv h 1, whereas the untreated sludge gamma dose rates had a range of 0.07 1.78 µSv h 1, and a mean of 0.456 ± 0.303 µSv h 1. The geometric mean of ambient soil 222Rn exhalation rate for area surrounding the sludge was mBq m 2 s 1. Radon exhalation rates reported in oil waste products were all higher than the ambient soil value and varied over three orders of magnitude.
This study resulted in some unique findings including: (i) detection of radiotoxic 227Ac in the oil scales and sludge, (ii) need of a new empirical relation between petroleum sludge activity concentrations and gamma dose rates, and (iii) assessment of exhalation of 222Rn from oil sludge. Additionally the study investigated a method to determine oil scale and sludge age by the use of inherent behaviour of radionuclides as 228Ra:226Ra and 228Th:228Ra activity ratios.
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Haneef, Javed. "Single and multiphase flow properties of fault rocks : implications for petroleum production." Thesis, University of Leeds, 2016. http://etheses.whiterose.ac.uk/13441/.
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Geological faults are known to have a major impact on fluid flow in the subsurface and may developed isolated compartments for hydrocarbon reservoirs. The knowledge of their properties is important for petroleum industries within interests that include oil and gas production, Carbon dioxide storage and radioactive waste disposal. Large data sets have been collected on the single-phase permeability of fault rocks but these have been collected under inappropriate laboratory conditions such as low confining pressures and using distilled water as the permeant. Some data have been published on the gas relative permeability of fault rocks but no data is available on oil-water relative permeabilities or from fault rocks that are not strongly water-wet. The current thesis aims to produce high quality experimental data to partly fill these knowledge gaps by collecting gas and brine absolute permeability data from fault rocks at reservoir stress conditions using a formation compatible brine as well as oil-water relative permeabilities from fault rocks that are water-wet and after wettability alteration so that they become less water wet. The key findings of this thesis show that the absolute permeability of fault rocks is very stress sensitive due to the presence of microfractures created during coring or core-retrieval. The stress sensitivity of permeability increases with decreasing permeability. On average, fault rocks have a permeability at in situ stress which is ~ 20% that measured at ambient conditions. Permeability is also found to be less sensitive to brine composition, with permeabilities to distilled water being around 20% those when measured with brine. So the effects of two poor laboratory practices cancel each other out meaning that much published data remain usable. The obtained results from oil water relative permeability measurements of water-wet cataclastic faults are consistent with what is known about grain-sorting controlling relative permeability. The changes in wettability resulting from aging the samples in crude oil are also consistent with what would be expected when the wettability of samples is altered to being neutral to oil-wet. These results raise the possibility that fault rocks in some reservoirs may not be strongly water-wet and will therefore not act as capillary barriers. A new clay-mixing model is also presented, which explains the scatter on permeability vs clay content that is used as input for calculating fault transmissibility multipliers in production simulation models. The obtained results can be used as the analogues for similar fault rock types and implemented in the reservoir simulation models for the future forecast of hydrocarbon production.
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Chuprin, Maksym. "Effect of Proppant Type on Economics of Shale Oil Production from the Bakken Formation." Thesis, University of Louisiana at Lafayette, 2019. http://pqdtopen.proquest.com/#viewpdf?dispub=10826999.
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<p> Hydraulic Fracturing is a cost-effective technique that has been widely integrated and applied to commercial production of oil and gas from unconventional reservoirs. Advancement of this technique brings more complexity into it, making optimization process more complicated in terms of economic analysis and decision making. Selection of proppant for treatment is a crucial and essential decision that has a significant impact on fracturing stimulation and well economics. This analysis indicates advantages and disadvantages of different types of proppant and provides a comparison of proppant performances considering proppant type, mesh size and concentration in order to identify the best scenario of proppant application in terms of economical profitability. </p><p>
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Bujarbarua, Vikram. "Production Optimization Using an In-Situ Steam Generator in a Rejuvenated Heavy Oil Field." Thesis, University of Louisiana at Lafayette, 2016. http://pqdtopen.proquest.com/#viewpdf?dispub=10003753.
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<p> Steam stimulation is by far the most widely used tertiary oil recovery method. Heavy oil finds its most effective way of production in thermal recovery method. Also with technical effectiveness, steam stimulation brings in cost effectiveness. In-situ steam generation and injection is the most important enhancement to the conventional thermal steam injection technique. Blackbird™ Energy LLC, has developed and a new generation in-situ steam generator with a view to make an almost unproductive heavy oil reservoir in North East Texas to start producing. </p><p> In this research, a reservoir simulation study has been performed to history match of pure depletion as well as three months of thermal stimulation done on the reservoir. To mimic the reservoir conditions, Schlumberger Eclipse 300 compositional Simulator has been used. Overall this research performs an evaluation of the newly developed in-situ steam generator capabilities. </p><p> The various predictive runs have been made with changing key performance parameters such as location of steam generator and time of application of thermal energy. There has been reported a considerable increase in production of the heavy oil. As a result, in-situ steam injection has been proved to be an effective and environment friendly recovery technique and should be widely considered for replacing conventional steam generators.</p>
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Abdelarahim, Abdelarahim Mohamed. "Libya's production sharing agreement in comparison with Iran's buyback contract." Thesis, University of Aberdeen, 2016. http://digitool.abdn.ac.uk:80/webclient/DeliveryManager?pid=229380.
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Choong, Peng Kee. "A comparison of uncertainty analysis methods for the modeling of land disposal of petroleum exploration and production waste." Thesis, This resource online, 1991. http://scholar.lib.vt.edu/theses/available/etd-08182009-040359/.
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Nagarajan, Kavitha Rani. "Dispersant Effectiveness of Crude, Refined and Synthetic Oil Under Different Environmental Conditions." University of Cincinnati / OhioLINK, 2008. http://rave.ohiolink.edu/etdc/view?acc_num=ucin1226632486.
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Meyer, Jeremy Joel. "The determination and application of in situ stresses in petroleum exploration and production." Title page, contents and abstract only, 2002. http://web4.library.adelaide.edu.au/theses/09PH/09phm6127.pdf.
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"August 2002" Bibliography: leaves 226-238. This thesis applies standard techniques, and develops new techniques for in situ stress determination from data acquired in petroleum exploration. The techniques are applied in four case studies, the Swan Lake Field, South Australia, The Mereenie Field, Northern Territory, the Gulf of Thailand and the Otway Basin, South Australia. The impact of the resultant in situ stress data on exploration and development plans is assessed.
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Abbas, A. J. "Descaling of petroleum production tubing utilising aerated high pressure flat fan water sprays." Thesis, University of Salford, 2014. http://usir.salford.ac.uk/33069/.
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Recent attempts to utilise solid particles in combination with high pressure water sprays has caused environmental and safety concern, in cleaning mineral and organic scale inside the Oil and Gas Production Tubing. To increase cleaning performance only high pressure aerated water sprays at high impact force instead should be used. Multi-nationals petroleum companies are facing immense challenges in removing the scale due to the decrease in cavitation bubbles along the production tubing when high pressure water sprays are applied. This has also resulted in high maintenance costs and low productivity of the ‘wells’ with multi billions pounds financial losses per annum. Currently scales are removed using either aggressive chemicals (acids), complete replacement of the tubing, or solid-liquid sprays which are both expensive and causes environmental concern. This research demonstrated that the application of air-water combination (aerated sprays) are the solution in complete removal of various scales in the production tubing without the use of solid particles and the cavitation bubbles. This novel experimental technique of scale removal utilised air concentration (or aeration) in combination with high pressure flat fan sprays, of up to 10 MPa, at low flow rate (up to 12 l/min) with high impact pressure of approximately 0.15 MPa, in removing scale along production tubing using a simulated aeration chamber. It was found that varying air concentration from 3 to 12%, within the emulated chamber, improved scale erosion up to 28% higher than non-aerated technique. This enabled the mass of the scale to be removed at the ‘stand-off distance’ of 25 mm relative to scale samples, irrespective of cavitation bubble length suppression which is normally about 2 mm away from the atomiser orifice exit, compared to non-aerated techniques (solids and water). Scale erosion was found to be 12.80g, 7.31 g, and 65.80 g at aerated conditions compared to non-aerated provision which found to be 9.88g, 6.33g and 5.31 g, at the required liquid pressure 10 MPa, for the hard, medium and soft scale samples that are typically found in oil production tubing. Prior to scale removal trials sprays were characterised qualitatively and quantitatively under the ambient conditions as well as inside the aerated simulated chamber. Air velocities were found to be approximately 18m/s towards the water spray centre which then decays to 3 m/s towards the spray periphery under ambient conditions using hot wire anemometer. Moreover, the flat fan sprays were also characterised utilising Phase Doppler Anemometry (PDA). It was found that the high pressure water liquid droplet velocities were in the range of 75 to 117 m/s with droplet diameters of 55 to 81 µm (SMD) at flow rates of 7.6 to 11.3 l/min at various stand-off distances of 25, 50 and 75mm, providing an impact pressure of 0.05, 0.10 and 0.15 MPa respectively. Qualitatively cavitation bubble length was also estimated using high resolution imaging techniques which were found to be between 1 to 2 mm from the atomiser exit orifice under submerged conditions, at the stand-off distance ≤ 25 mm where the scale is normally removed. Beyond this range (1-2 mm) where the cavitation bubbles are not present, that are normally the benefactors to scale removal process, requires air concentration up to 12%. This ensures that a complete removal of the mass of corresponding scales to be achieved with varying chemical scale compositions. The air concentration is the ratio of total mass of air within the simulated chamber to mass of the liquid sprays impacting directly onto the scale samples. The results of the experimental trials were used to validate the available CFD fluent models with regards to spray dynamics, aerated air (velocities), cavitation bubble generations and scale erosion (removal). The sensitivity analysis using the CFD modelling gave close comparison with those obtained through experimental trials. Spray droplets size and their velocities were found to be within ±10% compared to those obtained via experimental findings. The aerated air velocities were also compared with the data generated from CFD which were found to be approximately ±9%. Furthermore, the cavitation bubble generation and the mass of the scale removed were found to vary within ±5% and ±7% respectively, when compared to the CFD data. Finding emerged that the spray droplets especially at the centre undergoes acceleration after primary breakup, which due to higher velocities resulting from the acceleration has left the entrained-air particles behind, which is characterise with substantially low-pressure region, giving rise to utilisation of the air-water interaction model. This could be another approach in further understanding the break regions within the high pressure liquid sprays.
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Stevenson, Mallory. "The Marcellus Shale| Erosional boundary and production analysis, southern West Virginia, U.S.A." Thesis, East Carolina University, 2016. http://pqdtopen.proquest.com/#viewpdf?dispub=1606661.
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<p> The Middle Devonian Marcellus Shale is a natural gas producing formation that was deposited in the Appalachian foreland basin in what is now eastern North America. An unconformity truncates the Marcellus in southern West Virginia and progressively younger units onlap progressively older units. The zero isopach line that marks the edge of the Marcellus is mapped to reveal the southeastern boundary. A well production analysis is conducted to locate the region of maximum natural gas production. Four lithologic completions intervals in three different well fields are compared. This study shows that the most economically viable drilling is from the Marcellus Shale completion intervals that are less than 30 feet in Chapmanville gas field in western Logan County, West Virginia. Outside of the zero isopach are areas comprised of onlapping featheredges of younger formations that comprise a black shale unit mistakenly identified as “Marcellus Shale”. These areas produce significantly less gas than the “true” Marcellus Shale.</p>
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Buba, Ibrahim Muhammad. "Direct estimation of gas reserves using production data." Texas A&M University, 2003. http://hdl.handle.net/1969/153.
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Loegel, Thomas N. "High Performance Liquid Chromatography of Petroleum Asphaltenes and Capillary Electrophoresis of Glycosaminoglycan Carbohydrates." Miami University / OhioLINK, 2012. http://rave.ohiolink.edu/etdc/view?acc_num=miami1354241855.
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Wilson, Victoria R. "Point Pleasant Produced Water Characterization: An Analysis of Past Production and Prediction of Future Production." Youngstown State University / OhioLINK, 2019. http://rave.ohiolink.edu/etdc/view?acc_num=ysu155973360664964.
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Essien, Imoh Samson. "History Matching, Forecasting & Production Optimization on Norne E-Segment." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for petroleumsteknologi og anvendt geofysikk, 2012. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-19397.
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I performed manual History Matching on the E-segment of the Norne field based on available production & pressure data. I used the obtained final match for future prediction. I performed Production Optimization by experimenting with increased and decreased water injection rates.
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Jakobsson, Kristofer. "Petroleum Production and Exploration : Approaching the End of Cheap Oil with Bottom-Up Modeling." Doctoral thesis, Uppsala universitet, Globala energisystem, 2012. http://urn.kb.se/resolve?urn=urn:nbn:se:uu:diva-163181.
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The theme of this thesis is the depletion of petroleum (crude oil and natural gas). Are there reasons to be concerned about an ‘end of cheap oil’ in the near future? There is a lively debate regarding this issue. The debate is sometimes described as a clash of ‘concerned’ natural scientists and ‘unconcerned’ economists. However, this clash is both harmful and unnecessary. The views of natural scientists and economists can and should be reconciled. At the micro-level, geological and physical factors (such as diminishing reservoir productivity) are parameters in the producer’s economic optimization problem. Bottom-up modeling therefore appears to hold more promise for forming a common understanding of depletion than prevailing top-down models, such as the controversial Hubbert model. The appended papers treat various aspects of petroleum depletion: critical examination of top-down scenarios (I); bottom-up economic and geologic modeling of regional production (II); review of published bottom-up models and sensitivity analysis (III); simulation of success rates and expectations in oil exploration (IV); bottom-up scenarios of future natural gas production in Norway (V) and Russia (VI); empirical analysis of production profiles of giant oil fields (VII). Bottom-up models have the potential to be accepted by scientists from different disciplines, and they enable interpretable sensitivity analyses. They are, however, not likely to reduce quantitative uncertainty in long-term scenarios. There is theoretical evidence of the possibility that petroleum scarcity occurs long before the recoverable resource is close to exhaustion. This result is a consequence of both geological and economical factors. Several arguments for an ‘unconcerned’ view are at best uncertain, and at worst relying on questionable assumptions (analyzing reserves rather than production flows, using irrelevant reserve definitions, using average cost instead of marginal cost). The considerable uncertainty regarding an issue of such importance is in itself a cause for concern.
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Vu, Xuan Hoan, Sura Nguyen, Thanh Tung Dang, Udo Armbruster, and Andreas Martin. "Production of renewable biofuels and chemicals by processing bio-feedstock in conventional petroleum refineries." Technische Universität Dresden, 2014. https://tud.qucosa.de/id/qucosa%3A29110.
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The influence of catalyst characteristics, i.e., acidity and porosity on the product distribution in the cracking of triglyceride-rich biomass under fluid catalytic cracking (FCC) conditions is reported. It has found that the degradation degree of triglyceride molecules is strongly dependent on the catalysts’ acidity. The higher density of acid sites enhances the conversion of triglycerides to lighter products such as gaseous products and gasoline-range hydrocarbons. The formation of gasolinerange aromatics and light olefins (propene and ethene) is favored in the medium pore channel of H-ZSM-5. On the other hand, heavier olefins such as gasoline-range and C4 olefins are formed preferentially in the large pore structure of zeolite Y based FCC catalyst (Midas-BSR). With both catalysts, triglyceride molecules are mainly converted to a mixture of hydrocarbons, which can be used as liquid fuels and platform chemicals. Hence, the utilization of the existing FCC units in conventional petroleum refineries for processing of triglyceride based feedstock, in particular waste cooking oil may open the way for production of renewable liquid fuels and chemicals in the near future.<br>Bài báo trình bày kết quả nghiên cứu khả năng tích hợp sản xuất nhiên liệu sinh học và hóa phẩm từ nguồn nguyên liệu tái tạo sinh khối giầu triglyceride bằng công nghệ cracking xúc tác tấng sôi (FCC) trong nhà máy lọc dầu. Kết quả nghiên cứu cho thấy xúc tác có ảnh hưởng mạnh đến hiệu quả chuyển hóa triglyceride thành hydrocarbon. Tính acid của xúc tác càng mạnh thì độ chuyển hóa càng cao và thu được nhiều sản phẩm nhẹ hơn như xăng và các olefin nhẹ. Xúc tác vi mao quản trung bình như H-ZSM-5 có độ chọn lọc cao với hợp chất vòng thơm thuộc phân đoạn xăng và olefin nhẹ như propylen và ethylen. Với kích thước vi mao quản lớn, xúc tác công nghiệp FCC dựa trên zeolite Y ưu tiên hình thành C4 olefins và các olefin trong phân đoạn xăng. Ở điều kiện phản ứng của quá trình FCC, triglyceride chuyển hóa hiệu quả thành hydrocarbon mà có thể sử dụng làm xăng sinh học cho động cơ và olefin nhẹ làm nguyên liệu cho tổng hợp hóa dầu.
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Vu, Xuan Hoan, Sura Nguyen, Thanh Tung Dang, Udo Armbruster, and Andreas Martin. "Production of renewable biofuels and chemicals by processing bio-feedstock in conventional petroleum refineries." Saechsische Landesbibliothek- Staats- und Universitaetsbibliothek Dresden, 2015. http://nbn-resolving.de/urn:nbn:de:bsz:14-qucosa-190806.
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The influence of catalyst characteristics, i.e., acidity and porosity on the product distribution in the cracking of triglyceride-rich biomass under fluid catalytic cracking (FCC) conditions is reported. It has found that the degradation degree of triglyceride molecules is strongly dependent on the catalysts’ acidity. The higher density of acid sites enhances the conversion of triglycerides to lighter products such as gaseous products and gasoline-range hydrocarbons. The formation of gasolinerange aromatics and light olefins (propene and ethene) is favored in the medium pore channel of H-ZSM-5. On the other hand, heavier olefins such as gasoline-range and C4 olefins are formed preferentially in the large pore structure of zeolite Y based FCC catalyst (Midas-BSR). With both catalysts, triglyceride molecules are mainly converted to a mixture of hydrocarbons, which can be used as liquid fuels and platform chemicals. Hence, the utilization of the existing FCC units in conventional petroleum refineries for processing of triglyceride based feedstock, in particular waste cooking oil may open the way for production of renewable liquid fuels and chemicals in the near future<br>Bài báo trình bày kết quả nghiên cứu khả năng tích hợp sản xuất nhiên liệu sinh học và hóa phẩm từ nguồn nguyên liệu tái tạo sinh khối giầu triglyceride bằng công nghệ cracking xúc tác tấng sôi (FCC) trong nhà máy lọc dầu. Kết quả nghiên cứu cho thấy xúc tác có ảnh hưởng mạnh đến hiệu quả chuyển hóa triglyceride thành hydrocarbon. Tính acid của xúc tác càng mạnh thì độ chuyển hóa càng cao và thu được nhiều sản phẩm nhẹ hơn như xăng và các olefin nhẹ. Xúc tác vi mao quản trung bình như H-ZSM-5 có độ chọn lọc cao với hợp chất vòng thơm thuộc phân đoạn xăng và olefin nhẹ như propylen và ethylen. Với kích thước vi mao quản lớn, xúc tác công nghiệp FCC dựa trên zeolite Y ưu tiên hình thành C4 olefins và các olefin trong phân đoạn xăng. Ở điều kiện phản ứng của quá trình FCC, triglyceride chuyển hóa hiệu quả thành hydrocarbon mà có thể sử dụng làm xăng sinh học cho động cơ và olefin nhẹ làm nguyên liệu cho tổng hợp hóa dầu
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Acar, Cagdas. "Enhancing Petroleum Recovery From Heavy Oil Fields By Microwave Heating." Master's thesis, METU, 2007. http://etd.lib.metu.edu.tr/upload/12608403/index.pdf.
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There are many heavy oil reservoirs with thin pay zones (less than 10 m) in the world and in Turkey. Conventional steam injection techniques are not costeffective for such reservoirs, due to excessive heat loss through the overburden. Heat losses can be minimized through controlled heating of the pay zone. One such way is to introduce heat to the reservoir in a controlled manner is microwave heating. Laboratory studies on microwave heating of a scaled model of a heavy oil reservoir with a thin pay zone are presented with an economical feasibility of the method. In this thesis, three different conceptual oil reservoirs from south east Turkey are evaluated: Bati Raman (9.5 API) and Ç<br>amurlu (12 API) heavy crude oils and paraffinic Garzan (26 API)crude oil. Using a graphite core holder packed with crushed limestone with crude oil and water microwave effects of operational parameters like heating time and waiting period as well as rock and fluid properties like permeability, porosity, wettability, salinity, and initial water saturation are studied. The main recovery mechanisms for the experiments are viscosity reduction and gravity drainage. An analytical model is developed by coupling heat equation with the electromagnetic dissipated power per unit of volume based in Maxwell'<br>s equation successfully models the experiments for temperatures less than the pyrolysis temperature is presented. Also the experiments are scaled to the
model by geometric similarity concept. In economic evaluation, the cost of oil is calculated based on domestic electricity prices.
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Ahsan, Md Abul. "Production Optimization of Beani Bazar Gas Field of Bangladesh Through Simulation Run." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for petroleumsteknologi og anvendt geofysikk, 2012. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-19195.
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Bean Bazar gas field was discovered by Pakistan Shell Oil Company (PSOC) in 1960 and initial production started since 1999. The field has two wells-BB1 and BB2 and two sand groups- Upper Gas sand (UGS) and Lower Gas Sand (LGS). This is one of the condensate rich fields in Bangladesh. The field is produced by water drive. A huge amount of water is produced from the two sands. The proven gas reserve of this field was estimated approximately 230.80 Bcf. The total gas produced till December, 2011 was 75.65 Bcf. That is one-third gas had already been produced. The remaining gas is required to recover from the wells by predicting the present well and reservoir performance for a certain time based on the current production data. That is why, this task was liked by me when the authority proposed me.In this thesis work, a simulation model was constructed based on the latest production data. Vertical Flow performance (VFP) for BB1 and BB2, Change of transmissibility, Change of angle of aquifer etc. improved the recovery. Most of the geological data was taken from the "Simulation Study of Beani Bazar Field" by RPS Energy, U.K.2009. The simulation model was then run to forecast the future field performance to find out an optimal development plan for the field and to determine the reserve estimation.Simulation results showed that the ultimate recovery is very high in drilling wells but it involves a lot of cost. But there is no way out. The water must be controlled. The final recommendation for future work on Beani Bazar simulation model is that the water rise should be controlled by drilling a new well in the present reservoir a few km away from the existing wells. The quick gas production can bring huge water which should be handled by re-installing the plant infra-structure.
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Garcia, Perez Manuel. "Co-pyrolysis under vacuum of bagasse and petroleum residue for the production of bio-fuels." Thesis, National Library of Canada = Bibliothèque nationale du Canada, 2000. http://www.collectionscanada.ca/obj/s4/f2/dsk1/tape3/PQDD_0012/MQ56745.pdf.
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Hansen-Tangen, Jakob G., and Sindre Dombu Sangnes. "A Logic Branch and Bound Algorithm for Petroleum Production Optimization Based on Generalized Disjunctive Programming." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for industriell økonomi og teknologiledelse, 2013. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-24842.
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A new solution method for solving the real time production optimization (RTPO) problem for a petroleum production system is presented in this thesis. The objective function of the problem maximizes oil production and the RTPO handles decision variables at operational level. Including routing of production flows, lift gas allocation, and pressure configurations of the system. It is aimed to give decision support in a time horizon of days to weeks. Such problems require solution methods able to obtain solutions swiftly, as production planners adjust network components frequently to maintain optimal production.The problem contains binary decision variables combined with nonlinear expressions and is mathematically classified as a nonconvex mixed integer nonlinear problem (MINLP). MINLPs are in general known as computationally expensive and hard to solve to optimality, and when nonconvexities are present, few solvers can guarantee global optimality. The solution method presented deviates from traditional optimization techniques applied to such problems, and introduces logic disjunctions to substitute the binary variables of the MINLP. A specialized branch and bound algorithm (LBB) is developed to utilize the structure of these disjunctions, and as time is of paramount importance for the RTPO, it is aimed to reduce demanded computational effort for the problem. The LBB is given a high degree of user flexibility to be able to tailor the algorithm to different problems.Results of the LBB show substantial variation in solution efficiency when applied to a real petroleum production system. Only when specific problem knowledge is utilized to customize the algorithm to the current system, the algorithm provides solid reduction in computational effort compared to a recognized commercial solver. Also when applied to variations in system structure the LBB clearly outperforms the applied solver, and the effectiveness and robustness of the proposed algorithm when utilizing problem specific knowledge is confirmed. The fact that the LBB provides the same solution to the problem as the applied solver might also indicate that the nonconvexities of the problem are not as complex as expected, and that the solver is in fact able to find the global optimal solution.
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Matus, Eric Robert. "A top-injection bottom-production cyclic steam stimulation method for enhanced heavy oil recovery." Texas A&M University, 2006. http://hdl.handle.net/1969.1/4446.
Full textAbstract:
A novel method to enhance oil production during cyclic steam injection has been
developed. In the Top-Injection and Bottom-Production (TINBOP) method, the well
contains two strings separated by two packers (a dual and a single packer): the short
string (SS) is completed in the top quarter of the reservoir, while the long string (LS) is
completed in the bottom quarter of the reservoir. The method requires an initial warm-up
stage where steam is injected into both strings for 21 days; then the LS is opened to
production while the SS continues to inject steam for 14 days. After the initial warm-up,
the following schedule is repeated: the LS is closed and steam is injected in the SS for 21
days; then steam injection is stopped and the LS is opened to production for 180 days.
There is no soak period.
Simulations to compare the performance of the TINBOP method against that of a
conventional cyclic steam injector (perforated across the whole reservoir) have been
made. Three reservoir types were simulated using 2-D radial, black oil models: Hamaca
(9ðAPI), San Ardo (12ðAPI) and the SPE fourth comparative solution project (14ðAPI).
For the first two types, a 20x1x20 10-acre model was used that incorporated typical rock
and fluid properties for these fields. Simulation results indicate oil recovery after 10 years was 5.7-27% OIIP with
TINBOP, that is 57-93% higher than conventional cyclic steam injection (3.3-14% OIIP).
Steam-oil ratios were also decreased with TINBOP (0.8-3.1%) compared to conventional
(1.2-5.3%), resulting from the improved reservoir heating efficiency.
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Deshpande, Vaibhav Prakashrao. "General screening criteria for shale gas reservoirs and production data analysis of Barnett shale." [College Station, Tex. : Texas A&M University, 2008. http://hdl.handle.net/1969.1/ETD-TAMU-2357.
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Carvalho, Paulo Cesar Gasse de. "Gerenciamento do bombeio de cavidades progressivas." [s.n.], 1999. http://repositorio.unicamp.br/jspui/handle/REPOSIP/263658.
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Orientadores: Celso Kazuyuki Morooka, Sergio Nascimento Bordalo<br>Dissertação (mestrado) - Universidade Estadual de Campinas, Faculdade de Engenharia Mecanica<br>Made available in DSpace on 2018-07-25T22:21:03Z (GMT). No. of bitstreams: 1
Carvalho_PauloCesarGassede_M.pdf: 7671437 bytes, checksum: 5c73626d53d31bb65617b10db9e1c11a (MD5)
Previous issue date: 1999<br>Resumo: Neste trabalho, buscou-se desenvolver um sistema inteligente de acompanhamento e controle de poços, que permita avaliar periodicamente o desempenho operacional de um campo de petróleo, produzindo com os poços equipados com BCP - Bombeio de Cavidades Progressivas. O trabalho foi desenvolvido em duas etapas principais. Inicialmente, foi realizada uma revisão bibliográfica sobre o BCP, voltada para a identificação dos pontos fundamentais, para proporcionar um melhor funcionamento do sistema. Em seguida, com base na experiência acumulada nos últimos anos com o acompanhamento de campos de petróleo na Bahia, procurou-se propor um sistema de controle para gerenciamento das operações de um campo de petróleo, voltado para o BCP. Este sistema utiliza técnicas de inteligência artificial, como conjuntos nebulosos. Espera-se que os resultados apresentados neste trabalho possam servir de base a gerentes, engenheiros, supervisores e operadores, para obterem um desempenho contínuo e otimizado deste método de elevação, na produção de petróleo<br>Abstract: The main purpose of this work is to develop an intelligent system to management and control, that allows to periodically evaluate the operational performance of a petroleum field producing with the wells equipped with PCP - Progressing Cavity Pump. The work was developed in two main stages. Initially, it was accomplished a literature search about PCP, in order to identify its fundamental parameters that provide a better operation of the system. Afterwards, based on the experience obtained during the last years with the accompaniment of petroleum fields in Bahia, it is proposed acontrol system for management of the petroleum field operations, centered to PCP. This system uses techniques of artificial intelligence, as fuzzy sets, to obtain better interpolations. It is desired that the results presented in this Master' s thesis can be useful to managers, engineers, supervisors and operators to obtain a continuous and optimized performance of this artificial lift method, at the petroleum production<br>Mestrado<br>Mestre em Engenharia de Petróleo
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Viseshakul, Pongpisit. "The impact of taxation and government participation in petroleum production in Thailand : a decision making approach." Thesis, University of Cambridge, 1991. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.240061.
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Nyika, Erasmo. "Stabilization of petroleum fiscal regime in relation to production sharing agreements in Tanzania : challenges and prospects." Thesis, University of Aberdeen, 2017. http://digitool.abdn.ac.uk:80/webclient/DeliveryManager?pid=237077.
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This study argues for the need to ensure that host countries derive appropriate benefits from natural resources exploited within their territories. In this regard, the most important return from petroleum extraction, is from the fiscal take. Taxation of the extractive sector is thus a major revenue source. The host country interest from the extractive activities is in parallel to the interest of investor countries to share in the revenues derived from investments in the extractives sector by entities from those countries. Further, the capital exporting countries assert interest in protecting the investors from the risks associate with foreign investments, particularly in developing host countries. Historically, International Oil Companies enjoyed an upper hand in negotiating investment protection and stability terms as a result of information asymmetries. Many agreements concluded between the investor entities with developing host countries have been askew and overly favourable to the investor to the extent of endearing unconscionability. This study reveals that Tanzania's existing Production Sharing Agreements contain fiscal terms which do not allocate an appropriate share of financial benefits to the host country. It also reveals that arrangements to protect and provide investment stability have employed terms which are inimical to the economic and social well-being of the Peoples of Tanzania, for example through the excessive and wasteful grant of tax concessions. It was observed that Tanzania has offered fiscal terms to IOCs that do not allow the country to enjoy appropriate benefits from the exploitation of its natural resources. This project, therefore, establishes the effect of stabilisation terms as embedded in the Tanzanian fiscal regime, what redress measures should be sought to correct the imbalance and inequitableness engraved in the abusive use of stabilization arrangements through the PSAs.
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Akpan, Stella Eyo. ""Well Placement for maximum production in the Norwegian Sea" : Case Study: Norne C-segment Oil Field." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for petroleumsteknologi og anvendt geofysikk, 2012. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-19960.
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In petroleum fields, the essence of well placement is to develop and maintain petroleum reservoirs in order to achieve maximum production for economic benefit. Maximum production can be achieved with more oil wells, but few optimal numbers of wells in good location reduces economic costs and increase recovery. The best location for the placement of oil, gas or water wells depends on reservoir and fluid properties, well and surface equipment specifications, as well as economic parameters [1].The objective of the study is to determine the net present value from few well placements in the Norne C-segment reservoir by either obtaining the same or more oil production/recovery compared to the base case wells. New well placement in a reservoir simulation model uses an industrial standard ECLIPSE reservoir simulator. Manually simulation approach is used to locate high oil saturation grids for the new well placement. From the base case simulation result, a total number of thirteen wells were discovered, nine producers and four injectors. The production and injection wells were classified with a suffix according to the production templates B, D, K and injection template C respectively.The base case wells removed and new well placed from exhaustive simulation runs for two different scenario cases. A total number of ten wells, six producers and four injectors were placed in each scenario. In order to obtain maximum oil recovery, the producers are placed horizontally while injectors remain the same as those from the base case. The new well placements in the scenario cases are identified with the suffix “P-H” for producers and “I-H” for injectors. Simulation results, the total oil produced for wells in each field case from the start year 1997 to December 2015, (end of production) can be seen in Table 10, 11 and 12 in chapter 6. The cumulative oil produced from each field case is the same as the total oil produced from all the wells in each case. The cumulative field oil and gas production from the start of production, November 1997 to December 2015 is 41.3 million Sm3 oil and 260 million Sm3 of gas for base case, 42.8 million Sm3 oil and 269 million Sm3 of gas for scenario 1 case, 43.2 million Sm3 oil and 272 million Sm3 of gas for scenario 2 case. The recovery factor for base case is 28%, scenario 1 & 2 are 29.0% and 29.3%. Each field case uses drive mechanisms, gas injection and water injection to support oil production and maintain pressure in the each field case. The total gas and water injected in the base case field were 9.6 billion Sm3 and 78.8 million Sm3 respectively. In scenario 1, a total of 8.6 billion Sm3 of gas and 81.6 million Sm3 of water was injected and in Scenario 2, 8.6 billion Sm3 of gas and 81.3 million Sm3 of water was injected. The Net present values for the three cases were calculated taking into account the economic costs such as well cost, cost of gas and water injection. Sensitization was done on the oil price ($25, $35 and $45). The NPV results from Table 19 prove that all case projects are acceptable, but scenario 2 is the most economical as it has the highest NPV of $4,026 million based on $35-medium oil price that was considered.
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Alalade, Oluwadunsin. "What determines oil production? : a case study of Nigeria and the United Kingdom." Thesis, Brunel University, 2016. http://bura.brunel.ac.uk/handle/2438/13124.
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Nigeria and the United Kingdom are leading oil producers within their region. Both countries are linked by their exploration and production maturity within their regions and the fact that they produce similar oil grades. Their institutional similarities and their economic status as developed and developing economies provide the platform upon which this study basis its comparative investigation. On account of the oil price phenomenon and oil supply concerns by way of reserves, this study investigates the effect of the Hotelling theory, the Hubbert theory and Engineering decline curve theory on actual production rates within Nigeria and the United Kingdom. It develops individual models for both countries, applying each theory to each country to analyse the individual effect and the effect in comparison to one another. The level of adherence of each country to these production theories is measured, following which a combination of all three theories is applied to both country cases to quantify the level of significance and relationship to actual production behaviour. The results leave us with the understanding that the Hubbert theory does indeed capture the behaviour of production in both countries even where it was not expected in the case of Nigeria. The reserve constraint remains a key factor in future production plans for both countries. The results of the empirical analysis provide evidence of strong support in the United Kingdom for the Hotelling theory and weak support in the case of Nigeria. Oil price also remains a key factor in production modelling, though less so in the case of Nigeria. The engineering modelling approach on the other hand failed to explain Nigeria’s production profile, while it captured that of the UK; indicating that production in Nigeria is yet to decline. This result is corroborated by the projected peak production date seen in the Hubbert forecast model for Nigeria, and the weaker support Nigeria shows for the Hubbert theory. The study concludes by developing a combined model using all three theories to quantitatively analyse which of them best explains the country oil production profile. The results lead us to conclude that despite the fact that there is weak support for a production theory; an empirical analysis of the data does show that the relationship may not be insignificant. The augmentation along with the combination of the production models sheds more light on actual behaviour as it provides a more in-depth understanding on actual oil production behaviour.