Academic literature on the topic 'Unit operation of oil fields'
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Journal articles on the topic "Unit operation of oil fields"
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Afrisca, Cindy Clara. "Evaluasi Rigless Plug & Abandonment: Sebuah Studi Kasus." Jurnal Nasional Pengelolaan Energi MigasZoom 2, no. 2 (2020): 09–20. http://dx.doi.org/10.37525/mz/2020-2/256.
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Oil was explored and found by Royal Dutch (Shell Group) geologist in early 1900. And since Indonesia’s independence, development in oil and gas projects was able to put Indonesia as one of major oil exporter country with daily production above 1 Million barrel per day in 1970 – 1990. With time as fields become mature, some of the fields have come to the end of its life cycle, where mostly 70% of Indonesia total old oil wells will have no economic value and has to be permanently Plug and Abandonment (P&A) as ruled by the government. It’s part of decommissioning an entire field with environmental preservation which called Abandonment and Site Restoration (ASR). As P&A will impact operating company investment as outlined in Ministry of Energy and Mineral Resources (ESDM) No. 15, 2008, efficient P&A operation should be evaluated to ensure proper planning and executions. The subject of evaluation is X well located onshore at Y Field, Java, Indonesia. P&A operation with multiple cements plugs as barriers to ensure no fluids migrations from one formation to others, or to surface. Evaluation between workover rig and rigless P&A operation with coiled tubing unit (CTU) and electric line (E-line) will be presented in this paper to value the expenditures and achieving the result as standardize by the government with accordance of operating company standard. Results show that rigless operation is the preferable solution, which lead to cost effective operation. Rigless operation saves 25% of P&A operations even tough with longer operation days.
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Imran, Dr Aed Jaber. "AL – Mansuriya gas fields associated liquid and its role to increase the potential capacity of gasoline fuel in Daura oil refinery." Journal of Petroleum Research and Studies 7, no. 1 (2021): 107–17. http://dx.doi.org/10.52716/jprs.v7i1.167.
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Hydrotreating processing is commonly used to remove platforming catalyst poisons from straight run or cracked naphthas prior to charging to the platforming Process unit. It can be seen that the primary function of the naphtha Hydrotreating Process can be characterized as a “Clean up” Operation. The catalyst used in the Naphtha Hydrotreating Process is composed of an alumina base impregnated with compounds of cobalt or nickel and molybdenum. The catalyst is insensitive to most poisons which affect dehydrogenation reactions. A relatively high percentage of carbon on the catalyst does not materially affect its sensitivity or selectivity. Volumetric recoveries of products depend on the sulfur and olefin contents [1].
 The Naphtha Hydrotreating Process is a catalytic refining process employing a selected catalyst and a hydrogen-rich gas stream to decompose organic sulfur, oxygen and nitrogen compounds contained in hydrocarbon fractions. In addition, hydrotreating removes organo-metallic compounds and saturates olefinic compounds.
 Organo-metallic compounds, notably arsenic and lead compounds, are known to be permanent poisons to platinum catalysts. "The complete removal of these materials by Hydrotreating processing gives longer catalyst life in the platforming unit.
 Sulfur, above a critical level, is a temporary poison to platforming catalysts and causes an unfavorable change in the product distribution. Organic nitrogen is also a temporary poison to platforming catalyst. It is an extremely potent one, however, and relatively small amounts of nitrogen compounds in the Platformer feed can cause large deactivation effects, as well as the deposition of ammonium chloride salts in the platforming unit cold sections.
 Oxygen compounds are detrimental to the operation of a Platformer. Any oxygen compounds which are not removed in the hydrotreater will be converted to water in the platforming unit, thus affecting the water/ chloride balance of the platforming catalyst. Large amounts of olefins contribute to increase coking of the platforming catalyst. Also, olefins can polymerize at platforming operating conditions which can result in exchanger and reactor fouling.
 The Naphtha Hydrotreating Process makes a major contribution to the ease of operation and economy of platforming. Much greater flexibility is afforded in choice of allowable charge stocks to the platforming unit. Because this unit protects the platforming catalyst, it is important to maintain consistently good operation in the Hydrotreating Unit.
 In addition to treating naphtha for Platformer feed, naphthas produced from thermal cracking processes, such as delayed coking and visbreaking, are usually high in olefinic content and other contaminants, and may not be stable in storage. These naphthas may be hydrotreated to stabilize the olefins and to remove organic or metallic contaminants, thus providing a marketable product.
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Vaqif Gurbanov, Safa Mustafayev, Zuleykha Eyvazova, Vaqif Gurbanov, Safa Mustafayev, Zuleykha Eyvazova. "IMPROVEMENT OF THE OPERATION PROCESS OF WATERED DEEP OIL PUMP WELLS BY APPLICATION OF POLYFUNCTIONAL MEASURES." ETM - Equipment, Technologies, Materials 07, no. 03 (2021): 22–33. http://dx.doi.org/10.36962/etm0703202122.
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The article shows the types of complications that occur mainly in the fields of the Absheron archipelago in Azerbaijan and in the oil fields of the Azerbaijani sector of the Caspian Sea; the most common and frequent of them are the watering of the production of sucker rod pumping wells and the intensity of sand manifestations. It is noted that methods that prevent complications or reduce their negative impact are more appropriate than methods for their elimination. It is proposed to isolate formation water in flooded sucker-rod pumping oil wells using a universal hydrodynamic method; In this method, a liquid barrier should be created in front of the water in the formation, and not a solid barrier, and high-viscosity dead (non-gaseous) oil should be taken as a separating fluid, the specific gravity of which should be equal to the specific gravity of the formation water. The article uses the following five functions of multifunctional measures when carrying out various well survey methods: I. Pouring clean fluid into the annulus to increase the amount of fluid in the wellbore and reduce the concentration of sand particles in it. II. Without stopping the operation of the pumping unit, adding clean oil to the annulus with the help of a unit, raise its static level several meters higher. III. Determination of values of Pk, Po and G in rod deep well pumping wells producing viscous-plastic oil without stopping the operation of the pumping unit. IV. To determine the reservoir pressure in the simplest way, all well production is drained with a hose into the annulus. V. When removing the first lower curve by the method of two-sided restoration of curves without stopping the operation of the pumping unit VI. When applying the extraction method without changing the indicator diagrams S and n of water-cut oil wells. Thus, the use of multifunctional measures improves the performance of the considered wells and provides great economic benefits. Keywords: polyfunctional measure, irrigated well, sand manifestation, corrosion, erosion, wear, complication, pipe space, sand concentration in liquid, recovery curve.
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Afanasiev, V. A., S. N. Bastrikov, and V. A. Popov. "STATE, CHALLENGES AND PROSPECTS OF DEVELOPMENT OF THE METHOD FOR SIMULTANEOUS-SEPARATE OPERATION OF WELLS USING ECP UNITS IN THE MULTIHORIZON FIELDS OF WEST SIBERIA." Oil and Gas Studies, no. 1 (February 28, 2015): 19–25. http://dx.doi.org/10.31660/0445-0108-2015-1-19-25.
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To create the operable equipment for simultaneous-separate operation of wells by electrical centrifugal pumping units (“SSO-ECP”) the experience gained by domestic and foreign specialists in this equipment designing, manufacturing and introduction was studied. It is offered to experimentally apply the assembly of SSO-ECP -A unit in wells being in operation for development of multihorizon fields with the purpose to increase these horizons oil recovery factor and current flow rates of wells. It is shown that for perspective development of SSO-ECP it is necessary to speed up the designing process and to arrange the commercial production of automated well systems of flow rate control and water encroachment of layers separated in the borehole, well chokes, and to prepare the industry «Methodical recommendations for designing the SSO technologies in multihorizon oil fields of Russia».
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Mingulov, I. Sh, M. D. Valeev, V. V. Mukhametshin, and L. S. Kuleshova. "Wells production viscosity measurement results application for pumping equipment operation diagnostics." SOCAR Proceedings, SI2 (December 30, 2021): 152–60. http://dx.doi.org/10.5510/ogp2021si200584.
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The article is devoted to the diagnostics of the well pumping equipment operation using wells production viscosity measurement results obtained by the developed field device VNP 1-4, 0-90. The method for making measurements with a field oil viscometer was developed in accordance with the provisions of GOST R 8.563, GOST R ISO 5725-2. It has gained certification and entered the State Register of the Russian Federation. On the basis of preliminary laboratory studies of oils viscosity from the group of fields of LLC UK «Sheshmaoil», a formula was obtained for the dependence of oil emulsions viscosity on temperature and the content of formation water in them. Viscosity measurements obtained with the developed device in field conditions have shown the applicability of the method for calculating the watered oil viscosity.The application of the results of measuring the watered oil viscosity at the wellhead allows diagnosing the downhole sucker rod pump unit operation based on the construction of a dynamic model of its operation. Keywords: equipment diagnostics; water cut; temperature; fluid viscosity; dynamic model; sucker rod pump.
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Bikbulatova, G. I., A. A. Isaev, A. S. Galeev, Yu A. Boltneva, O. A. Shipilova, and T. A. Ganiev. "The results of introducing technology to remove gas from the annulus of a well by creating vacuum at the Zarechnoye field." Oil and Gas Studies, no. 3 (July 8, 2020): 100–108. http://dx.doi.org/10.31660/0445-0108-2020-3-100-108.
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The technology for pumping out and partial utilization of associated gas in oil fields by the vacuum method, using a unit for pumping gas from the annulus of the well and pumping it into the product collection system (KOGS), have been implemented at wells at the Zarechnoye field of Geotech JSC in the Republic of Tatarstan. These wells are operated by sucker rod units. The use of the KOGS unit allowed us to evaluate the effectiveness of the production system under consideration Experimental studies have shown that a decrease in annular pressure causes a significant increase in the dynamic level and an improvement in the conditions of oil inflow to the well. The operation of sucker rod units in such conditions provides an increase in the delivery and filling coefficients of the pump and, accordingly, an increase in oil production.
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Ahmadov, I. Z., and S. E. Tagiyeva. "Study the depth impact of sucker-rod pumps running on delivery rate." Azerbaijan Oil Industry, no. 6-7 (July 15, 2021): 23–27. http://dx.doi.org/10.37474/0365-8554/2021-6-7-23-27.
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As it is known, currently, the fields at the last stage of development are operated predominantly with sucker-rod pumps. Their operation is usually carried out in quite complicated technological and hydrodynamic conditions dramatically affecting the operation efficiency. Based on the actual field data, the paper studies the possible impact of the depth of sucker-rod pump running on the delivery rate, which is one of the indexes of operation of the whole sucker-rod pump unit. The values of delivery rates by oil and water have been calculated and their functional dependencies on the depth of sucker-rod pumps running developed as well. The results justified the increase of delivery rate by oil and its decrease by water in reviewed value diapasons. Mathematical models of developed dependencies have been obtained as well. As a result of conducted studies, the practicability of the increase of pump setting depth in operation conditions of reviewed field is justified.
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Ilqar Ahmadov, Sabina Tagiyeva, Ilqar Ahmadov, Sabina Tagiyeva, and Samira Mansurova Samira Mansurova. "INVESTIGATION OF THE INFLUENCE OF THE LOWERING DEPTH OF DOWNHOLE SUCKER-ROD PUMPS ON THE DELIVERY FACTOR." ETM - Equipment, Technologies, Materials 12, no. 04 (2022): 52–59. http://dx.doi.org/10.36962/etm12042022-52.
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It is well known that, at present, late stage fields are operated mainly by sucker-rod pumps. The pumps are usually operated in rather complicated technological and hydrodynamic conditions, strongly influencing its efficiency. In the article the possible influence of downhole sucker-rod pump (DSRP) depth on delivery factor that is one of the indicators of operating efficiency of the entire sucker-rod pumping unit is investigated on the basis of actual field information. The values of oil and water delivery coefficients were calculated and functional dependence on the depth of sucker-rod pump immersion was built. The results showed an increase in the oil supply coefficient and a decrease in its water supply coefficient in the considered ranges of values. Mathematical models of the dependencies were also obtained. As a result of the conducted research, the expediency of the controlled increase of the depth of suspension of pumps in the conditions of operation of the considered field is confirmed. Keywords: down-hole sucker-rod pump, delivery ratio, well operation, pump parameters, depth of pump suspension
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Jasiński, Ryszard. "Analysis of the Heating Process of Hydraulic Motors during Start-Up in Thermal Shock Conditions." Energies 15, no. 1 (2021): 55. http://dx.doi.org/10.3390/en15010055.
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Conditions that prevail during harsh winters and hot summers pose a serious challenge for machine designers building devices suitable for operation in extreme weather. It is essential for the designers and the users to define the principles and conditions for the safe operation of machines and devices with hydraulic drive in low ambient temperatures. Bearing in mind the above, the author tested the hydraulic motors in thermal shock conditions (cold motors were fed with a hot working medium). This enterprise required the design and construction of a specialized stand for testing hydraulic motors, including satellite motors, in thermal shock conditions. The stand was equipped with the apparatus and a system for measuring the temperature of the moving parts of the satellite motor. The experimental tests were conducted in the laboratory of the Faculty of Mechanical Engineering and Ship Technology at Gdańsk University of Technology. The paper presents the results of tests of a correctly and incorrectly operating satellite motor during start-up in thermal shock conditions. The results concerned the course of oil temperatures, temperatures of heated elements, oil pressures, and the pressure drop in the motor. The influence of the oil pressure drop in the motor on its temperature increase was determined. The distributions of the temperature fields of the heated elements of the satellite motor during start-up in thermal shock conditions were derived by means of computer simulation. The utilization of the distribution of the temperature fields of the motor elements enables the evaluation and analysis of the work of this unit. The conducted tests may determine the conditions for the proper operation of hydraulic motors started in thermal shock conditions.
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Kopey, І. B. "Prospects of using the hydraulic drive of the rod well pump." Prospecting and Development of Oil and Gas Fields, no. 4(81) (December 28, 2021): 71–81. http://dx.doi.org/10.31471/1993-9973-2021-4(81)-71-81.
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The most widespread mechanized way of oil production is use of sucker rod deep pumping units. This mode of well operation is characterized by moderate costs of the equipment and its service, increase in production when developing difficult-to-recover oil reserves, increase in production of layer which is reached by decrease in critical bottom hole pressure. Installation of the sucker rod deep pump comprises the land and borehole equipment. The drive, the well head setup and control system belongs to the land equipment. For today the pump unit is used as a wire. The unit itself represents the four-link crank-and-rod mechanism converting crank rotational motion into reciprocal motion of polished rod carrier bar. The work considers the prospects of creation and implementation of the drives nonconventional designs replacing classical pumping units, namely hydraulic actuators of sucker rod deep pumps on Ukrainian oil fields. Furthermore, the possible fields of their use has been defined. The hydraulic pressure drives existing designs presented by the leading global manufactures have been analyzed via critical-comparative method. Moreover, their design features in comparison with pumping units and chain occasions have been covered, the main advantages and shortcomings have been revealed. The usage possibilities of remote and automatic control of the hydraulic pressure drive working mode have been specified. The drive allows to carry out monitoring and remote control of technological process in real time with the minimum participation of service staff. The work presents the results of the hydraulic pressure drive PSHN-80-2.5 with pneumatic equilibration pilot test on well 64-Dolyna of scientific testing ground of the Ivano-Frankivsk National Technical University of Oil and Gas which have confirmed the work capacity of all drive systems and also convenience of carrying out the installation operations.
Dissertations / Theses on the topic "Unit operation of oil fields"
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Boltyanskiy, Boris. "Operation of the heat and power complex Alatyr to power Russian oil and gas facilities." Thesis, KTH, Skolan för industriell teknik och management (ITM), 2018. http://urn.kb.se/resolve?urn=urn:nbn:se:kth:diva-264245.
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B. Boltyansky Operation of the heat and power complex Alatyr to power Russian oil and gas facilities, Master's Dissertation, 2017 - 102 pages, 26 tables, 30 figures Supervisor Prof. V. G. Kucherov, Doctor of Sciences, Department of Energy Technology. The work includes the following. A calculation of the main thermodynamic cycle of the heat and power complex Alatyr heat and power complex. A consideration of various schemes of using the Rankine organic cycle WERE integrated in the Alatyr heat and power complex with the aim of increasing energy efficiency. Conclusions about the feasibility of using the heat and power complex Alatyr. Conclusions about the feasibility of integration of the organic Rankine cycle. Economic comparison of the heat and power complex Alatyr with similar facilities on the distributed power generation market. Economic analysis of the comparison of energy blocks of HPC Alatyr with similar designs from other countries.<br>B. Boltyansky Drift av värme- och kraftkomplexet Alatyr till makten Ryska olje- och gasanläggningar, Masters uppläggning, 2017 - 102 sidor, 26 tabeller, 30 figurer Handledare Prof. VG Kucherov, doktorsexamen, kandidatexamen för teknisk vetenskap, institutionen för termodynamik och termisk motorer. Arbetet innehåller följande. En beräkning av värmekraftkomplexets värmeoch kraftkomplex Alatyrs värmekomplex. En övervägning av olika system för användning av Rankine organiska cykeln var integrerad i Alatyr värme- och kraftkomplexet i syfte att öka energieffektiviteten. Slutsatser om möjligheten att använda värme- och kraftkomplexet Alatyr. Slutsatser om möjligheten att integrera den organiska Rankine-cykeln. Ekonomisk jämförelse av värme- och kraftkomplexet Alatyr med liknande anläggningar på den distribuerade kraftproduktionsmarknaden. Ekonomisk analys av jämförelsen av energiblock av HPC Alatyr med liknande konstruktioner från andra länder.
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John, Yakubu M. "Kinetic modelling simulation and optimal operation of fluid catalytic cracking of crude oil: Hydrodynamic investigation of riser gas phase compressibility factor, kinetic parameter estimation strategy and optimal yields of propylene, diesel and gasoline in fluid catalytic cracking unit." Thesis, University of Bradford, 2018. http://hdl.handle.net/10454/17323.
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The Fluidized Catalytic Cracking (FCC) is known for its ability to convert refinery wastes into useful fuels such as gasoline, diesel and some lighter products such as ethylene and propylene, which are major building blocks for the polyethylene and polypropylene production. It is the most important unit of the refinery. However, changes in quality, nature of crude oil blends feedstock, environmental changes and the desire to obtain higher profitability, lead to many alternative operating conditions of the FCC riser.
There are two major reactors in the FCC unit: the riser and the regenerator. The production objective of the riser is the maximisation of gasoline and diesel, but it can also be used to maximise products like propylene, butylene etc. For the regenerator, it is for regeneration of spent or deactivated catalyst.
To realise these objectives, mathematical models of the riser, disengage-stripping section, cyclones and regenerator were adopted from the literature and modified, and then used on the gPROMS model builder platform to make a virtual form of the FCC unit. A new parameter estimation technique was developed in this research and used to estimate new kinetic parameters for a new six lumps kinetic model based on an industrial unit. Research outputs have resulted in the following major products’ yields: gasoline (plant; 47.31 wt% and simulation; 48.63 wt%) and diesel (plant; 18.57 wt% and simulation; 18.42 wt%) and this readily validates the new estimation methodology as well as the kinetic parameters estimated. The same methodology was used to estimate kinetic parameters for a new kinetic reaction scheme that considered propylene as a single lump. The yield of propylene was found to be 4.59 wt%, which is consistent with published data.
For the first time, a Z-factor correlation analysis was used in the riser simulation to improve the hydrodynamics. It was found that different Z factor correlations predicted different riser operating pressures (90 – 279 kPa) and temperatures as well as the riser products. The Z factor correlation of Heidaryan et al. (2010a) was found to represent the condition of the riser, and depending on the catalyst-to-oil ratio, this ranges from 1.06 at the inlet of the riser to 0.92 at the exit.
Optimisation was carried out to maximise gasoline, propylene in the riser and minimise CO2 in the regenerator. An increase of 4.51% gasoline, 8.93 wt.% increase in propylene as a single lump and 5.24 % reduction of carbon dioxide emission were achieved. Finally, varying the riser diameter was found to have very little effect on the yields of the riser products.
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Tsai, Ming-Te, and 蔡明德. "The search of optimal operation variables for crude oil distillation unit by neural networks." Thesis, 2003. http://ndltd.ncl.edu.tw/handle/48160884249106838429.
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碩士<br>國立臺北科技大學<br>化學工程系碩士班<br>91<br>This study was to optimize the oil production rate under the required oil product qualities of a crude oil distillation unit (CDU). The system was established based on an existed operation database of a CDU operating system. The input operating variables of the CDU system were properties of crude oil and manipulated variables. The system output variables were defined as oil product qualities. The knowledge database of the CDU operating model can be built using the input-output data with an approach of artificial neural networks (ANN). The built ANN model can be applied on the prediction of the oil product qualities with respect to the system input variables. Besides, a design of experiment (DOE) was applied to analyze the effects of the system input variables on the oil product qualities. As a result, optimal operating conditions were then found using the knowledge database with an optimization method based on a predefined objective function. The built expert system can provide an on-line optimal operating information of the CDU process to the operators corresponding to the change of crude oil properties.
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Vilhena, Daniela Palma. "Microalgae Biorefinery Routes and Unit Operation Pre-Project Design, Selection and Sizing." Master's thesis, 2018. http://hdl.handle.net/10362/53494.
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Microalgae, or microscopic algae, have been studied as a natural marine resource for a number of economically relevant applications and several options exist for recovering and pro-cessing the biomass to obtain intracellular metabolites. This work presents the laboratory results from two proposed Nannochloropsis sp. microalgae biorefineries for the production of oil, high-value pigments, proteins and carbohydrates. Concerning the microalgal cell disruption processes, an overview of the technologies available was performed and bead milling was found to be potentially suitable for large scale microalgae biorefineries.
Since petroleum-derived solvents such as dichloromethane, toluene or hexane are toxic and non-renewable, innovative and sustainable extractions using D-limonene, olive oil and etha-nol were tested to extract valuable lipids and pigments. Different membranes were also tested aiming the solvent recovery of ethanol and D-limonene. Regarding rejections of pigments and fatty acids, high values were achieved using organic solvent resistant membranes, proving to be possible to fractionate valuable biomolecules with a green and clean process.
Afterwards, the laboratory results were extrapolated to mass balance calculations to select the biorefinery route by conducting a simplified economic analysis through equipment sizing and the cost estimation of the major equipments. The biorefinery route using olive oil as solvent was found to be the most promising process to study because, combined with the lower estimated CAPEX, the olive oil extract might be a highly profitable product rich in EPA fatty acid, as a product with significant health benefits for the human population.
Books on the topic "Unit operation of oil fields"
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Joint operating agreement: Working manual. Section of Natural Resources Law, American Bar Association, 1986.
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Libecap, Gary D. The self-enforcing provisions of oil and gas unit operating agreements: Theory and evidence. National Bureau of Economic Research, 1999.
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Hankinson, R. L. Landman's encyclopedia. 3rd ed. Gulf Pub. Co., Book Division, 1988.
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Unitization of oil and gas fields in Texas: A study of legislative, administrative, and judicial policies. Resources for the Future, 1986.
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Shumilov, A. V. The geophysical survey during oilfield operation: Tutorial for students. Permskiĭ gos. universitet, 2010.
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Major, R. P. Delineation of unrecovered mobile oil in a mature dolomite reservoir: East Penwell San Andres Unit, university lands, West Texas. Bureau of Economic Geology, University of Texas at Austin, 1990.
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United States. Bureau of Land Management. Draft environmental impact statement for the Bull Mountain Unit master development plan. U.S. Department of the Interior, Bureau of Land Management, Uncompahgre Field Office, 2015.
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Serebryakov, Andrey, and Gennadiy Zhuravlev. Exploitation of oil and gas fields by horizontal wells. INFRA-M Academic Publishing LLC., 2021. http://dx.doi.org/10.12737/971768.
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The textbook describes the design features of offshore horizontal multi-hole production wells, as well as the bottom-hole components of horizontal multi-hole wells. The classification of complications of multi-hole horizontal wells, methods of their prevention and elimination are given. Methods of underground geonavigation of the development of offshore horizontal production wells are proposed. The geological and field bases of operation of horizontal offshore multi-hole oil and gas wells, modes and dynamics of oil, gas and associated water production, methods for calculating dynamic bottom-hole and reservoir pressures are specified. The technologies of operation of offshore horizontal multi-hole wells are presented. The composition and scope of environmental, field and research marine monitoring of the operation of offshore horizontal multi-hole wells and the protection of the marine environment in the production of oil and gas are justified. Meets the requirements of the federal state educational standards of higher education of the latest generation. It is intended for undergraduates of the enlarged group of "Earth Sciences" training areas, as well as for teachers, employees of the fuel and energy complex, industrial geological exploration and oil and gas production enterprises, scientific and design organizations.
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Weaver, Jacqueline Lang. Unitization of Oil and Gas Fields in Texas: A Study of Legislative, Administrative, and Judicial Policies. RoutledgeFalmer, 2013.
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Weaver, Jacqueline Lang. Unitization of Oil and Gas Fields in Texas: A Study of Legislative, Administrative, and Judicial Policies. Earthscan LLC, 2013.
Find full textBook chapters on the topic "Unit operation of oil fields"
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Durmanov, M. Ya, B. G. Martynov, and S. V. Spiridonov. "Oil Consumption Through Burning in Heavy-Duty Operation of an Agricultural Machine and Tractor Unit." In Lecture Notes in Mechanical Engineering. Springer International Publishing, 2021. http://dx.doi.org/10.1007/978-3-030-54817-9_25.
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Guldemond, Ewoud. "Collaborative Work Environments in Smart Oil Fields." In Advances in Business Strategy and Competitive Advantage. IGI Global, 2013. http://dx.doi.org/10.4018/978-1-4666-2002-5.ch004.
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In the last decade, oil companies are increasingly viewing collaborative work environments as an important component of their smart oil fields programs. Collaborative work environments (CWEs) have been implemented by several major oil companies, to support the use of technology in smart oil fields. The implementation of these collaborative work environments is not without problems. After major oil companies successfully implemented the hardware, tools and applications in CWEs, organizational design challenges remained unsolved. The biggest challenge is to change behavior of staff and to effectively integrate people across disciplinary boundaries. This chapter emphasizes the importance of the organizational aspect of CWEs in smart oil fields. The objective of this chapter is to provide the upstream petroleum industry with guidelines for the organizational design of the collaborative work environments, in support of the operation of smart oil fields. In order to provide the organizational design guidelines, a PhD research was conducted at three different operating units of a major oil company. This research focused on the business processes, organizational structure, and competencies of staff in the CWEs.
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VALLE, BRUNO. "THE IMPORTANCE OF PETROPHYSICS IN THE REDEVELOPMENT OF MATURE FIELDS: A CASE STUDY IN THE POTIGUAR BASIN." In Resumos do I Encontro Brasileiro de Petrofísica de Campos Maduros. Editora Realize, 2022. http://dx.doi.org/10.46943/i.ebpcm.2022.01.017.
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IN THE PAST YEARS THE REDEVELOPMENT OF MATURE FIELDS HAS BECOME AN IMPORTANT THEME IN BRAZIL DUE TO THE DISINVESTMENT PLAN OF THE MAJOR OPERATOR IN THE COUNTRY. IN THIS SCENARIO, NEW PLAYERS SPECIALIZED IN REVITALIZING THESE FIELDS ARE APPLYING DIFFERENT STRATEGIES AND ACHIEVING IMPORTANT RESULTS. THE PRODUCTION DECLINE IN BROWNFIELDS IS A NATURAL PHENOMENON AND SEVERAL TECHNIQUES CAN BE DEPLOYED TO REVERSE THIS DECLINE. IN THIS SENSE, THE INTEGRATED APPROACH BETWEEN MANY DIFFERENT AREAS IS A KEY FACTOR, WHICH CAN RESULT IN A MORE RELIABLE RESERVOIR CHARACTERIZATION AND FIELD DEVELOPMENT. THE PETROPHYSICS PLAY A KEY ROLE IN THE REDEVELOPMENT STRATEGIES, ACTING INTEGRATED WITH GEOLOGY, RESERVOIR ENGINEERING AND OPERATIONS. A GOOD STATIC MODEL IS ONE OF THE MOST IMPORTANT PREMISES WHEN STUDYING A RESERVOIR, APPLYING HIGH-RESOLUTION STRATIGRAPHY TECHNIQUES, IDENTIFYING RESERVOIR CONNECTIVITY AND FLOW UNITS. IN ADDITION, THE INTEGRATION BETWEEN PETROPHYSICS AND RESERVOIR ENGINEERING HAS A CRUCIAL ROLE IN THE ESTABLISHMENT RESERVOIR DEPLETION LEVELS AND ESTIMATING CURRENT WATER SATURATION AND OIL-WATER CONTACT DISPLACEMENT. THE USE OF CASED HOLE TOOLS SUCH AS PULSED NEUTRON LOGS AID IN THE RESERVOIR MONITORING, IN THE IDENTIFICATION OF BYPASSED OIL ZONES AND SIGNIFICANTLY REDUCES RISKS IN WORKOVER ACTIVITIES. IN THIS PRESENTATION IT WILL BE DESCRIBED WORKFLOWS AND TECHNIQUES OF HOW PETROPHYSICS WAS APPLIED IN THE CONCEPT OF MATURE OILFIELD REDEVELOPMENT, WHICH LED TO AN INCREASE OF RESERVOIR PRODUCTIVITY IN OVER 60%.
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VALLE, BRUNO. "THE IMPORTANCE OF PETROPHYSICS IN THE REDEVELOPMENT OF MATURE FIELDS: A CASE STUDY IN THE POTIGUAR BASIN." In Resumos do I Encontro Brasileiro de Petrofísica de Campos Maduros. Editora Realize, 2022. http://dx.doi.org/10.46943/i.ebpcm.2022.01.017.
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IN THE PAST YEARS THE REDEVELOPMENT OF MATURE FIELDS HAS BECOME AN IMPORTANT THEME IN BRAZIL DUE TO THE DISINVESTMENT PLAN OF THE MAJOR OPERATOR IN THE COUNTRY. IN THIS SCENARIO, NEW PLAYERS SPECIALIZED IN REVITALIZING THESE FIELDS ARE APPLYING DIFFERENT STRATEGIES AND ACHIEVING IMPORTANT RESULTS. THE PRODUCTION DECLINE IN BROWNFIELDS IS A NATURAL PHENOMENON AND SEVERAL TECHNIQUES CAN BE DEPLOYED TO REVERSE THIS DECLINE. IN THIS SENSE, THE INTEGRATED APPROACH BETWEEN MANY DIFFERENT AREAS IS A KEY FACTOR, WHICH CAN RESULT IN A MORE RELIABLE RESERVOIR CHARACTERIZATION AND FIELD DEVELOPMENT. THE PETROPHYSICS PLAY A KEY ROLE IN THE REDEVELOPMENT STRATEGIES, ACTING INTEGRATED WITH GEOLOGY, RESERVOIR ENGINEERING AND OPERATIONS. A GOOD STATIC MODEL IS ONE OF THE MOST IMPORTANT PREMISES WHEN STUDYING A RESERVOIR, APPLYING HIGH-RESOLUTION STRATIGRAPHY TECHNIQUES, IDENTIFYING RESERVOIR CONNECTIVITY AND FLOW UNITS. IN ADDITION, THE INTEGRATION BETWEEN PETROPHYSICS AND RESERVOIR ENGINEERING HAS A CRUCIAL ROLE IN THE ESTABLISHMENT RESERVOIR DEPLETION LEVELS AND ESTIMATING CURRENT WATER SATURATION AND OIL-WATER CONTACT DISPLACEMENT. THE USE OF CASED HOLE TOOLS SUCH AS PULSED NEUTRON LOGS AID IN THE RESERVOIR MONITORING, IN THE IDENTIFICATION OF BYPASSED OIL ZONES AND SIGNIFICANTLY REDUCES RISKS IN WORKOVER ACTIVITIES. IN THIS PRESENTATION IT WILL BE DESCRIBED WORKFLOWS AND TECHNIQUES OF HOW PETROPHYSICS WAS APPLIED IN THE CONCEPT OF MATURE OILFIELD REDEVELOPMENT, WHICH LED TO AN INCREASE OF RESERVOIR PRODUCTIVITY IN OVER 60%.
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SLATT, R. M., J. M. BOAK, G. T. GOODRICH, et al. "DEPOSITIONAL FACIES, PALEOENVIRONMENTS, RESERVOIR QUALITY, AND WELL LOG CHARACTERISTICS OF MIO-PLIOCENE DEEP WATER SANDS, LONG BEACH UNIT, WILMINGTON FIELD, CALIFORNIA." In Giant Oil and Gas Fields. SEPM (Society for Sedimentary Geology), 1988. http://dx.doi.org/10.2110/cor.88.12.0031.
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"Palm Oil Mill Wastewater and Treatment." In Membrane Technology for Water and Wastewater Treatment in Rural Regions. IGI Global, 2020. http://dx.doi.org/10.4018/978-1-7998-2645-3.ch011.
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Palm oil is an essential agricultural commodity in Malaysia, as Malaysia is one of the largest producers and exporters globally. The processes of palm oil extraction and purification generate a large amount of wastewater known as palm oil mill effluent (POME). Currently, most treatment processes are carried out using a conventional ponding system which is outdated as it requires large land areas and long retention time. Discharge of poorly treated POME directly to the surroundings leads harms the environment, as it contains high contents of oil and BOD. Therefore, this chapter discusses the treatment method of POME from a newer perspective of membrane technology integrated with biological treatment. Various methods such as clarification system with nanofibre unit, cooling system, activated sludge system, and anaerobic membrane bioreactor, are reviewed on their principles of operation.
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Jäschke, Johannes, and Sigurd Skogestad. "A Self-Optimizing Strategy for Optimal Operation of a Preheating Train for a Crude Oil Unit." In Computer Aided Chemical Engineering. Elsevier, 2014. http://dx.doi.org/10.1016/b978-0-444-63456-6.50102-2.
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Haouache, Nahid, Soukaina El Asri, Adil Asfers, Abdelhadi Ait Houssa, Bouchra Tazi, and Ahmed Boughdad. "Valorization of Olive Mill Wastewater in the Control of Aphis pomi De Geer 1773 (Hemiptera, Aphididae) Infesting Apple Plants in Nurseries." In Insecticides [Working Title]. IntechOpen, 2021. http://dx.doi.org/10.5772/intechopen.100016.
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Olive mill wastewater (OMW), are the liquid residues generated during the extraction of oil by traditional and modern three-phase type crushing units. These effluents are characterized by an acidic pH and composition rich in water, organic matter, minerals and polyphenols. In general, they are directly discharged into natural ecosystems. Their danger is linked to the enormous quantities produced in a short period between October and March. To mitigate the effects of vegetable waters on the environment, their valorization in different areas is discussed. As biopesticides, crude OMW have been shown to be very toxic to Aphis pomi; the LC50 and LC95 varied respectively from 27.17 to 45.59 and from 77.19 to 134.57 mg of OMW/L of water; they vary according to the stage of the aphid considered. The young stages of A. pomi were more sensitive than the elderly are. Therefore, the OMW can be used as a means of controlling aphids. However, before operating on a large scale, it is necessary to repeat the trials in field and assess their impact on non-target organisms and treated crops.
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Muhsin, Wissam, and Jie Zhang. "Modelling and Optimal Operation of a Crude Oil Hydrotreating Process with Atmospheric Distillation Unit Utilising Stacked Neural Networks." In Computer Aided Chemical Engineering. Elsevier, 2017. http://dx.doi.org/10.1016/b978-0-444-63965-3.50415-3.
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"Script-, Function-Files and Program Managing." In Advances in Systems Analysis, Software Engineering, and High Performance Computing. IGI Global, 2021. http://dx.doi.org/10.4018/978-1-7998-7078-4.ch003.
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The Editor window for writing scripts and user-defined functions are presented, as well as the Live Editor window for writing live scripts and functions. All commands, regular and live scripts, and functions are explained by examples from the mechanics and tribology (M&T) fields. After that, the application examples are given; they include the stress unit converters, computing of the stress factor of a shaft with a transverse hole, gear warm K-parameter calculations, installation, and operation stresses on the piston ring.
Conference papers on the topic "Unit operation of oil fields"
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Rahman, Risal, Reyhan Hidayat, Pratika Siamsyah Kurniawati, et al. "New Well Intervention Means as an Answer to Offshore Minimalist Platform Concept: A Breakthrough from Mahakam, Indonesia." In SPE/IATMI Asia Pacific Oil & Gas Conference and Exhibition. SPE, 2021. http://dx.doi.org/10.2118/205800-ms.
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Abstract Nowadays oil and gas industry are encouraging the independents and majors to take a fresh look at the technology and concepts required to develop marginal shallow water fields using a minimal platform approach. Innovation on well intervention means (lighter, smaller and less footprint) that fit for Offshore Minimalist Platform (OMP) is needed, including optimizing time and cost during well intervention activities in OMP. To achieve the objectives, well intervention innovation and technology are the main focuses. Intervention activities commonly done on campaign basis with several units (slickline, wireline, coiled tubing, testing) shall be integrated in a safe manner. The approach of integration shall signify these points:Identifying potential jobs in OMP to be done by well intervention methodsIdentifying necessary well intervention means and methods to support the jobs (combo unit, micro coil, hazardous zone redefinition, remote operation)Creating project planning and schedulingPerforming site visit and risk assessmentImplementation and operational executionEvaluation of overall project execution result The following results were obtained after the integration performed:No major safety issues during operationExemplary method and risk assessment for well intervention activities which can be applied for next campaignsTrials on well intervention new units and method (combo unit, micro coil, hazardous zone redefinition, remote operation), were safely performed with some optimization100% success ratio60% on supply boat arrangement35% efficiency in N2 consumption for CT operation45% efficiency in diesel consumption20% - 40% efficiency in Rig Up Time28% less in Job Cost compared to conventional unit These innovations are proven as reliable method to answer OMP challenges with main advantages on footprint and cost optimization. Through this paper, we would like to share lucrative well intervention breakthrough and innovation in OMP with measurable milestones.
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Suzuki, Katsumasa, Shinpei Ota, Shuji Kasuya, and Ken Sugimura. "Intermittently Operated Oil Hydraulic Pump Unit With Accumulator to Save Energy and Hydraulic Assist for Restart." In ASME 2013 Fluids Engineering Division Summer Meeting. American Society of Mechanical Engineers, 2013. http://dx.doi.org/10.1115/fedsm2013-16380.
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Efforts to conserve energy have been made in a number of fields due to a shortage of energy resources, such as oil, and the need to protect the Earth’s environment. In the field of hydraulics, energy-saving pump units are very important because they consume less energy. At present, variable displacement type hydraulic pump units (VD pump units) and inverter control type pump units (INV pump units) are widely used. The authors propose using an intermittently operated pump unit coupled with an accumulator (ACC pump unit). It is verified that the ACC pump unit is superior to the others in terms of efficiency, especially when the flow rate to the load is small or the duty ratio for the intermittent work is low. However, the stop/restart operation of the electric motor for the pump drive is repeated frequently, and the instantaneous electric power consumed by the electric motor is more than six times the rated electricity when the pump is restarted. Therefore, we decreased the excess electricity consumption at pump restart using a method called “hydraulic assist”. Before the electric motor is turned on, high-pressure fluid is supplied to the pump inlet from the accumulator. The pressure at the pump outlet is made to be zero by opening the valve to the tank. The pump essentially works as a hydraulic motor. Then, the electric motor is turned on. In this method, the instantaneous electric power consumption is reduced. This method is also applied to a hydraulic pump unit driven by an internal combustion engine. The intermittent operation of the engine-driven hydraulic pump unit was accomplished using hydraulic assist to restart the pump. In this report, the energy-saving characteristics are shown.
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Al-Busaidi, Asaad, Ghusn Al-Shabibi, Ali Al-Khanbashi, et al. "Development of Inline Testing in Sour High Pressure Fields." In ADIPEC. SPE, 2022. http://dx.doi.org/10.2118/210891-ms.
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Abstract Newly drilled high-pressure sour wells require initial well testing before being hooked-up to a production facility. Mobile well test unit is sent to perforate, stimulate and test the new well potential. During operation, HC and H2S gases are flared to atmosphere. Innovative approach of Inline testing is invented by accelerating the well hookup and connecting the well to production station before well test unit intervention to avoid oil and gas flaring at well site. After well pad release, Hookup process normally takes 3-4 months with good practices applied for acceleration. A mobile well testing is then sent to perforate, stimulate, clean out and test the well. After well clean up completed and ensuring clean HC fluids flowing, well flow is diverted to the flowline producing to the production station and testing using Well Test Unit separator with clear sequenced standard procedures followed up and integrated among Well Test Unit, Engineering and Production teams to ensure safe operation. Inline testing approach was successfully implemented in two wells for the first time in high sour cluster fields in July-21 using CI methodologies and detailed risk assessments. A Flaring reduction of about 15% of total Oil flared in 2021 and 2% of gas during the two wells testing equivalent to more than 2,000 tons of CO2 emissions and a deferment reduction benefit of more than 1 mln USD. These results were achieved with good integration of different teams and stakeholders involved, clear operation procedures and live communications during the operation. Inline testing was then approved and planned for all coming new wells testing interventions (7-10 wells per year). These successful two pilot trials open wider opportunities for extending inline testing for existing flowing wells when Well Test Unit intervention is required. More emission reduction is expected, and more production deferment will be reduced.
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Sinaga, Rahmat, Boris Styward, and Garry Andrew Yandra. "Probabilistic Estimation of Rigless Plug and Abandonment Campaign in Mahakam Offshore Fields." In SPE Asia Pacific Oil & Gas Conference and Exhibition. SPE, 2022. http://dx.doi.org/10.2118/210781-ms.
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Abstract Under the low commodity prices, the operator of the marginal fields has been constantly initiating the ways to improve efficiency. Re-entry wells technique has been chosen as one of many to achieve the objective. Plug and abandonment (P&A) campaign has become massively conducted to prepare the wells for the re-entry. Moreover, a hydraulic workover unit (HWU) is utilized to support the drilling rigs in executing such projects in the last 3 (three) years. Since the nature of the operation involves multiple stakeholders, careful planning is required to ensure that the company's objectives are well delivered. Therefore, estimating duration of single well P&A is more critical to gain the better perspective in the early stages. This paper explains the probabilistic technique developed in forecasting the project's duration. Historical data are collected and multi-level statistical data analytics are performed to establish a tool for estimating the days, costs and finally providing valuable feedback for the initial planning. Utilizing the probabilistic method in this case for the last 5 (five) wells of P&A campaign has showed significant approximation to the actual days. Therefore, the operator is confidence to continuously use this method for the planning. Besides predicting the main scope of P&A works, the tool has accommodated the duration of the non-productive time (NPT) as well as the wait on weather (WOW) for each P&A well. Hence, the probabilistic method introduced in this paper can be beneficial not only for estimating but also enhancing the performance evaluation as the part of continuous improvement.
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Holt, Torleif, and Heiner Schümann. "Energy Efficient Operation of Petroleum Production Plants." In SPE Norway Subsurface Conference. SPE, 2022. http://dx.doi.org/10.2118/209539-ms.
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Abstract The use of energy and the possibilities for energy recovery from pressurised fluid streams has been analysed for a petroleum production plant connected to an undersaturated oil field that was produced by water injection. The plateau production of oil was 15900 Sm3/d and water was injected at a rate of 20670 m3/d. The produced fluids arrived at the production plant at a relatively high pressure and temperature (70 bar and 82 °C). Produced oil and gas were continuously exported from the plant at 200 bara. The power consumption in the plant could be reduced by using equipment with high efficiency. The average power over the 27-year lifetime of the field was reduced from 19.95 MW to 14.78 MW for two scenarios using different equipment. This corresponds to a reduced energy consumption and reduced CO2 emissions of 986 million kWh and 692502 tonnes, respectively. Energy can be recovered from pressurized process streams. For the hydrocarbon streams in the plant turbogenerators were considered. Pressure from produced water could be recovered by use of pressure exchangers. On average 2 MW power was recovered over the lifetime of the field, saving 486 million kWh electric energy corresponding to 341166 tonnes CO2 emissions. All energy savings above apply both to plants powered by gas turbines and electrified fields. CO2 emissions per unit of potential combustion energy from produced petroleum was very low in the plateau phase of the production. Only late in the lifetime of the field the emissions approached and exceeded (depending on scenario) the average emissions of 5 g CO2/MJ for fields on the Norwegian Continental Shelf. The high potential for reduced energy consumption in the petroleum production plant and for energy recovery was due to the relatively high inlet pressures to the plant and high pressures of injected water. For lower inlet pressures and better water injectivity the potential will be lower, and fields should be studied case by case. Factors such as weight and space requirements of new alternative process equipment, cost and maintenance have not been considered in this work. In an electrified field the abundant supply of thermal energy from gas turbine exhaust will not be available. Thermal energy was available from the produced fluids and from the petroleum processing and could be sufficient e.g. for heating of housing areas and heating of process streams. If higher temperatures were needed heat pumps can be taken into use. Dedicated and field specific studies regarding use and recovery of thermal energy and possible applications of heat pumps must be done to find optimal solutions for the thermal energy demand of an electrified field, however.
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Topolinsky, Ken M., and German D. Ordoñez R. "Colombian Crude Export System Begins Full Operation." In 1998 2nd International Pipeline Conference. American Society of Mechanical Engineers, 1998. http://dx.doi.org/10.1115/ipc1998-2009.
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Shipments began in October 1997 along Oleoducto Central S.A (OCENSA), the 837 km oil export system, consisting of 406, 762 and 914 mm (16”, 30” and 36”) diameter pipe, from eastern Colombia to the country’s north coast on the Carribean Sea. Start-up follows the completion of a phased construction program which began in 1993–94 and ended in September 1997. The system transports production from the Cusiana / Cupiagua oilfields, and several adjacent smaller production fields in the eastern foothills of the Andes to an offshore terminal loading unit 11 km offshore. The authors provide an operating overview of this system designed to handle some 88,410 m3/d (556 kbd) and some of its operating challenges.
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Fajardo, J., D. Yabrudy, D. Barreto, C. Negrete, B. Sarria, and C. Cardona. "Efficiency Centered Maintenance of Preheat Train of a Crude Oil Distillation Unit." In ASME 2020 International Mechanical Engineering Congress and Exposition. American Society of Mechanical Engineers, 2020. http://dx.doi.org/10.1115/imece2020-23186.
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Abstract Nowadays, maintenance is based on the synergistic integration of operational reliability and timely maintenance, which guarantees the required availability and optimal cost. Operational reliability implies producing more, better performance, longer life, and availability. Timely maintenance involves the least time out of service, fewer maintenance costs, fewer operating costs, and less money. In this work, we study the preheating train of a crude distillation unit of a refinery, which processes 994 m3/h, which presents a formation of a fouling layer inside it. Among the impacts of fouling is the reduction in the effectiveness of heat transfer, the increase in fuel consumption, the increase in CO2 emissions, the increase in maintenance costs, and the decrease in the profit margin of process. An appropriate cleaning program of the surface of the heat exchanger network is necessary to preserve its key performance parameters, preferably close to design values. This paper presents the maintenance method centered on energy efficiency, to plan the intervention of the preheating train equipment maintenance, which considers the economic energy improvement and the cost of the type of maintenance. The method requires the calculation of the fouling evolution from which the global heat transfer coefficient is obtained, and the heat flux is determined as a function of time. It was observed that, as time passes, the resistance provided by fouling increases and that the overall heat transfer coefficient decreases. The energy efficiency centered maintenance has an indicator of economic justification (factor J) that relates the economic-energy improvement achieved when performing maintenance, taking into account the economic effort invested. Depending on the cost of the type of maintenance to be performed, a threshold should be chosen, from which the maintenance activity is justified. The effectiveness values of the heat exchanger (ε) and the J indicator are used to form a criticality matrix, which allows prioritizing maintenance activities in each equipment. The planning of the implementation dates of the maintenance of each heat exchanger, from the maintenance method centered on energy efficiency applied to the crude distillation unit’s, preheat train, constitutes a contribution in this specific field. The conceptual design of the maintenance method centered on energy efficiency presented in this work is feasible for other heat transfer equipment used in oil refineries and industry in general. The procedure developed uses real operation values, and with its implementation, a saving of 150000 US dollars was achieved.
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Aljedaani, Abdulrahman, Mohammed AlOtaibi, Subhash Ayirala, and Ali Al-Yousef. "An Eco-Friendly and Low Carbon Footprint Water Treatment Technology for Produced Water Recycling." In SPE Middle East Oil & Gas Show and Conference. SPE, 2021. http://dx.doi.org/10.2118/204744-ms.
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Abstract Many challenges and limitations are experienced while treating the produced water in oil fields, due to large volumes of water produced together with oil. In this paper, we propose a new method to treat produced water, by integrating humidification and de-humidification desalination (HDH) unit with waste heat, extracted from abandoned oil and gas wells. This solution is based on circulating the produced water through abandoned wells (both vertical and horizontal wells) and heat them up to 60-80°C so that the heated water can be directly used as hot feed water into the HDH unit. This eliminates either electricity or power requirements from an external source thereby significantly lowering the energy requirements. The direct use of hot produced water at the desired temperature range allows for better performance of the HDH desalination unit, while reducing the operating cost, besides minimizing CO2 emissions to the environment. The use of heat extracted from abandoned oil and gas wells in the form of geothermal energy enables the utilization of waste heat associated with existing wells, which is already available in most of the oil fields. The proposed method therefore provides a sustainable renewable energy solution for produced water desalination using HDH processes.
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Al-Fazari, Mohamed Salim, Abdullah Khalifa AL-Hinai, and Hilal Mohammed AL-Ghefeili. "Decarbonizing Thermal Enhanced Oil Recovery Operations Through Improvements in Saturated Steam Distribution System." In SPE EuropEC - Europe Energy Conference featured at the 83rd EAGE Annual Conference & Exhibition. SPE, 2022. http://dx.doi.org/10.2118/209674-ms.
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Abstract Petroleum Development Oman LLC (PDO) is Oman's premier oil producer and operates several fields at "A". "A" East and "A" West are located on the eastern flank of the South Oman Salt Basin. As "A" thermal fields contain heavy oil, PDO plans to significantly increase oil recovery by increasing steam injection, which has high energy intensity. The objective of this paper is to demonstrate that the improvement in thermal EOR operation by initiating decarbonization initiatives resulted in a significant reduction in Green House Gases (GHG) emissions. Operational comparison of steam generation unit cost to produce one tonnage of steam for different combinations found that OTSGs is the most expensive combination as it is associated with higher taxation cost (i.e. 90% of total cost is from carbon tax). OT-HRSGs with Miraah Solar combination is found one of the best to reduce the overall unit cost and maximize the production. The Miraah Solar facility was built at "A" to cater for the steam growth requirement. The adaptation of Miraah shall reduce the annual gas usage related to steam production by utilizing the sun's radiation. This facility is one of the largest solar plants of its kind in the world. It has an energy production capacity of 330 MWe of peak thermal energy and daily steam output of 1,980 tons per day. An Energy Assessment (EA) had has been conducted for top energy consumers (e.g. OT-HRSGs, OTSGs, export pumps, etc.) to identify the top high GHG emitters and feature opportunities to reduce their carbon footprint. Miraah Solar enhancement was one of the identified opportunities that will result in GHG saving more than 100,000 TCO2e/yr. In 2021, a 41% improvement is seen in terms of production and GHG reduction. In addition, the Thermal Steam Integration System (SIS) is an integrated and novel system developed to allow all steam generators to be integrated into a system that will smooth the operation and enhance the availability of the steam system/network in both on-plot and off-plot.. This will allow us to reduce GHG emissions from steam systems by 80,000 tons CO2/year by 2030, as well as reduce power consumption by more than 36% from the base case.
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Maturana, Marcos Coelho, Victor Rafael Souza, Valentina Clavijo Mesa, Marcelo Ramos Martins, Anderson Takehiro Oshiro, and Adriana Miralles Schleder. "MIL and MIRO Diagrams for Risk-Based Positioning of Drilling Rigs With Dynamic Positioning System." In ASME 2020 39th International Conference on Ocean, Offshore and Arctic Engineering. American Society of Mechanical Engineers, 2020. http://dx.doi.org/10.1115/omae2020-18834.
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Abstract Currently, most offshore oil exploration operations are performed by Dynamically Positioned (DP) units; in Brazil, the use of these units is traditional in drilling operations (DP drilling rigs). The advent of DP systems, which allow the vessel to maintain a certain position without the need for anchor lines, has brought great flexibility to the oil field; however, usually in drilling areas, there are a large number of operations being performed simultaneously and subject to weather conditions and a failure of the DP system may cause these vessels to drift, which may occasionally result in a collision with other field equipment or vessels, causing material, personal and environmental damage. In this context, it is necessary to analyze what would be the best positioning points for these units according to the configuration of potential obstacles present in the area (such as risers, anchor systems and floating production systems), the characteristics of the DP unit and the expected environmental conditions. It is vital to know the risk of collision associated with the positioning of these units. The risk of collision will depend mainly on the meteo-oceanographic variables of the operating region, the hydrodynamic characteristics of the unit, the DP system reliability and its repair time, and the distribution of obstacles in the area. The objective of the ongoing research is the development of a methodology to define the risk associated with the positioning of the DP units, through a statistical method and a validated drift mathematical model under the influence of environmental agents. The proposed methodology allows us to demonstrate compliance with a widely accepted RAC (Risk Acceptance Criterion). The developed methodology proposes the use of two instruments: Location Iso-Probability Maps (MIL) and Operational Iso-Risk Maps (MIRO), to synthesize the information to the decision making about the operation of the DP units at a specific location, considering the overall collision risk (at MIRO) and the probability of the rig being at a specific location (at MIL).
Reports on the topic "Unit operation of oil fields"
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Hicks, Julie, Laurin Yates, and Jackie Pettway. Mat Sinking Unit supply study : Mississippi River revetment. Engineer Research and Development Center (U.S.), 2021. http://dx.doi.org/10.21079/11681/41867.
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The Mississippi Valley Division (MVD) has maintained the Mississippi River banks for over 80 years. The Mat Sinking Unit (MSU), built in 1946, was considered state-of-the-art at the time. This system is still in operation today and has placed over 1,000 miles of Articulated Concrete Mats along the Mississippi River from Head of Passes, LA, to Cairo, IL. A new MSU has been designed and is expected to be fully mission capable and operational by the 2023 season, which is expected to increase the productivity from 2,000 squares/day up to 8,000 squares/day with double shifts and optimal conditions. This MSU supply study identifies and optimizes the supply chain logistics for increased production rates from the mat fields to the MSU. The production rates investigated for this effort are 2,000 squares/day, 4,000 squares/day, and 6,000 squares/day. RiskyProject® software, which utilizes a Monte Carlo method to determine a range of durations, manpower, and supplies based on logical sequencing is used for this study. The study identifies several potential supply and demand issues with the increased daily production rates. Distance to casting fields, number of barges, and square availability are the major issues to supply increased placement rates identified by this study.
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Rokita, Dagmar, Rainer Sawatzki, and Raushan Szyzdykova. Energy Transition in Central Asia: a Short Review. Kazakh German University, 2022. http://dx.doi.org/10.29258/dkucrswp/2022/20-52.eng.
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The five countries of Central Asia, Kazakhstan, Kyrgyzstan, Uzbekistan, Tajikistan and Turkmenistan, have each adopted climate targets to achieve the climate goals agreed in Paris by 2050. In this paper, the starting positions of all five countries are presented and the respective obstacles on the path to climate neutrality are identified. The starting positions in the countries with large oil, gas or coal reserves (Kazakhstan, Uzbekistan and Turkmenistan) differ from the countries where the basis of energy supply are large hydroelectric plants (Kyrgyzstan and Tajikistan). One problem in all countries is the poorly developed power grid, which is partly outdated and not designed for high throughput rates. Existing power plants are mainly located in metropolitan regions and rural areas are partly undersupplied. If wind and solar power plants are built on a large scale in uninhabited areas, the lack of transmission lines is a major problem. Another problem is that energy prices are sometimes heavily subsidised, which can make it difficult for the population to accept necessary investments in the renewable energy sector. Especially in economically weak sections of the population, resistance to market-based energy prices is likely to be particularly strong. In the long term, information and increased education of large parts of the population can significantly improve the acceptance of the energy transition from carbon-based energy to solar, wind and small hydropower. The use of renewable energy is still in its infancy in all countries and must develop quickly if the ambitious climate goals are to be achieved. To this end, the training of local experts is particularly important. To this end, centres should be established at selected locations where local experts can be trained and further educated in various fields, from conception and planning to construction, maintenance and operation.