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Standalone museum focused on the Argentinian petroleum heritage. It offers educational program in indoor/outdoor exhibition spaces. The museum stands on the site of the first commercial oil well drilled in Argentina, the Pozo N 2 in 1907. The National University of Patagonia San Juan Bosco manages the museum since its opening in December 13, 1987. The collections of the museum consist mainly of donations from the YPF. Standalone museum mainly focused on the local petroleum exploration. It includes indoor/outdoor exhibition spaces.
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Selecting the appropriate tracer, and understanding the information gathered during awell to well tracer test requires consideration of how various tracers interact with, and therefore flow, through reservoir rock. When tracers are flowing in the reservoirs, it is normally a requirement that the compounds follow the phase they are going to trace. The best example of a passive water tracer is tritiated water (HTO). The HTO will, in all practical aspects, follow the water phase. For gas tracers, there are no known passive tracers.
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The capacity to flow fluids is one of the most important properties of reservoir rocks. As a result, extensive research has been applied to describe and understand the permeability of rocks tofluid flow. In this page and its associated topics, only single-phase or absolute permeability will be considered. Permeability (k) is a rock property relating the flow per unit area to the hydraulic gradient by Darcy's law, The ratio q/A has the units of velocity and is sometimes referred to as the "Darcy velocity" to distinguish it from the localized velocity of flow within pore channels. The natural unit ofk is length squared; however, petroleum usage castsEq. 1 in mixed units, so that the unit of k is the darcy, which is defined as the permeability of a porous medium filled with a single-phase fluid of 1-cp viscosity flowing at a rate of 1 cm3/s per cross-sectional area of 1 cm2 under a gradient of 1 atm pressure per 1 cm.[1]
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While downhole pumps and sucker rods are the chief components of a sucker-rod lift type artificial lift system, a number of other components are also used in the subsurface portion of the system. These include tubing, tubing anchor-catchers, tubing rotators, sinker bars, rod centralizers, and paraffin scrapers. Tubing provides detailed information on the design, selection, and use of tubing for production wells. As related to most sucker-rod-lifted wells, the standard weight of external-upset-end, API tubing[1] should be used because of the increased wall thickness in the threaded ends. Thus, if there is rod coupling-on-tubing wear, more life and fewer leaks will be realized than if nonupset API tubing is used. Using API Grade J55 tubing, consider full-body normalizing after upsetting to prevent "ringworm corrosion" in the heat-affected upset region when the tubing is placed in corrosive (H2S or CO2) service.
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Produced water typically enters the water-treatment system from either a two or three phase separator, a free water knockout, a gun barrel, a heater treater, or other primary separation unit process. It probably includes small amounts of free or dissolved hydrocarbons and solids that must be removed before the water can be re-used, injected or discharged. The level of removal (particularly for hydrocarbons) and disposal options are typically specified by state, province, or national regulations. This article discusses techniques for the removal of free and dissolved hydrocarbons. Intermittent flow * 3 Gas flotation units * 3.1 Dissolved gas units * 3.2 Dispersed gas units * 4 Deoiling hydrocyclones * 5 Centrifuges * 6 Walnut shell filters * 7 Removing dissolved hydrocarbons from water * 7.1 Hydrocarbon discharges * 7.2 Determining removal * 8 Nomenclature * 9 References * 10 Noteworthy papers in OnePetro * 11 Other noteworthy papers * 12 Online multimedia * 13 External links * 14 See also * 15 Page champions * 16 Category Produced water contains small concentrations (100 to 2000 mg/L) of dispersed hydrocarbons in the form of oil droplets. In applying these concepts, one must keep in mind the dispersion of large oil droplets to smaller ones and the coalescence of small droplets into larger ones, which takes place if energy is added to the system. The amount of energy added per unit time and the way in which it is added will determine whether dispersion or coalescence will take place. Stokes' law, shown in Eq. 1, is valid for the buoyant rise velocity of an oil droplet in a water-continuous phase. Several immediate conclusions can be drawn from this equation. The third conclusion requires further elaboration.
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Extraction of oil and gas from underground reservoirs often is accompanied by water or brine, which is referred to as produced water. As reservoirs mature, especially if secondary or tertiary recovery methods are used, the quantity of water climbs and often exceeds the volume of the hydrocarbons before the reservoir is exhausted. The cost of producing, handling, and disposing of the produced water often defines the economic lifetime of a field and the actual hydrocarbon reserves; therefore, understanding and predicting the aspects, behavior, and problems induced by the produced-water flow is important. This page provides an introduction to produced water, production mechanisms, economics, and characterization. Because the produced water is not usually a revenue stream, the emphasis on water-flow prediction, technology development, and engineering application has not traditionally been a major focus of oil- and gas-production engineering.
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This page discusses the specific artificial-lift technique known as beam pumping, or the sucker-rod lift method. Many books, technical articles, and industry standards have been published on the sucker-rod lift method and related technology.[1][2][3][4][5][6][7]Additionally, the other components of a sucker-rod pumping installation are discussed, including applicable engineering and operating information. The complete operating system should be understood and addressed to properly design, install, and operate this or any other type of artificial lift system. The Gipson and Swaim "Beam Pump Design Chain" is used as a foundation and built upon using relevant, published technology.[5][6][7] Beam pumping, or the sucker-rod lift method, is the oldest and most widely used type of artificial lift for most wells. A sucker-rod pumping system is made up of several components, some of which operate aboveground and other parts of which operate underground, down in the well. The surface-pumping unit, which drives the underground pump, consists of a prime mover (usually an electric motor) and, normally, a beam fixed to a pivotal post. The post is called a Sampson post, and the beam is normally called a walking beam.Figs. 1 and 2 present a detailed schematics of a typical beam-pump installation. This system allows the beam to rock back and forth, moving the downhole components up and down in the process.
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Flow-control accessories add to the flexibility of the cased-hole completion design and perform a multitude of tasks, such as: * Temporarily plugging off the tubing string. Profile seating nipples and sliding sleeves have a special locking groove and a honed sealbore to allow a flow-control device to lock in the nipple and seal off when installed. By design, the sleeves and nipples will have a smaller inside diameter (ID) than that of the tubing string. For this reason, careful consideration must be given to the overall application and completion design when selecting and sizing the various models of profile seating nipples and sleeves. This is especially true in any case in which through-tubing operations or perforating are planned.
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