scholarly journals KINERJA POMPA JET EJECTOR DENGAN MODIFIKASI HELMHOLTZ RESONATOR PADA PIPA NORMAL SHOCK

ARIKA ◽  
2021 ◽  
Vol 15 (2) ◽  
pp. 94-103
Author(s):  
Mesak Frits Noya ◽  
Rusdy Rumeon ◽  
P. W. Tetelepta ◽  
Abdul Hadi
Keyword(s):  
Fluid Flow ◽  
High Capacity ◽  
Helmholtz Resonator ◽  
Acoustic Properties ◽  
Normal Shock ◽  
Flow Meter ◽  
Fluid System ◽  
Flow Capacity ◽  
Injection Pump ◽  
Ejector Pump

Setiap fluida yang mengalir selalu memiliki bunyi dengan intensitas dan frekwensi tertentu di dalam atau diluar ambang batas audio. Sifat akustik dari aliran fluida ini menjadi ide untuk memodifikasi normal shock diffuser dari suatu sistem fluida dengan menerapkan helmholtz resonator sebagai pengganti normal shock diffuser dengan menggabungkan dua pompa yang di aliri fluida, yaitu pompa sentrifugal tekanan rendah berkapasitas tinggi dan pompa injeksi tekanan tinggi berkapasitas rendah. Penelitian ini bertujuan untuk menentukan berapa besar pengaruh variasi jumlah pipa kapiler helmholtz resonator terhadap kinerja aliran fluida hidrolik booster-jet ejector pump. Penelitian ini bersifat eksperimental, dengan menerapkan sensor magneto flow meter arduino mega untuk mengukur kapasitas aliran fluida. Hasil penelitian ini menunjukan daya terbesar berada pada helmholtz resonator dengan jumlah 4 pipa kapiler yaitu sebesar 170,914353 Watt. Disimpulkan bahwa kinerja pompa jet-ejector mengalami peningkatan sebesar 36% dari daya sebesar 125 Watt sebelum modifikasi. Kata Kunci : Booster Jet Ejector, Resonator Helmholtz, Normal Shock Every fluid that flows always has a sound with a certain intensity and frequency, within or outside the audio threshold. The acoustic properties of this fluid flow became the idea to modify the normal shock diffuser of a fluid system by applying a Helmholtz resonator as a substitute for the normal shock diffuser by combining two pumps that are fed with fluid entering through a high-capacity low-pressure centrifugal pump and the other pump namely high pressure -low capacity injection pump. This study aims to determine how much the variation in the number of Helmholtz resonator capillaries towards performance of the hydraulic fluid flow of the booster-jet ejector pump. This research is experimental, by applying the arduino mega magneto flow meter sensor to measure the fluid flow capacity. The results of this study show that the greatest power is in the helmholtz resonator with a total of 4 capillary pipes, which is 170.914353 Watt. It is concluded that the performance of the jet-ejector pump has increased by 36% from the power of 125 Watt before modification. Keywords: Booster Jet Ejector, Helmholtz Resonator, Normal Shock

The Uniform Distribution of a Fluid Flowing Through a Perforated Pipe

1950 ◽  
Vol 17 (4) ◽  
pp. 431-438
Author(s):  
Willard M. Dow
Keyword(s):  
Fluid Flow ◽  
High Capacity ◽  
Practical Significance ◽  
Linear Rate ◽  
Gaseous Fuels ◽  
Extended Range ◽  
Flow Through ◽  
Perforated Pipe ◽  
Special Case ◽  
Theoretical Results

Abstract A theoretical analysis is made of the flow through a perforated pipe with a closed end for the special case of a constant linear rate of discharge along the length of the pipe. The results of the fluid-flow considerations are applicable to many practical manifold systems. The practical significance of the results with respect to pipe burners for gaseous fuels is emphasized as the results make possible the design of simple high-capacity and extended-range pipe burners of industrial importance. The capacity of commercially available pipe burners may be increased several hundred per cent. The validity of the theoretical results was verified by experiment.

Long-term burial history and orogenic-scale fluid flow depicted from stable isotopes and stylolite paleopiezometry in the Umbria-Marches arcuate belt (Northern Apennines, Italy).

2020 ◽  
Author(s):  
Nicolas Beaudoin ◽  
Aurélie Labeur ◽  
Olivier Lacombe ◽  
Guilhem Hoareau ◽  
Marta Marchegiano ◽  
...  
Keyword(s):  
Fluid Flow ◽  
Local Maximum ◽  
Geothermal Gradient ◽  
Burial Depth ◽  
Fold Axis ◽  
Clumped Isotopes ◽  
Burial History ◽  
Fluid System ◽  
Calcite Veins ◽  
Absolute Dating

<p>Faults, joints and stylolites are ubiquitous features in fold-and-thrust belts, and have been used for decades to reconstruct the past fluid flow (or plumbing system) at the scale of folded reservoirs/basins. The textural and geochemical study of the minerals filling the fractures makes it possible to unravel the history of fluid flow in an orogen, when combined with a knowledge of the burial history and/or of the paleothermal gradient. In most cases, the latter derives from the former, itself often argued over, limiting the interpretations of past fluid temperatures. Yet, recent methodological developments applied to carbonates and calcite fillings provide new perspectives for a more accurate reconstruction of the temperature, pressure and timing of the fluids that were present in the strata at the time they deformed, at every stage of fold development. Indeed, the temperature at which fluids precipitated can be obtained by Δ<sup>47</sup>CO2 clumped isotopes while the timing of calcite precipitation in veins and faults is given by U-Pb absolute dating. Also, the maximum burial depth of strata before contraction can be estimated using sedimentary stylolite paleopiezometry, hence in a way free of any consideration about the geothermal gradient.<br><br>These techniques were jointly applied at the scale of the Umbria-Marches arcuate belt (UMAR, Northen Apennines, Italy). Mesoscale faults and vein sets were measured and sampled in the Cretaceous-Eocene rocks. Focusing on those fractures that developed during Layer Parallel Shortening (LPS, i.e. oriented NE-SW to E-W) and during folding (i.e. oriented parallel to local fold axis), paleofluid sources, temperatures and timing were reconstructed using U-Pb absolute dating, Δ<sup>47</sup>CO2 clumped isotopes as well as δ<sup>18</sup>O, δ<sup>13</sup>C, and <sup>87/86</sup>Sr signatures of calcite veins. Results show a regional divide in the fluid system, with most of the belt including the foreland recording a fluid system involving basinal brines resulting at various degree from fluid-rock interactions (FRI) between pristine marine fluids (δ<sup>18</sup>O<sub>fluid</sub><span>= 0‰ SMOW) and surrounding limestones (δ<sup>18</sup>O<sub>fluid</sub>= 10‰ SMOW). Precipitation temperatures (35°C to 75°C) appear consistent with the burial history unraveled by sedimentary stylolite roughness paleopiezometry (600 m to 1500m in the range) and estimated geothermal gradient (23°C/km, Caricchi et al., 2004). As the degree of FRI increases forelandward, we propose a lateral, strata-bound, squeegee-type migration of fluids during folding and thrusting. In the western hinterland however, the fluid system rather involves hydrothermal fluids with a higher degree of FRI, the corresponding precipitation temperatures (100°C to 130°C) of which are inconsistent with local maximum burial (1500m). As the Sr radiogenic signatures preclude any deep origin of the fluids, we propose that the fluid system prevailing in the hinterland during LPS reflects the eastward migration of formational fluids originating from the Tuscan basin, located west from the UMAR, where studied Cretaceous rocks were buried under more than 4 km of sediments during the Miocene.</span></p><p><br>Beyond being the first combination of paleofluid geochemistry and burial estimates through paleopiezometry, this fluid flow model illustrates how the large scale structures may control the fluid system at the scale of a mountain belt.</p>

scholarly journals A LABORATORY SYSTEM FOR INVESTIGATING OF FLUIDS FLOW CAPACITY THROUGH UNCONSOLIDATED SAND SAMPLES

2020 ◽  
Vol 17 (36) ◽  
pp. 634-645
Author(s):  
Izzat Niazi SULAIMAN ◽  
Yahya Jirjees TAWFEEQ
Keyword(s):  
Porous Media ◽  
Fluid Flow ◽  
Steady State ◽  
Relative Permeability ◽  
Flow Rate ◽  
Pressure Difference ◽  
Absolute Permeability ◽  
Sand Sample ◽  
Flow Capacity ◽  
State Process

Practically all studies of reservoir engineering involve detailed knowledge of fluid flow characteristics. The fluid flow performance in porous media is affected by pressure, flow rate, and volume of single fluid phases. Permeability is a measure of how well a porous media allows the flow of fluids through it. Permeability and porosity form the two significant characteristics of reservoir rocks. This research aimed to present the design of laboratory equipment to test the ability of fluid flow through different sandstone samples. Two sand core samples (coarse sand sample and fine sand sample) were tested. The laboratory findings measurements of porosity, saturation, total permeability, effective permeability, and relative permeability were evaluated. The laboratory tests were performed on partially saturated, unconsolidated core sand for two-phase fluid flow. The experimental work was developed for measuring the flow capacity achieved under the steady-state conditions method. Various grain sizes sands were selected as a porous medium to determine petrophysical properties and fluid flow capacity of the rock sample. Nitrogen and air were utilized as gas-phases, and, for liquid-phases, water was chosen as an injection fluid. The steady-state process method was used to determine the permeability and relative permeability of unconsolidated sands to water flow. Different flow rates were measured for different pressure gradients in a viscose flow. As the flow rate increases, the pressure difference also increased. It can be observed that there are a direct correlation and relationship between the flow rate and the pressure difference. The core plug's absolute permeability was measured using Darcy Equation. Absolute permeability does not depend on fluid characteristics but only on media properties. The sample container contains a more significant amount of sand, decrease the permeability, and therefore requires high pressure for fluid flowing within the sample.

Reservoir Quality and Flow Unit Characterization of a Reservoir in X Field, Baram Delta

2020 ◽  
Vol 17 (2) ◽  
pp. 1447-1459
Author(s):  
Najmuddin Abdul Rahim ◽  
Wan Ismail Wan Yusoff
Keyword(s):  
Fluid Flow ◽  
Depositional Environment ◽  
Flow Unit ◽  
Reservoir Quality ◽  
Facies Distribution ◽  
Flow Capacity ◽  
Porosity And Permeability ◽  
Core Descriptions ◽  
Reservoir Facies ◽  
Permeability Data

Reservoir stratigraphic continuity are uncertainties that may be due to lack of facies association definition in reservoirs. These uncertainties come into play where proper porosity–permeability (poroperm) evaluation is misrepresented, leading to volumetric estimation uncertainties. Most oil fields in the Baram Delta have been previously studied with the development of static models. The lack of sequence stratigraphic input in the study was due to constraints including fault shadowing and gas chimney presence which deterred the volume estimations. Earlier interpretation of facies distribution and depositional environment of a field, named X, was achieved mainly by using core descriptions and interpretations. In this study, a reinterpretation of the depositional environment and facies distribution were carried out in the R1 and R2 reservoirs. The analysis was done by incorporating the depositional environment and facies with newly interpreted facies comprising of sand, silty sand, sandy shale and shale facies, created using neural network programme. Utilising newly set facies definitions with additional inputs including porosity and permeability data, a better facies distribution for the reservoir is emplaced. With the facies definitions set for 3 wells, the reservoir quality was investigated through poroperm relationship, reservoir quality index (RQI) and fluid flow unit interpretation. The new definitions for reservoir facies consequently matched well to the core descriptions. The R1 reservoir facies-poroperm relationship were clustered well with respect to each facies type. The RQI was then evaluated from the permeability and porosity values for all the selected wells. The fluid flow units were estimated using depth interval difference, effective porosity and permeability data. The fluid flow regimes are different for all the wells, where the updip Well B displayed significantly better flow capacity than both Well C and Well A. However, Well C also displayed good fluid flow capability, indicated by high gradient flow capacity over storage capacity, although with presence of some layers of poor flow quality. Good communication for the downdip wells provides a potential for lateral fluid flow component which can influence the storage and flow capacity of fluid in the updip Well A, and thus creating an overall control and validation of fluid capacity in the reservoir.

Impacts of mineralogy on micro-scale pore structure and fluid flow capacity of deeply buried sandstone reservoirs

2020 ◽  
Author(s):  
Juncheng Qiao ◽  
Jianhui Zeng ◽  
Xiao Feng
Keyword(s):  
Fluid Flow ◽  
Pore Structure ◽  
Pore Size ◽  
Clay Minerals ◽  
Mercury Porosimetry ◽  
Pore Geometry ◽  
Pore System ◽  
Intergranular Porosity ◽  
Micro Scale ◽  
Flow Capacity

<p>Hydrocarbon exploration is extending from the shallowly buried to deeply buried strata with increasing demands for fossil fuels. The variable storage and percolation capacities that intrinsically depend on the pore geometry restrict the hydrocarbon recovery and displacement efficiency and trigger studies on the micro-scale pore structure, fluid flow capacity, and their controlling factors. Minerals within sandstone are the results of the coupling control of depositional factors and diagenetic alternations, which determine the microscopic pore geometry and subsequently affect the fluid flow capacity. In order to investigate the impacts of mineralogy on the pore structure and fluid flow capacity, integrated analyses including porosity and permeability measurements, casting thin section (CTS), scanning electron microscopy (SEM), pressure-controlled mercury porosimetry (PCP), rate-controlled mercury porosimetry (RCP), nuclear magnetic resonance (NMR), and X-ray diffraction (XRD) are conducted on the deeply buried sandstone samples in the Jurassic Sangonghe Formation of the Junggar Basin. Microscopic pore structure is characterized by the combination of SEM, CTS, PCP, and RCP and fractal theory. Fluid flow capacity is evaluated by the innovative application of film bound water model in NMR and mineralogy is quantitatively measured by XRD. The results indicate that the deeply buried sandstone is rich in quartz (54.2%), feldspar (25.1%), and clay (14.2%), with dominant kaolinite (5.04%) and chlorite (5.38%) cementation. The reservoir has a wide pore-throat diameter distribution with three peaks in the ranges 0.01–1, 10–80, and 200–1000 μm. Pores are tri-fractal and can be divided into micropores, mesopores, and macropores, with average porosity contributions of 50.11, 21.83, and 28.04%, respectively. The movable porosity of deeply buried sandstone ranges from 1.75 to 8.24%, primarily contributed by intergranular (avg. 2.34%) and intragranular pores (avg. 2.56%). Most of the fluids are movable in intergranular pores but are irreducible in intragranular pores. Correlation analyses between mineralogy and pore structure suggest that quartz provides preservation to intergranular porosity, which increases pore size and macropores porosity and reduces heterogeneity of the pore system. The influence of feldspar reverses and becomes poor owing to the simultaneous clay precipitation and complex roles of feldspar dissolution in microporosity. Chlorite, kaolinite, and illite, all act as destructions to intergranular porosity. They enhance the mesopores and micropores porosities, reduce the pore size, and increase the microscopic heterogeneities of the macropores, micropores, and whole pore system. The relationships between mineralogy and fluid flow capacity indicate that quartz is favorable for the fluid flow capacity, but feldspar and clay play negative roles. The reversed impacts of quartz and feldspar lay in their opposite controls on pore size. However, both pore size and hydrophilia should be taken into account when considering the effects of clay minerals. These negative effects are associated with types, contents, and hydrophilic degrees of clay minerals, in which I/S and illite exhibit the strongest negative impacts. The fluid flow in the intergranular and intragranular pores is generally enhanced by higher quartz content, but reduced by higher clay content. Irreducible fluids in the intergranular and intragranular pores are determined by chlorite and kaolinite contents, respectively.</p>

Magnetic fluid flow meter for gases

1994 ◽  
Vol 30 (2) ◽  
pp. 936-938 ◽  
Author(s):  
N.C. Popa ◽  
I. Potencz ◽  
L. Vekas
Keyword(s):  
Fluid Flow ◽  
Magnetic Fluid ◽  
Flow Meter
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