Hot-Water and Steamflood Laboratory Experiments Under Reservoir Conditions

1988 ◽  
Vol 3 (01) ◽  
pp. 149-157 ◽  
Author(s):  
L. Quettier ◽  
B. Core
Keyword(s):  
Laboratory Experiments ◽  
Hot Water ◽  
Reservoir Conditions

scholarly journals Semi-commercial hot water treatments for control of bull’s eye rot of apples

2019 ◽  
Vol 72 ◽  
pp. 284
Author(s):  
Luna Hasna ◽  
Kerry R. Everett ◽  
Michelle J. Vergara ◽  
I.P. Shamini Pushparajah ◽  
Peter N. Wood ◽  
...  
Keyword(s):  
Fungal Pathogen ◽  
Laboratory Experiments ◽  
Hot Water ◽  
Commercial Test ◽  
Commercial Trial ◽  
Fold Reduction ◽  
High Incidence ◽  
Pressure Water ◽  
Bull's Eye ◽  
Water Treatments

Bull’s eye rot (BER) of apples is caused by a postharvest fungal pathogen (Phlyctema vagabunda syn. Neofabraea alba). Previous laboratory experiments found hot water treatments (HWT) resulted in a significant reduction of BER incidence for artificially inoculated fruit so the feasibility of HWT to control naturally infected fruit in a semi-commercial trial was tested. One bin (1934 fruit) of naturally infected ‘Scired’ apples was harvested from a Hawke’s Bay orchard with a known high incidence of BER, then placed in a coolstore for 1 week until treated. All fruit were passed through a high-pressure water blaster then air dried. Approximately half the contents of the bin (1034 fruit) were packed into Friday trays in apple boxes with a plastic polyliner. The other half (900 fruit) were treated for 2 min with hot water at 51°C in a semi-commercial hot water bath before packing. All fruit were then coolstored for 20 weeks before assessment for BER. This HWT resulted in a 6-fold reduction of BER incidence so was an effective treatment for BER in a semi-commercial test.

scholarly journals Characterization of a Reservoir Fluid Based on an Analysis of Intrinsic Properties Using the Adaptive Batzle-Wang Method in Field “M”

2019 ◽  
Vol 17 (2) ◽  
Author(s):  
M. Syamsu Rosid ◽  
Muhammad` Iksan ◽  
Reza Wardhana ◽  
M. Wahdanadi Haidar
Keyword(s):  
Physical Properties ◽  
Laboratory Experiments ◽  
Fluid Model ◽  
Rock Physics ◽  
P Wave ◽  
Fluid Replacement ◽  
Intrinsic Properties ◽  
Temperature Conditions ◽  
Reservoir Conditions ◽  
Fluid Properties

The physical properties and phases of a fluid under reservoir conditions are different from those under surface conditions. The value of a fluid property may change as a result of changes in pressure and temperature. An analysis of the intrinsic properties of fluids is carried out to obtain a fluid model that corresponds to fluid conditions in a reservoir. This study uses the Adaptive Batzle-Wang model, which combines thermodynamic relationships, empirical data trends, and experimental fluid data from the laboratory to estimate the effects of pressure and temperature on fluid properties. The Adaptive Batzle-Wang method is used because the usual Batzle-Wang method is less suitable for describing the physical properties of a fluid under the conditions in the field studied here. The Batzle-Wang fluid model therefore needs to be modified to obtain a fluid model that adjusts to the fluid conditions in each study area. In this paper, the Adaptive Batzle-Wang model is used to model three types of fluid i.e. oil, gas, and water. By making use of data on the intrinsic fluid properties such as the specific gravity of the gases (G), the Gas-Oil Ratio (GOR), the Oil FVF (Bo), the API values, the Salinity, and the Fluid Density obtained from laboratory experiments, the Batzle-Wang fluid model is converted into the Adaptive Batzle-Wang model by adding equations for the intrinsic fluid properties under the pressure and temperature conditions in the field reservoir. The results obtained are the values of the bulk modulus (K), the density (ρ), and the P-wave velocity (Vp) of the fluid under reservoir conditions. The correlation coefficient of the Adaptive Batzle-Wang model with the fluid data from the laboratory experiments is 0.95. The model is well able to calculate the fluid properties corresponding to the conditions in this field reservoir. The model also generates a unique value for the fluid properties in each study area. So, it can adjust to the pressure and temperature conditions of the field reservoir under study. The Adaptive Batzle-Wang method can therefore be applied to fields for which laboratory fluid data is available, especially fields with a high reservoir pressure and temperature. The results of the fluid modeling can then be used for rock physics and Fluid Replacement Model analysis.

Reservoir Conditions Laboratory Experiments of CO2 Injection Into Fractured Cores

2006 ◽  
Author(s):  
Gholam Reza Darvish ◽  
Erik G.B. Lindeberg ◽  
Torleif Holt ◽  
Jon Kleppe ◽  
Svein Arild Utne
Keyword(s):  
Laboratory Experiments ◽  
Co2 Injection ◽  
Reservoir Conditions

Calculation Methods for Linear and Radial Steam Flow in Oil Reservoirs

1983 ◽  
Vol 23 (03) ◽  
pp. 427-439 ◽  
Author(s):  
J. van Lookeren
Keyword(s):  
Laboratory Experiments ◽  
Steam Injection ◽  
Injection Rate ◽  
Hot Water ◽  
Oil Reservoirs ◽  
Steam Flow ◽  
Volatile Components ◽  
Calculation Methods ◽  
Oil Viscosity ◽  
Injection Wells

Abstract The flow of oil and water in a reservoir as a result of steam injection is related to the shape of the growing steam zone. Analytical formulas describing the approximate shape of this zone have been derived both for linear flow in horizontal and dipping formations and for radial flow around injection wells in a horizontal formation. The theory is based on segregated-flow principles such as those previously used by Dupuit,1 Dietz,2 and others. The formulas take into account gravity overlay of steam zones and have been checked against results of scaled laboratory experiments, steam-injction projects in the field, and calculations with a numerical reservoir simulator. From the good agreement with the new calculation method it would seem that the shape of a steam zone is controlled mainly by one group of parameters including steam-injection rate, pressure, and effective formation permeability to steam. The equations can be used to analyze and explain field observations, such as the position of steam/liquid contacts in injection wells, estimates of effective permeability to steam in steam zones, and steam-zone thickness as noticed in observation wells. This paper shows, for example, how a cumulative oil/steam ratio for oil displaced from a steam zone depends on steam-zone pressure, injection rate, and time. With increasing oil viscosity, more bypassing of oil by steam owing to viscous forces will occur, leading to more overlay of steam zones and eventually to narrow tonguing in a lateral direction. The calculation methods provide an evaluation tool for steam drive and steam-soak processes to reservoir engineers engaged in field operations, project design, and research. Introduction The reservoir engineer is often confronted with many day-to-day problems in designing, planning, and starting up steam-injection projects and monitoring their performance analysis and improvement in which fast and simple, although approximate, engineering calculation methods could be used to advantage. By presenting calculation methods for linear and radial steam flow in oil reservoirs, a tool is provided to gain a better understanding of the shape and growth of steam zones in reservoirs subjected to steam injection. A selection has been made from reservoir engineering literature, laboratory experiments, and field data to introduce the essentials of the calculation methods for making estimates with respect to performance, sweep efficiency, optimization, etc., of steam-injection processes in actual oil reservoirs. Oil displaced from steam zones is calculated, but no attempt has been made to arrive at a full prediction tool for oil production from reservoirs by adding calculations for oil quantities displaced by cold- and hot-water drives and even miscible drives, if the oil has volatile components. With the present capacities of mathematical reservoir simulation programs, adequate integration of simultaneously occurring oil-displacement processes seems more appropriate for the large computer.

A New Tool-less Layered Fracturing Technology and Its Pilot Application in Deep Thick Formations

2016 ◽  
Author(s):  
Daobing Wang ◽  
Fujian Zhou ◽  
Hongkui Ge ◽  
Xiongfei Liu ◽  
Sergio Zlotnik ◽  
...  
Keyword(s):  
Pressure Difference ◽  
Laboratory Experiments ◽  
Degradation Rate ◽  
Oil Reservoir ◽  
Great Success ◽  
Test Results ◽  
Reservoir Conditions ◽  
Net Pressure ◽  
Temperature And Pressure ◽  
Fiber Ball

ABSTRACT Multi-layer fracturing technology is challenging because of the risk of packer failure and high cost in the deep thick formation. It depends largely on the effectiveness of packer tools. However, a new degradable fiber ball could be successfully used to temporarily block the open perforations, and then the layer with higher fracturing pressure is broken down. This paper presents a new tool-less layered fracturing technique and its pilot test results with this special material. A series of laboratory experiments were conducted to evaluate the feasibility of this new technique. Degradable fiber balls were applied to perforated pipes under simulated reservoir conditions. The ball carried by the fluid first sealed the perforation holes and then increased the pressure in the pipe to simulate the resistance to pressure. In addition, the fluid was heated up to 140°C to simulate the degradation rate of fiber balls. Throughout these processes, the flow rate, temperature and pressure were continuously monitored for subsequent analysis. Experimental and application results showed that: (1) fiber balls could be thoroughly degraded at 140°C temperature after six hours; (2) at a pressure difference of 50-70MPa, its deformation rate was less than 1.5%, which indicated its higher compression capability; (3) it could effectively block the perforation holes at 90°C and a pressure difference of 20MPa; (4) The blockage of perforations by the fiber ball could significantly enlarge the net pressure in the wellbore. This technique was applied for 35 wells in a deep and thick oil reservoir, which had achieved a great success and the post-treatment oil production was enhanced by 50-60% compared with conventional stimulation techniques.

Study of the Efficiency of Gel and Polymer-Stabilized Foam Systems for Gas Shut-Off in Horizontal Wells

2021 ◽  
Author(s):  
Maiia Vladimirovna Zvada ◽  
Pavel Nikolaevich Belovus ◽  
Evgeny Ivanovich Sergeev ◽  
Nikolay Grigorevich Glavnov ◽  
Mikhail Alekseevich Varfolomeev ◽  
...  
Keyword(s):  
Laboratory Experiments ◽  
Horizontal Wells ◽  
Economic Effects ◽  
Laboratory Studies ◽  
Core Flooding ◽  
Foaming Agents ◽  
Subsequent Determination ◽  
Reservoir Conditions ◽  
Polymer Stabilized

Abstract This article describes the assessment of effectiveness of gel and foaming agents for gas shut-off treatments in horizontal wells. The research is carried out through the implementation of a complex of special laboratory studies and analysis of the results using numerical modeling methods. A list of necessary laboratory experiments to minimize risks when carrying out work to limit gas inflow has been formulated, and approaches to carrying it out have been described. The program includes: free volume studies, filtration on linear and parallel core models. The results confirm the importance of studying not only the agent's physical characteristics at the reservoir conditions, but their interaction with reservoir fluids. The influence of different agents on the mobility of gas and oil was assessed as a result of linear core flooding experiments. In addition, the filtration tests on parallel cores were carried out aimed to determining the saturation selectivity. The series of numerical calculations was performed for the subsequent determination of the technological and economic effects of the treatment with gas blockers.

Multi-layer hydraulic exchange flows

2000 ◽  
Vol 416 ◽  
pp. 269-296 ◽  
Author(s):  
G. F. LANE-SERFF ◽  
D. A. SMEED ◽  
C. R. POSTLETHWAITE
Keyword(s):  
Internal Wave ◽  
Laboratory Experiments ◽  
Rectangular Cross Section ◽  
Wave Mode ◽  
Uniform Density ◽  
Exchange Flow ◽  
Hydraulic Control ◽  
Narrow Channels ◽  
Reservoir Conditions ◽  
Flow Through

Flows between ocean basins are often controlled by narrow channels and shallow sills. A multi-layer hydraulic control theory is developed for exchange flow through such constrictions. The theory is based on the inviscid shallow-water equations and extends the functional approach introduced by Gill (1977) and developed by Dalziel (1991). The flows considered are those in rectangular–cross-section channels connecting two large reservoirs, with a single constriction (sill and/or narrows). The exchange flow depends on the stratification in the two reservoirs, represented as a finite number of immiscible layers of (different) uniform density. For most cases the flow is ‘controlled’ at the constriction and often at other points along the channel (virtual controls) too. As with one- and two-layer hydraulics, controls are locations at which the flow passes from one solution branch to another, and at which (at least) one internal wave mode is stationary. The theory is applied to three-layer flows, which have two internal wave modes, predicting interface heights and layer fluxes from the given reservoir conditions. The theoretical results for three-layer flows are compared to a comprehensive set of laboratory experiments and found to give good agreement. The laboratory experiments also show other features of the flow, such as the formation of waves on the interfaces. The implications of the results for oceanographic flows and ocean modelling are discussed.

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