Strategies for Improving Sweep Efficiency and Waterflood Recovery in a Complex Reservoir in the Greater Burgan Field; Learning from a Pilot Water Injection Project and Evaluation Using Sector Model Simulation.

2013 ◽  
Author(s):  
Sasi Rajan ◽  
Megdad Al-Naqi ◽  
Alaa Ali Ameen ◽  
Haya Hussain Al-Hashash ◽  
Sethu Madhavan ◽  
...  
Keyword(s):  
Model Simulation ◽  
Water Injection ◽  
Sweep Efficiency ◽  
Sector Model

Carbonated Water Injection for Recovery of Oil and Wettability Analysis

2014 ◽  
Vol 695 ◽  
pp. 499-502 ◽  
Author(s):  
Mohamad Faizul Mat Ali ◽  
Radzuan Junin ◽  
Nor Hidayah Md Aziz ◽  
Adibah Salleh
Keyword(s):  
Oil Recovery ◽  
Oil And Gas ◽  
Promising Result ◽  
Water Injection ◽  
High Mobility ◽  
Wettability Alteration ◽  
Sweep Efficiency ◽  
Gas Flooding ◽  
Carbonated Water Injection ◽  
Carbonated Water

Malaysia oilfield especially in Malay basin has currently show sign of maturity phase which involving high water-cut and also pressure declining. In recent event, Malaysia through Petroliam Nasional Berhad (PETRONAS) will be first implemented an enhanced oil recovery (EOR) project at the Tapis oilfield and is scheduled to start operations in 2014. In this project, techniques utilizing water-alternating-gas (WAG) injection which is a type of gas flooding method in EOR are expected to improve oil recovery to the field. However, application of gas flooding in EOR process has a few flaws which including poor sweep efficiency due to high mobility ratio of oil and gas that promotes an early breakthrough. Therefore, a concept of carbonated water injection (CWI) in which utilizing CO2, has ability to dissolve in water prior to injection was applied. This study is carried out to assess the suitability of CWI to be implemented in improving oil recovery in simulated sandstone reservoir. A series of displacement test to investigate the range of recovery improvement at different CO2 concentrations was carried out with different recovery mode stages. Wettability alteration properties of CWI also become one of the focuses of the study. The outcome of this study has shown a promising result in recovered residual oil by alternating the wettability characteristic of porous media becomes more water-wet.

Utilisation d'un modèle stochastique de réseaux de fractures pour étudier les propriétés hydrauliques d'un massif fissuré

1989 ◽  
Vol 26 (2) ◽  
pp. 313-323
Author(s):  
Lahcen Ait-Ssi ◽  
Jean-Pierre Villeneuve ◽  
Alain Rouleau
Keyword(s):  
Rock Mass ◽  
Hydraulic Properties ◽  
Model Simulation ◽  
Water Injection ◽  
Stochastic Simulations ◽  
Fracture Aperture ◽  
Modèle Stochastique ◽  
Fracture System ◽  
Fracture Porosity ◽  
Fractured Medium

This study of the hydraulic properties of a fractured rock mass is based on data from field injection tests and fracture measurements, and on simulations of the fracture system in the bedrock upstream from the Daniel Johnson dam at Manic 5. Analysis of water injection tests indicates that the bedrock can be divided into two zones with respect to the permeability. The more permeable zone, which is the object of this study, shows a log-normal distribution of the hydraulic conductivities.Using several stochastic simulations of fracture networks, the fracture aperture has been adjusted gradually to reproduce the rock mass permeability estimated from injection tests. The results show that the fracture system geometry, as well as the fracture porosity and the fracture lengths and densities, influences widely the hydraulic properties of a fractured medium and particularly the fracture porosity. Also, the estimation of the fracture porosity is sensitive to a number of other factors, including the assumed hydraulic boundary conditions, the field estimation of the hydraulic conductivities, and the orientation of the simulation planes. Key words: fissured media, fracture porosity, stochastic model, simulation, sensitivity analysis, dam.

A New Approach to Simulation of Wax Precipitation During Cold Water Injection in Carbonate Reservoir of Kharyaga Oilfield

2021 ◽  
Author(s):  
Yuri Mikhailovich Trushin ◽  
Anton Sergeevich Aleshchenko ◽  
Oleg Nikolaevich Zoshchenko ◽  
Mark Suleimanovich Arsamakov ◽  
Ivan Vasilevich Tkachev ◽  
...  
Keyword(s):  
Cold Water ◽  
Water Injection ◽  
Carbonate Reservoir ◽  
Hot Water ◽  
Reservoir Rock ◽  
Laboratory Studies ◽  
Wax Deposition ◽  
Field Development ◽  
Sector Model ◽  
The Impact

Abstract The paper describes a methodology for assessing the impact of wax deposition in reservoir oil during cold water injection into heterogeneous carbonate reservoir D3-III of the Kharyaga field. The main goal is to determine the optimal amount of hot water that must be injected before switching to cold water without affecting the field development. The paper presents the results of laboratory studies to determine the thermophysical properties of oil, samples of net reservoir and non-reservoir rock, as well as the results of laboratory studies to determine the conditions and nature of wax deposition in oil when the temperature and pressure conditions change. Calculations were carried out to describe the physical model of oil displacement by water of various temperatures. A series of synthetic sector model runs was performed, which includes the average properties of the selected reservoir and the results of laboratory studies in order to determine the effect of cold water injection on the development performance.

Improvement of Uniform Oil Displacement Technology on the Example of Kazakhstani Fields

2018 ◽  
Vol 9 (3) ◽  
pp. 542
Author(s):  
Abdeli D. ZHUMADILULI ◽  
Irina V. PANFILOV ◽  
Jamilyam A. ISMAILOVA
Keyword(s):  
Oil Recovery ◽  
Research University ◽  
Water Injection ◽  
Oil Fields ◽  
Simulation Test ◽  
Sweep Efficiency ◽  
Oil Companies ◽  
Industrial Companies ◽  
Energy Current ◽  
Water Cut

Most of oil companies today are focused on increasing the recovery factor from their oil fields. New drilling and well technologies as well as last advances in reservoir management, monitoring and Enhanced Oil Recovery (EOR) methods are thought to play a major role to meet the future demand of energy. Current decline in discovery of new oilfields intensified by a decline in oil prices make industrial companies to work on development of new efficient and economic techniques that will allow better production at lower cost. One such technology developed at Kazakh National Research University is presented in this paper. The latter propose the use of specific perforated holes on tubing liners in order to control the rate of water injection into variably permeable layers and to prevent non-uniform displacement of oil. The study was initially conducted on experimental facility that proved a positive correlation between the perforation density and water flow rates. Then the simulation test was performed using the data from several Kazakhstani oil fields. The results show an increase of sweep efficiency as well as a decrease in water-cut compared to traditional well case.

scholarly journals Analytical Model of Waterflood Sweep Efficiency in Vertical Heterogeneous Reservoirs under Constant Pressure

2016 ◽  
Vol 2016 ◽  
pp. 1-9 ◽  
Author(s):  
Lisha Zhao ◽  
Li Li ◽  
Zhongbao Wu ◽  
Chenshuo Zhang
Keyword(s):  
Analytical Model ◽  
Oil Recovery ◽  
Constant Pressure ◽  
Water Saturation ◽  
Water Injection ◽  
Single Layer ◽  
Sweep Efficiency ◽  
Heterogeneous Reservoirs ◽  
Water Cut ◽  
Swept Volume

An analytical model has been developed for quantitative evaluation of vertical sweep efficiency based on heterogeneous multilayer reservoirs. By applying the Buckley-Leverett displacement mechanism, a theoretical relationship is deduced to describe dynamic changes of the front of water injection, water saturation of producing well, and swept volume during waterflooding under the condition of constant pressure, which substitutes for the condition of constant rate in the traditional way. Then, this method of calculating sweep efficiency is applied from single layer to multilayers, which can be used to accurately calculate the sweep efficiency of heterogeneous reservoirs and evaluate the degree of waterflooding in multilayer reservoirs. In the case study, the water frontal position, water cut, volumetric sweep efficiency, and oil recovery are compared between commingled injection and zonal injection by applying the derived equations. The results are verified by numerical simulators, respectively. It is shown that zonal injection works better than commingled injection in respect of sweep efficiency and oil recovery and has a longer period of water free production.

Inclusions of well test interpretation and sector model simulation into a full field model: an integration modeling approach

2009 ◽  
Author(s):  
Nasser Saqer Al-Mohannadi ◽  
Oliver Maximilian Seybold ◽  
Gert-jan C.A. Reijnders ◽  
Jean-Michel Laurent Dawans
Keyword(s):  
Field Model ◽  
Model Simulation ◽  
Test Interpretation ◽  
Well Test ◽  
Full Field ◽  
Sector Model ◽  
Modeling Approach

How Much Polymer Should Be Injected During a Polymer Flood? Review of Previous and Current Practices

SPE Journal ◽  
2016 ◽  
Vol 22 (01) ◽  
pp. 1-18 ◽  
Author(s):  
R. S. Seright
Keyword(s):  
Water Injection ◽  
Design Procedure ◽  
Base Case ◽  
Mechanical Degradation ◽  
Sweep Efficiency ◽  
Resistance Factors ◽  
Economics Of Scale ◽  
Field Activity ◽  
Viscous Polymer ◽  
Case Design

Summary This paper provides an extensive review of the polymer concentrations, viscosities, and bank sizes used during existing and previous polymer floods. On average, these values have been substantially greater during the past 25 years than during the first 30 years of polymer-flooding field activity. Reasons for the changes are discussed. Even with current floods, a broad range of polymer viscosities are injected, with substantial variations from a base-case design procedure. Extensive discussions with operators and designers of current polymer floods revealed substantial differences of opinion for the optimum design of polymer floods. This paper examines the validity of arguments that are commonly given to justify deviations from the base-case design. For applications involving viscous oils (e.g., 1,000 cp), the designed polymer viscosities have sometimes been underestimated because of insufficient water injection while determining relative permeabilities; reliance on mobility ratios at a calculated shock front; and overestimation of polymer resistance factors and residual resistance factors. In homogeneous reservoirs, the ratio of produced-oil value to injected-fluid cost is fairly insensitive to injected-polymer viscosity (up to the viscosity predicted by the base-case method), especially at low oil prices. However, reservoir heterogeneity and economics of scale associated with the polymer-dissolution equipment favor high polymer viscosities over low polymer viscosities, if injectivity is not limiting. Injection above the formation-parting pressure and fracture extension are crucial to achieving acceptable injectivity for many polymer floods, especially those using vertical injectors. Under the proper circumstances, this process can increase fluid injectivity, oil productivity, and reservoir-sweep efficiency, and also reduce the risk of mechanical degradation for polyacrylamide solutions. The key is to understand the degree of fracture extension for a given set of injection conditions so that fractures do not extend out of the target zone or cause severe channeling. Many field cases exist with no evidence that fractures caused severe polymer channeling or breaching of the reservoir seals, in spite of injection above the formation-parting pressure. Although at least one case exists (Daqing, China) where injection of very-viscous polymer solutions (i.e., more viscous than the base-case design) reduced Sor to less than that for waterflooding, our understanding of when and how this occurs is in its infancy. At this point, use of polymers to reduce Sor must be investigated experimentally on a case-by-case basis. A “one-size-fits-all” formula cannot be expected for the optimum bank size. However, experience and technical considerations favor use of the largest practical polymer bank. Although graded banks are commonly used or planned in field applications, more work is needed to demonstrate their utility and to identify the most-appropriate design procedure.

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