Enhanced oil recovery of heavy oils by non-thermal chemical methods (original) (raw)
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Polymer Flooding for Improving Oil Recovery
Several methods to enhance oil recovery are encouraging in Indonesia as well as in the world today. In compliance with this, research in the area of enhanced oil recovery (EOR) is still carried out by many examiners. One of the research areas is exploitation of chemicals for seeking the enhancement of oil recovery. Some chemicals have been found for Enhanced Oil Recovery processes. However, in order to determine chemicals used in this experiment, some aspect have been set as follows: it is easily found in Indonesia, it can be produced inexpensively, it has high recoverability and it is not petroleum base. The goal of this research is to investigate the effect of polimer found in the market and developed in the laboratory such as Poly Vynil Alcohol (PVA) and Partially Hydrolyzed Polyacrylamide (HPAM) polymer on the oil recovery which can be used to optimize recovery and minimize residual oil in the reservoir by: lowering the oil / water interfacial tension and improving mobility ratio. The effectiveness of chemicals was tested through micro displacement using artificial reservoir as porous medium. The procedure of operation is as follows: initially the reservoir model was filled with brine until it was 100 % saturated. Then to represent oil migration, oil was injected into the medium until minimum water saturation (S wc) of about 30 % is reached. After this, the medium was flooded by the same brine until minimum oil saturation, S or, was reached, which was about 10 %. The oil remaining in the reservoir model after this water flood was then subjected to the injection of various chemicals for additional oil recovery. A set of mathematical model of oil displacement from porous media using water and polymer flooding has also been developed, based on fundamental theories of two phase flow. Since the model includes the material balance of the water and polymer, the concentration of the polymer at any position and time can be predicted. The oil displacement experiments show that as much as 20 % to 60 % of remaining oil can be recovered by flooding it with the chemical developed in the laboratory. The results also show the oil recovery depends on chemical, chemical concentration, pressure and temperature in the model reservoir, and crude oil. It turns that the mathematical models proposed were in a good agreement with the experimental data.
Spe Journal, 2018
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Oil Recovery by Polymer Flooding; Sensitivity Analysis to Technical Parameters
2016
maxImum oil reco\ er: \\ a achieved at 200 ppm pol) mer concentration. three month of W P C) cleo and u ing the am completion as in the continuou proce. Results also indicated that both continuou and pol) mer slug injection have the arne optimum concentration of 200 ppm. Furth rmore. the study reconmlend u ing well completion one. t\\O years of pol) mer lug injection. and polymer concentration of 1000 ppm. Th sel cted) tem) ields an oil recovery of 49.26%. The outcomes of thi work should assist the oil industry in plaruling polymer nooding fo r heterogeneou reservoirs; keeping in mind that UAE hydrocarbon re en irs are normally complex \,-jtb higb degree of heterogeneity.
Surfactant and Surfactant-Polymer Flooding for Enhanced Oil Recovery
Advances in Petroleum Exploration and Development, 2011
Literatures show that 40% to 55% of oil reserves are usually left insitu after primary and secondary recovery processes such as water flooding. This remaining reserve has to be recovered by Enhanced Oil Recovery process. Surfactant-Polymer flooding is one of the viable Enhanced Oil Recovery processes for recovering additional by lowering the interfacial tension between the oil and water and reducing water mobility. In this research, two sets of experiments were performed. First, the optimum surfactant concentration was determined through surfactant polymer flooding using a range of surfactant (Sodium Dodecyl sulphate, SDS) concentration of 0.1% to 0.6% and 15% of polymer (gum Arabic). Secondly, another set of experiments to determine the optimum flow rate for surfactant flooding was performed. The result of the first set of experiment shows a range of oil recovery of 59% to 76% for water flooding and a range of 11.64% to 20.02% additional oil recovery for surfactant Polymer flooding for a range of surfactant flow rate of surfactant concentration of 0.1% t0 0.6%. For the second sets of experiments, a range of oil recovery of 64% to 68% for water flooding and a range of 15% to 24% additional oil recovery for surfactant flooding for a range of surfactant flow rate of surfactant flow rate of 1cc/min to 6cc/min. The Optimum surfactant flow rate resulting in the highest oil recovery for the chosen core dimension and parameter is 3cc/min.
Investigate Polymer Flooding for Enhanced Oil Recovery in a Mature Oil Field
International Journal of Petroleum and Petrochemical Engineering
Polymer flooding is the evolution of conventional water flooding technique. Instead of using just water to displace oil, polymer is used as an alternative to injection water. The polymer introduced to the injection water affects the viscosity of displaced fluid and hence decreases mobility ratio, improves stratification efficiencies and frontal saturations. The relative flow rates of water and oil are altered by the polymer solution, sweeping larger area of the reservoir and; therefore, more oil is in contact with the polymer solution and displaced to the production well. One of the principal purpose of this research is to examine the efficiency of polymer flooding in an oilfield by performing sensitivity analysis, which includes altering injection timing, polymer concentration, injection rate, injection layer, injection period and well configurations in a Western Australian oilfield. Also, water flooding is to be conducted as a base case to compare the efficiency of oil recovery for polymer flooding. A 7x7x6 box model was built and all the reservoir fluid data were analyzed using Computer Modeling Group (STARS). The results show that there is a slight increase in oil recovery (1.72%) after polymer is injected. However, by changing the well configurations, a significant increment of 12.46% of oil recovery is observed.
Formulation of a combined low saline water and polymer flooding for enhanced oil recovery
International journal of ambient energy, 2019
The study aims in formulating a new Enhanced Oil Recovery (EOR) slug comprising of a synthetic polymer, which is Polyacrylamide (PAM) and a biopolymer, which is Xanthan Gum (XG). In this case the EOR will be named XPS, where low saline water flooding was assisted by PAM and XG. The polymer flooding application in depleted oil fields of Upper Assam Basin has faced a number of challenges, as it was unable to enhance the viscosity of the displacing fluid and reduce the effective permeability of the displacing fluid, which led to the failure of the macroscopic sweep efficiency (ES) of the reservoir. The rheological properties were found to be Non-Newtonian mostly shear thinning and followed the Herschel-Bulkley (HB) and Ostwald de Waele power law (OWP) models. The appropriate slugs were further flooded in a core flooding. Low saline water flooding followed by polymer flooding increases the overall recovery efficiency. Keywords XPS,Core Flood, Low saline water flood 1. Introduction The oil recoveries at the end of primary and secondary recovery processes are generally in the range of 20-40% of the original oil in place (OOIP) (Gogoi, 2008, 2009). Work on chemical EOR specially polymer, surfactant flooding, alkali surfactant polymer flooding, micellar alkali polymer flooding showed oil recovery from the depleted oil fields of Upper
Effect of Polymer Adsorption on Permeability Reduction in Enhanced Oil Recovery
In order to reduce the permeability to water or brine, there is a possibility of polymer injection into the reservoir. In the present work, special focus has been paid in polymer [partially hydrolyzed polyacrylamide (PHPA)] injection as a part of chemical method. Tests were conducted in the laboratory at the ambient temperature to examine the reduction in permeability to water or brine in the well-prepared sand packed after the polymer injection. The experiments were performed to study the effect of polymer adsorption on permeability reduction by analyzing residual resistance factor values with different concentrations of polymer solutions. The rheological behavior of the polymer has also been examined. The experimental results also indicate that the adsorption behavior of polymer is strongly affected by salinity, solution pH, and polymer concentration. To investigate the effect of polymer adsorption and mobility control on additional oil recovery, polymer flooding experiments were conducted with different polymer concentrations. It has been obtained that with the increase in polymer concentrations, oil recovery increases.
Polymer Flooding in a High Salinity Heavy-Oil Reservoir
Brazilian Journal of Petroleum and Gas, 2018
This work aims to present a methodology to evaluate polymer flooding and compare the results with the conventional waterflooding for a target heavy oil reservoir. The dead oil and produced water (SPW) (104 800 ppm of total solids dissolved) were prepared to represent the reservoir fluids at test conditions (60°C). SPW was the water source to make and determine the polymer concentration (HPAM-ATBS) to get the target viscosity for the injection fluid (10 mPa s at 7.8 s-1). Botucatu sandstone samples represented the reservoir formation. We verified the thickness of the polymer solution after flow throughout the rock sample and confirmed higher value than that for injected SPW. Polymer flooding led to the breakthrough delay, shifted the fractional flow to the right, anticipated oil production, and incremented oil recovery. Under the tested conditions, the maximum contribution of polymer flooding occurred up to 70% of water cut.