Study the Displacement Characteristics of Foam Flooding after Polymer Flooding on NMR

2011 ◽  
Vol 361-363 ◽  
pp. 493-498
Author(s):  
Jin Sheng Zhao ◽  
Tian Tai Li ◽  
Ming Zhang ◽  
Zhao Min Li
Keyword(s):  
Nuclear Magnetic Resonance ◽  
Magnetic Resonance ◽  
Polymer Flooding ◽  
Water Flooding ◽  
Fluid Distribution ◽  
Distribution Area ◽  
Low Permeability ◽  
High Permeability ◽  
Polymer Foam ◽  
Foam Flooding

Through parallel cores with different permeability contrast, the displacement process of foam flooding after polymer flooding is experimental studied. Using the experiment technology of nuclear magnetic resonance, the fluid distribution in cores with different diameter was studied. The distribution area of bore diameter in which oil is sweepouted of water flooding, polymer flooding and foam flooding under different processes and various heterogeneity conditions. The results show, against water flooding and polymer flooding, the distribution area of bore diameter in which oil is sweepouted is broadened. Foam can plugging the wide aperture in which water and polyer channeling，and foam can sweep the bore diameter which can’t be swept by water and polymer. Foam can not only advance the recovery of low permeability core but also sweep the oil in microbore of high permeability core.

scholarly journals Effect of asphaltene precipitation on CO2-flooding performance in low-permeability sandstones: a nuclear magnetic resonance study

RSC Advances ◽  
2017 ◽  
Vol 7 (61) ◽  
pp. 38367-38376 ◽  
Author(s):  
Chen Wang ◽  
Tiantai Li ◽  
Hui Gao ◽  
Jinsheng Zhao ◽  
Huazhou Andy Li
Keyword(s):  
Nuclear Magnetic Resonance ◽  
Magnetic Resonance ◽  
Damage Mechanism ◽  
Nuclear Magnetic Resonance Study ◽  
Low Permeability ◽  
Co2 Flooding ◽  
Pore Scale ◽  
Asphaltene Precipitation ◽  
Magnetic Resonance Study ◽  
Nuclear Magnetic

With nuclear magnetic resonance (NMR), a novel experimental study is conducted to reveal the pore-scale formation damage mechanism of tight sandstones caused by asphaltene precipitation during CO2 flooding.

scholarly journals Nuclear magnetic resonance experiments on foam flooding and evaluation of foam dynamic stability

2018 ◽  
Vol 45 (5) ◽  
pp. 910-917 ◽  
Author(s):  
Jingnan ZHANG ◽  
Qinfeng DI ◽  
Shuai HUA ◽  
Feng YE ◽  
Yuan LI ◽  
...  
Keyword(s):  
Nuclear Magnetic Resonance ◽  
Magnetic Resonance ◽  
Dynamic Stability ◽  
Foam Flooding ◽  
Nuclear Magnetic

Assessment of NPV Uncertainty on Heterogeneous Reservoirs during Polymer Flood

2013 ◽  
Vol 448-453 ◽  
pp. 4033-4037 ◽  
Author(s):  
Kyung Wan Yu ◽  
Byung In Choi ◽  
Kun Sang Lee
Keyword(s):  
Net Present Value ◽  
Water Saturation ◽  
Polymer Flooding ◽  
Water Flooding ◽  
Low Permeability ◽  
Oil Viscosity ◽  
Permeability Model ◽  
Heterogeneous Reservoirs ◽  
Polymer Flood ◽  
Porosity And Permeability

This study shows net present value (NPV) distribution by considering uncertainties in porosity, oil viscosity, water saturation, and permeability for polymer flood with Monte Carlo simulation. For high and low average permeability conditions, differences of NPV between polymer flooding and water flooding have been investigated. According to results both average NPV and range of NPV distribution tend to increase with porosity and permeability in all cases. Although water saturation and oil viscosity affect NPV, they are not important parameters that conclude uncertainty of NPV under the conditions considered in this study. For high permeability model which has Dykstra-Parsons coefficient (DP) as 0.72 and porosity as 0.3088, Monte Carol simulations for polymer flood show that 50th percentile (P50) of NPV is 352.81 M$. If porosity is decreased from 0.3088 to 0.1912, the P50 is also decreased 63.8 %. The reduction of NPV during polymer flooding in low permeability reservoirs are almost 40 % higher than that of water flood. These differences come from polymer adsorption and permeability reduction that easily occurs in low permeability zone. The procedure has proven to be useful tool to generate probability distribution of NPV when polymer flood is selected as a tertiary flood process.

Simulation Experimental Study on Aeolotropism Affects the Recovery of Low Permeable Sub Layer Reservoir

2015 ◽  
Vol 733 ◽  
pp. 174-177
Author(s):  
Xin Yuan Zhao ◽  
Yi Kun Liu ◽  
Feng Jiao Wang ◽  
Ru Ya Chen ◽  
Jin Ming Wang
Keyword(s):  
Recovery Rate ◽  
Water Flooding ◽  
Displacement Rate ◽  
Low Permeability ◽  
High Permeability ◽  
Water Displacement ◽  
Sand Body ◽  
Rock Cores ◽  
Layer Analysis ◽  
The Impact

In order to reveal the impact of reservoir heterogeneity on its recovery and by taking the interlayer heterogeneous and inner layer sand superimposition model (two forms of complexity situation) into account, water flooding experiments have been conducted on parallel connected rock cores, which are selected and artificially casted cores with different permeability, at different injection rates. Experimental results suggested that water displacement recovery is kept decreasing with the increasing of interlayer heterogeneity. when the interlayer permeability ratio (ratio of high permeability versus low permeability) is at about 6.5 and water displacement rate is set at 0.5ml/min, 1ml/min, 1.5ml/min, 2ml/min, respectively, the water flooding experiments indicated that the low permeability recovery increased significantly and low permeability layer became main producer with the increasing of water displacement rate, on the opposite, the high permeability recovery showed no little big change. Laboratory experiments on the model of layer sand body superimposition revealed that the recovery rate of FTRLPTPL model is about 5%~10% higher than that of FTPLPTRL model.(FTRLPTPL is briefed from that flooding from the thick and rich in oil layer and produced from the thin and poor in oil layer. FTPLPTRL is briefed from that flooding from the thin and poor in oil layer and produced from the thick and rich in oil layer.) Analysis on the experiments in different reservoir inner situation told us that recovery enhancement of low permeability layer can play a significant role in increasing the overall recovery rate.

scholarly journals Enhanced oil recovery ability of branched preformed particle gel in heterogeneous reservoirs

2018 ◽  
Vol 73 ◽  
pp. 65 ◽  
Author(s):  
Long Yu ◽  
Qian Sang ◽  
Mingzhe Dong
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Water Flooding ◽  
Low Permeability ◽  
High Permeability ◽  
Sweep Efficiency ◽  
Reservoir Heterogeneity ◽  
Heterogeneous Reservoirs ◽  
Preformed Particle Gel ◽  
Profile Control

Reservoir heterogeneity is the main cause of high water production and low oil recovery in oilfields. Extreme heterogeneity results in a serious fingering phenomenon of the displacing fluid in high permeability channels. To enhance total oil recovery, the selective plugging of high permeability zones and the resulting improvement of sweep efficiency of the displacing fluids in low permeability areas are important. Recently, a Branched Preformed Particle Gel (B-PPG) was developed to improve reservoir heterogeneity and enhance oil recovery. In this work, conformance control performance and Enhanced Oil Recovery (EOR) ability of B-PPG in heterogeneous reservoirs were systematically investigated, using heterogeneous dual sandpack flooding experiments. The results show that B-PPG can effectively plug the high permeability sandpacks and cause displacing fluid to divert to the low permeability sandpacks. The water injection profile could be significantly improved by B-PPG treatment. B-PPG exhibits good performance in profile control when the high/low permeability ratio of the heterogeneous dual sandpacks is less than 7 and the injected B-PPG slug size is between 0.25 and 1.0 PV. The oil recovery increment enhanced by B-PPG after initial water flooding increases with the increase in temperature, sandpack heterogeneity and injected B-PPG slug size, and it decreases slightly with the increase of simulated formation brine salinity. Choosing an appropriate B-PPG concentration is important for B-PPG treatments in oilfield applications. B-PPG is an efficient flow diversion agent, it can significantly increase sweep efficiency of displacing fluid in low permeability areas, which is beneficial to enhanced oil recovery in heterogeneous reservoirs.

scholarly journals Evaluation of Displacement Effects of Different Injection Media in Tight Oil Sandstone by Online Nuclear Magnetic Resonance

Energies ◽  
2018 ◽  
Vol 11 (10) ◽  
pp. 2836 ◽  
Author(s):  
Ting Chen ◽  
Zhengming Yang ◽  
Yutian Luo ◽  
Wei Lin ◽  
Jiaxiang Xu ◽  
...  
Keyword(s):  
Nuclear Magnetic Resonance ◽  
Magnetic Resonance ◽  
Water Flooding ◽  
Tight Oil ◽  
Recovery Ratio ◽  
Co2 Flooding ◽  
Remaining Oil ◽  
Gas Flooding ◽  
Displacement Effects ◽  
Nuclear Magnetic

In order to evaluate the displacement effect of four kinds of injection media in tight oil sandstone, water, active water, CO2, N2 flooding experiments were carried out in laboratory. Online Nuclear Magnetic Resonance (NMR) spectrometers combine the advantages of NMR technology and core displacement experiments. In the displacement experiment, NMR data of different injection volumes were obtained and magnetic resonance imaging (MRI) was carried out. The results showed that micro and sub-micropores provided 62–97% of the produced crude oil. The enhanced oil recovery ratio of active water flooding was higher than that of conventional water flooding up to 10%. The recovery ratio of gas flooding in micro and sub-micropores was 60–70% higher than that of water flooding. The recovery ratio of CO2 flooding was 10% higher than that of N2 flooding. The remaining oil was mainly distributed in pores larger than 0.1 μm. Under the same permeability level, the remaining oil saturation of cores after gas flooding was 10–25% lower than water flooding. From MRI images, the displacement effects from good to bad were as follows: CO2 flooding, N2 flooding, active water flooding, and conventional water flooding.

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