scholarly journals Experiment on the profile control effect of different strength gel systems in heterogeneous reservoir

2021 ◽  
Vol 7 ◽  
pp. 6023-6030
Author(s):  
Runnan Zhou ◽  
Dong Zhang ◽  
Jianguang Wei
Keyword(s):  
Control Effect ◽  
Heterogeneous Reservoir ◽  
Profile Control

scholarly journals Experimental Study of Profile Control with Foam Stabilized by Clay Particle and Surfactant

Energies ◽  
2019 ◽  
Vol 12 (5) ◽  
pp. 781 ◽  
Author(s):  
Songyan Li ◽  
Chenyu Qiao ◽  
Guowei Ji ◽  
Qun Wang ◽  
Lei Tao
Keyword(s):  
Anionic Surfactants ◽  
Resistance Factor ◽  
Clay Particle ◽  
Petroleum Engineering ◽  
Control Effect ◽  
Clay Particles ◽  
Profile Control ◽  
Water Cut ◽  
Deep Profile ◽  
Increasing Temperature

Foam is a kind of ideal fluid for profile control in petroleum engineering, which has attracted intense interests of scholars globally in recent years. In this study, a foam system stabilized with anionic surfactants and clay particles was proposed for profile control in reservoirs, and the formulation was optimized experimentally. Moreover, flooding experiments in visible porous media models and in sandpacks were conducted to test the plugging effect of the foam system on reservoirs, and the effects of different factors such as gas–liquid ratio, temperature and permeability on profile control were also evaluated. According to the experimental results, the clay-HY-2 system was elected for its satisfactory foamability, stability, and salinity resistance, and the optimum concentrations of HY-2 and clay particle are 0.6 wt% and 5.0 wt%, respectively. Compared with traditional foam fluids, the clay-HY-2 system can form denser and smaller bubbles in high- and middle-permeable layers, enhancing the plugging effect there, while there are less bubbles in low-permeable layers, i.e., the restriction on the flow in narrow structures is slight. The clay-HY-2 foam can perform the efficient and uniform profile control effect on sandpacks when the foam quality is around 50%. The resistance factor of the foam decrease gradually with the increasing temperature, however, the resistance factor remains higher than 350.0 when the temperature reaches 80.0 °C. When the permeability exceeds 1502.0 mD, the clay-HY-2 foam can perform deep profile control in reservoirs, and the resistance factor are not sensitive to the change of permeability when it exceeds 3038.0 mD. Besides, the site application case shows that the clay-HY-2 foam do have good profile control effect on reservoirs, i.e., improving oil production and declining water cut.

scholarly journals Experimental Investigation of Self-Assembled Particles on Profile Control in the Fuyu Oilfield

2021 ◽  
Vol 9 ◽  
Author(s):  
Lifei Dong ◽  
Miao Wang ◽  
Jie He ◽  
Mingchen Ding ◽  
Hun Lin
Keyword(s):  
Oil Recovery ◽  
Particle System ◽  
Water Channel ◽  
Control Agent ◽  
The Self ◽  
Control Effect ◽  
Water Breakthrough ◽  
Profile Control ◽  
Self Assembled ◽  
Enhance Oil Recovery

The particle system is one of the widely used profile control agents in many oilfields, and the matching relationship between the particle and the reservoir pore throat is significant for the profile control effect. In order to enhance oil recovery after water breakthrough in the Fuyu oilfield, a self-assembled particle with some branches on the surface, compounded by inverse emulsion polymerization and added, is introduced as the profile control agent in this paper. Then the permeabilities of the water channel and the oil remaining area in the Fuyu oilfield are achieved after the statistic analysis of 1,022 cores from the practical reservoir. Furthermore, the oil restarting pressure in the oil remaining area and the self-assembled particle plugging strength in the water channel are tested. Finally, the adaption of the self-assembled particle and effect of profile control in the Fuyu oilfield are evaluated by comparing the oil restarting pressure and the plugging strength. The results show that the self-assembled particles can be gathered together easily by the force of the ionic bond, which is good for water channel plugging. The permeability of the water channel in the Fuyu oilfield ranges from 1,000 mD to 1,500 mD. The oil restarting pressure increases with the decreasing of permeability, and the increasing rate grows rapidly when it drops below 50 mD. Comparing the oil restarting pressure with the plugging strength, a self-assembled particle with a diameter of 20–40 μm in the water channel with a permeability of 1,265.7 mD can provide sufficient plugging strength to restart the remaining oil in the oil remaining areas with a permeability over 3.38 mD. The matched window of the self-assembled particle is wider than a normal particle in the Fuyu oilfield.

A Practical Model for Water Injection Evaluation and Optimization in Typical Offshore Reservoirs Considering Formation Heterogeneity Based on Experimental Study

2021 ◽  
Author(s):  
Shijun Huang ◽  
Yuanrui Zhu ◽  
Shichao Chai ◽  
Guanyang Ding ◽  
Yicheng Xin ◽  
...  
Keyword(s):  
Horizontal Well ◽  
Superposition Principle ◽  
Water Injection ◽  
Injection Rate ◽  
Rate Curve ◽  
Control Effect ◽  
Injection Efficiency ◽  
Profile Control ◽  
Horizontal Wellbore ◽  
Heterogeneous Formation

Abstract A major concern with water injection in offshore oil reservoir is the water breakthrough. The formation heterogeneity is the main reason for it. In order to evaluate the water injection efficiency, a visualized 2-D experiment was carried out to obtain the distribution law of injected water and the variation of injection parameters in homogeneous and heterogeneous formation. In addition, a coupled wellbore/reservoir model was established by applying microelement method, superposition principle and imaging. This model considers the formation heterogeneity and pressure drop caused by wellbore friction. The visualized 2-D sand filling displacement experiment indicates that the injection rate at the horizontal well heel is greater than that at the toe and the injection front is more irregular in heterogeneous formation. The injection rate and injection pressure distribution along the horizontal well are obtained analytically based on the proposed model, the results show that the injection rate at the two sides of the wellbore is much higher than that in the middle when the formation is homogeneous and the wellbore is infinite-conductive. In this case, the injection rate curve along horizontal well shows a "U" shaped distribution. When a finite-conductive horizontal wellbore is considered, the injection rate at the heel of the wellbore is higher than that of the toe, although the injection rate curve along horizontal well also exhibits a deformed "U" shape distribution. For the formation heterogeneities along the horizontal wellbore, the injection rate distribution curve is not continuous anymore, but a deformed "U" shape is also observed for each wellbore segment. At last, the established model was applied to an ultra-heterogeneous offshore reservoir. It is concluded that the profile control effect of typical well is obvious. The results of this study are of great significance for the calculation of the injection rate profile and improving the water injection efficiency.

Profile Control Effect and Mechanism Analysis of Fly Ash

2009 ◽  
Vol 27 (16) ◽  
pp. 1866-1879 ◽  
Author(s):  
K. Zhang ◽  
J. S. Qin ◽  
X. L. Chen ◽  
X. G. Liu
Keyword(s):  
Fly Ash ◽  
Mechanism Analysis ◽  
Control Effect ◽  
Profile Control

Research and Application of Floaters Produced from Water Treatment in Oilfield SZ36-1 as Profile Control Agent

2013 ◽  
Vol 724-725 ◽  
pp. 1171-1175
Author(s):  
Li Wei Niu ◽  
Xiang Guo Lu ◽  
Wei Li ◽  
Sheng Wang Yuan
Keyword(s):  
Suspended Solids ◽  
Particle Concentration ◽  
Structural Characteristics ◽  
Control Agent ◽  
Reservoir Engineering ◽  
High Permeability ◽  
Control Effect ◽  
Permeability Ratio ◽  
Engineering Theory ◽  
Profile Control

Composition and structural characteristics of floaters were detected and forming reasons were analysed through modern reservoir engineering theory, equipment analysis and physical simulation.Experiments on flowing characteristics, fluid diversion effect and driving effect were carried out. The results show that floaters are formed by huge amounts of tiny bubble absorbing crude oil and suspended solids in floating progress which make their density lower than water. Disposed floaters have better adaptability and can block off high-permeability. Furthermore, profile control effect turns better as particle concentration and permeability ratio increases. However,floater particles have selectivity to permeability ratio. When permeability ratio is not less than 8, profile control agent may damage low-permeability layers and cause succeeding water passing through high-permeability layers. Therefore, only when floaters adapt well to permeability ratio can we get better profile control effect.

scholarly journals Preparation and Performance Evaluation of Polymeric Microspheres Used for Profile Control of Low-Permeability Reservoirs

2020 ◽  
Vol 2020 ◽  
pp. 1-11
Author(s):  
Fajun Zhao ◽  
Hongbao Zhang ◽  
Yanping Wu ◽  
Dawei Wang ◽  
Yufei Zhang
Keyword(s):  
Particle Size ◽  
Shear Rate ◽  
Size Distribution ◽  
Depth Profile ◽  
Pore Channel ◽  
Low Permeability ◽  
Core Flooding ◽  
Control Effect ◽  
Polymeric Microspheres ◽  
Profile Control

To improve in-depth profile control in a low-permeability reservoir, polymeric microspheres were used. A distillation–precipitation polymerization method was adopted to prepare nanometer-sized polymeric microspheres, whose structure, apparent pattern, thermal endurance, particle size, hydration, and swelling capacity were tested and analyzed by a series of techniques, including infrared spectroscopy, scanning electron microscopy, thermogravimetry, high-pressure and high-temperature rheometry, and dynamic light scattering. The prepared polymeric microspheres were copolymerization products of acrylamide, acrylic acid, and methyl methacrylate that were uniformly round with a centralized size distribution. The nanometer-sized microspheres had satisfactory hydration/swelling performance, indicating that they could act as oil displacement profile control agents. With the increase of shear rate, the apparent viscosity of the polymeric microspheres was significantly reduced, and the fluid possessed a pseudoplastic behavior. When the shear rate was 100–1000 s−1, the fluid demonstrated a Newtonian fluid behavior. After the polymeric microspheres were hydrated, the particle size distribution curve shows a normal distribution, reaching a maximum swelling size of 21.3 times that of the original microspheres. The plugging performance and deformability of the polymeric microspheres gradually enhanced with swelling time, which makes the microspheres effective pore channel plugging agents for delivering a better in-depth profile control effect in rock cores with lower permeability. The core flooding test showed that, for the heterogeneous core with a permeability of 10 μm2, polymer microspheres have good plugging effect.

scholarly journals Experimental Investigation of the Matching Relationship between Asphalt Particle and Reservoir Pore in Profile Control Process

2016 ◽  
Vol 2016 ◽  
pp. 1-11 ◽  
Author(s):  
Chengfeng Ren ◽  
Junjian Li ◽  
Yiqiang Li ◽  
Jingshu Yuan ◽  
Yanqiang Xi ◽  
...  
Keyword(s):  
Low Cost ◽  
Water Injection ◽  
Control Process ◽  
Resistance Coefficient ◽  
Control Effect ◽  
Migration Ability ◽  
Reservoir Permeability ◽  
Profile Control ◽  
Alternative Water ◽  
Relative Change

Modified sulfonated asphalt particles have a bright application prospect of the profile control of thick reservoirs due to the low cost, extensive sources, and good compatibility with reservoir. Nevertheless, the matching relationship between asphalt particles and reservoir pore has seldom been investigated till now. Oversized particles always block the near-wellbore area, which causes high injection pressures, while undersized particles cannot plug large pores. We designed a core for this experiment which has a high permeability zone in front of it and many pressure measuring points. We could quantitatively assess the matching relationship by measuring the on-way resistance coefficient, residual resistance factor, and relative change of permeability of man-made cores after injecting asphalt. Experimental results indicate that asphalt particles with sizes of 0.02 mm, 0.02–0.06 mm, and 0.08–0.1 mm match with reservoir permeability of 500 mD, 1000 mD, and 2000 mD, respectively. Undersized or oversized particles can reduce the conformance control effect, and the concentration of asphalt particles in the injectant can limit their migration ability. When the concentration of asphalt particles increases to 3000 mg/L, accumulations of asphalt particles can be caused in the formation, in which a scheme with asphalt particles alternative water injection is proposed to avoid the accumulation.

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