Progressing cavity pump anti-scaling techniques in alkaline-surfactant-polymer flooding in the Daqing Oilfield

Liang, Yongtu; Cao, Gang; Guochen, Shi; Wang, Guoqing; Li, Jinling; Zhao, Yongjun

doi:10.1016/s1876-3804(11)60049-9

Cited by 22 publications

(8 citation statements)

References 7 publications

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“…And as the micropore structure of the Note: bold font indicates values greater than 60% of the swept volume, indicating good compatibility of the polymer solution formulation with the reservoir type. 8 Geofluids reservoir becomes worse, that is, the reservoir changes from type I to type V, the degree of influence of the increase of polymer concentration on the change of swept volume also increases. For example, for 1500 × 10 4 polymer molecular weight, when the solution concentration increases from 0.10% to 0.20%, the reduction of sweep volume of the type I reservoir is 7.31%, the reduction of sweep volume of the type III reservoir is 8.83%, and the reduction of sweep volume of type V reservoir is 10.81%.…”

Section: Analysis Of Experimental Resultsmentioning

confidence: 99%

“…At present, the conglomerate reservoir has been developed through a long period of waterflooding, with a limited swept volume of injected water, increasing water content, and rapidly decreasing oil production. Therefore, the tertiary oil recovery technology with polymer flooding as the pilot test becomes an inevitable trend to improve the complex mode conglomerate reservoir [7][8][9]. As we all know, compared to water injection and flooding, tertiary oil recovery mainly uses chemicals to improve the adsorption performance and interaction between oil, gas, water, and rock to maximize the recovery of oil reservoirs [10].…”

Section: Introductionmentioning

confidence: 99%

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Study on Compatibility between Complex Mode Micropore Structure and Polymer Solution of Different Formulation for Conglomerate Reservoir

Tan

Jing

et al. 2023

Geofluids

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In this paper, the conglomerate reservoir is selected as the object to investigate the micropore structure and the compatibility of polymer solutions. Firstly, the characteristics of complex mode pore structure are analyzed based on casting thin sections, scanning electron microscope, and capillary pressure curve. Then the conglomerate reservoir is divided into five types by use of the K-means clustering algorithm, and the differences in micropore structure among the different reservoir types are also clarified. Secondly, the dynamic light scattering technology is used to directly determine the hydrodynamic diameter of different polymer formulations. As the polymer molecular weight increases, the average hydrodynamic diameter becomes larger, and with the same polymer molecular weight, the average hydrodynamic diameter becomes gradually larger as the solution concentration increases. Based on the above research results, the matching relationship between five reservoir types and polymer solutions is determined through laboratory experiments. The experimental results show that when the polymer molecular weight is determined, the volume of pore volume that can be effectively swept by polymer hydration molecules gradually decreases as the concentration of the solution increases. When the polymer molecular weight and its concentration are both determined, the pore volume of effective displacement of polymer-hydrated molecules also gradually reduces with becoming worse reservoir pore structure. The scope of application of different polymer formulations becomes progressively smaller as the microscopic pore structure of type I to type V reservoirs becomes deteriorated. The compatibility between the micropore structure of different conglomerate reservoir types and polymer solution is determined to provide the geological basis for the reasonable formulation of the polymer flooding scheme.

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Section: Analysis Of Experimental Resultsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Study on Compatibility between Complex Mode Micropore Structure and Polymer Solution of Different Formulation for Conglomerate Reservoir

Tan

Jing

et al. 2023

Geofluids

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“…The active surface of the rotor is a cylindrical helical surface of constant pitch, and the stator, whose active surface is a double helical surface, is also cylindrical and with constant pitch. The stator is usually made of rubber [6,7], and the rotor is made of steel, often superficially hardened. The exploitation activity of the pumps with progressive cavities has highlighted the fact that traditional pumps with a rubber stator, which surrounds the rotor, do not allow the existence of an interstice between them, which limits their activity until the stator wears out [8,9].…”

Section: Introductionmentioning

confidence: 99%

Roller Profiling for Generating the Screw of a Pump with Progressive Cavities

Baroiu¹,

Moroşanu²,

Teodor³

et al. 2021

Inventions

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Progressive cavity pumps are used in industry for the circulation of high viscosity fluids, such as crude oil and petroleum products, sewage sludge, oils, salt water, and wastewater. Also known as single screw pumps, these pumps are composed of a single rotor which has the shape of a rounded screw, which moves inside a rubber stator. The stator has an double helical internal surface which, together with the helical surface of the rotor, creates a cavity that moves along the rotor. The movement effect of the cavity inside the stator is the movement of the fluid with a constant flow and high pressure. In this paper, an algorithm for profiling the rollers for generating the helical surface of the pump rotor with progressive cavities is proposed. These rollers are constituted as tools for the plastic deformation of the blank (in case the pump rotor is obtained by volumetric deformation) or for its superficial hardening.

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“…In the petroleum industry, surfactants play a very important role in the chemical flooding technology for enhancing oil recovery (EOR) due to their capability of reducing interfacial tension. Besides surfactant flooding, surfactants can be used in many chemical combination flooding systems, such as surfactant/polymer, − alkaline/surfactant/polymer, − and surfactant/alkaline − systems. Two distinct mechanisms in reducing interfacial tension with surfactants have been found.…”

Section: Introductionmentioning

confidence: 99%

Effects of Extended Surfactant Structure on the Interfacial Tension and Optimal Salinity of Dilute Solutions

Zhang

et al. 2019

ACS Omega

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Extended surfactants with the oxypropylene (PO) group and ethoxylated anionic surfactants with the oxyethylene (EO) group have a high salt tolerance capability. Most of the researches on extended surfactants and ethoxylated anionic surfactants focused on the microemulsion, solubilization, and interfacial tension (IFT) of concentrated surfactant solutions, whereas a few researches focused on the IFT of dilute surfactant solutions. Moreover, a previous work focused only on surfactants with PO numbers greater than 4 and copolymers of PO and EO. The effects of extended surfactants containing short PO chains and no EO groups have not been examined. We measured the IFT and optimal salinity between n -alkanes and dilute solutions of extended surfactants or ethoxylated sulfonates at 30 °C. The effects of the surfactant structure on the equilibrium interfacial tension (IFT eq ) and optimal salinity of the system were studied in detail. As for the effects on IFT, results indicate that the introduction of PO groups leads to their enhanced capability to reduce the IFT prior to cross-salinity and a reduction in the IFT between n -alkanes and surfactant solutions to ultralow values (smaller than 0.01 mN/m) near the optimal salinity. It was also found that extended surfactants with different alkyl chains also entail a cross-salinity; at values lower than the cross-salinity, the IFT reduction capacity of extended surfactants with a long alkyl chain (C16P3SO3) is better than that of extended surfactants with a short alkyl chain (C13P3SO3). As for the effect on the optimal salinity, it was found that the optimal salinity of extended surfactants is lower than that of ethoxylated sulfonates for the same oil phase. It was also found that the optimal salinity of extended surfactants first increased and later decreased with increasing PON. This finding is first proposed based on summarizing some researchers’ studies and our experiments.

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Progressing cavity pump anti-scaling techniques in alkaline-surfactant-polymer flooding in the Daqing Oilfield

Cited by 22 publications

References 7 publications

Study on Compatibility between Complex Mode Micropore Structure and Polymer Solution of Different Formulation for Conglomerate Reservoir

Study on Compatibility between Complex Mode Micropore Structure and Polymer Solution of Different Formulation for Conglomerate Reservoir

Roller Profiling for Generating the Screw of a Pump with Progressive Cavities

Effects of Extended Surfactant Structure on the Interfacial Tension and Optimal Salinity of Dilute Solutions

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