scholarly journals A Study on the Matching Relationship of Polymer Molecular Weight and Reservoir Permeability in ASP Flooding for Duanxi Reservoirs in Daqing Oil Field

Energies ◽  
2017 ◽  
Vol 10 (7) ◽  
pp. 951 ◽  
Author(s):  
Bin Huang ◽  
Wei Zhang ◽  
Rui Xu ◽  
Zhenzhong Shi ◽  
Cheng Fu ◽  
...  
Keyword(s):  
Molecular Weight ◽  
Oil Field ◽  
Polymer Molecular Weight ◽  
Asp Flooding ◽  
Reservoir Permeability ◽  
Daqing Oil Field ◽  
Relationship Of

Study on Physical Simulation Experiments of Different Chemical Displacement Systems

2011 ◽  
Vol 201-203 ◽  
pp. 2562-2566
Author(s):  
Wen Xiang Wu ◽  
Deng Hui Mu ◽  
Qing Dong Liu
Keyword(s):  
Molecular Weight ◽  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Physical Simulation ◽  
Oil Field ◽  
Polymer Molecular Weight ◽  
Simulation Experiments ◽  
Reservoir Condition ◽  
Asp Flooding ◽  
Polymer Surfactant

In the reservoir condition of Liaohe oil field, the indoor physical simulation experiments of polymer / surfactant binary combination flooding and polymer / surfactant / alkali (ASP) flooding in the artificial cores have been conducted. The results show that enhanced oil recovery of polymer flooding is about 24.4%, by utilizing experiment project that polymer molecular weight is 19 million, main slug concentration is 1500mg/L. Binary flooding system that molecular weight of polymer is 19 million, main slug concentration is 1500mg/L, 0.3% surfactant YR has improved the oil recovery by 30.1%. The ASP flooding system (19 million 1500mg/L polymer +0.3% surfactant SS+ 1.2%Na2CO3) has improved the oil recovery by 28.4%. It can be seen that the binary flooding system is best.

Key Aspects of Project Design for Polymer Flooding at the Daqing Oilfield

2008 ◽  
Vol 11 (06) ◽  
pp. 1117-1124 ◽  
Author(s):  
Dongmei Wang ◽  
Randall S. Seright ◽  
Zhenbo Shao ◽  
Jinmei Wang
Keyword(s):  
Molecular Weight ◽  
Polymer Concentration ◽  
Oil Production ◽  
Polymer Flooding ◽  
Oil Field ◽  
Polymer Injection ◽  
Polymer Flood ◽  
Daqing Oil Field ◽  
Water Cut ◽  
Injection Rates

Summary This paper describes the design procedures that led to favorable incremental oil production and reduced water production during 12 years of successful polymer flooding in the Daqing oil field. Special emphasis is placed on some new design factors that were found to be important on the basis of extensive experience with polymer flooding. These factors include (1) recognizing when profile modification is needed before polymer injection and when zone isolation is of value during polymer injection, (2) establishing the optimum polymer formulations and injection rates, and (3) time-dependent variation of the molecular weight of the polymer used in the injected slugs. For some Daqing wells, oil recovery can be enhanced by 2 to 4% of original oil in place (OOIP) with profile modification before polymer injection. For some Daqing wells with significant permeability differential between layers and no crossflow, injecting polymer solutions separately into different layers improved flow profiles, reservoir sweep efficiency, and injection rates, and it reduced the water cut in production wells. Experience over time revealed that larger polymer-bank sizes are preferred. Bank sizes grew from 240-380 mg/L·PV during the initial pilots to 640 to 700 mg/L·PV in the most recent large-scale industrial sites [pore volume (PV)]. Economics and injectivity behavior can favor changing the polymer molecular weight and polymer concentration during the course of injecting the polymer slug. Polymers with molecular weights from 12 to 35 million Daltons were designed and supplied to meet the requirements for different reservoir geological conditions. The optimum polymer-injection volume varied around 0.7 PV, depending on the water cut in the different flooding units. The average polymer concentration was designed approximately 1000 mg/L, but for an individual injection station, it could be 2000 mg/L or more. At Daqing, the injection rates should be less than 0.14-0.20 PV/year, depending on well spacing. Introduction Many elements have long been recognized as important during the design of a polymer flood (Li and Niu 2002; Jewett and Schurz 1970; Sorbie 1991; Vela et al. 1976; Taber et al. 1997; Maitin 1992; Koning et al. 1988; Wang et al. 1995; Wang and Qian 2002; Wang et al. 2008). This paper spells out some of those elements, using examples from the Daqing oil field. The Daqing oil field is located in northeast China and is a large river-delta/lacustrine-facies, multilayer, heterogeneous sandstone in an inland basin. The reservoir is buried at a depth of approximately 1000 m, with a temperature of 45°C. The main formation under polymer flood (i.e., the Saertu formation) has a net thickness ranging from from 2.3 to 11.6 m with an average of 6.1 m. The average air permeability is 1.1 µm2, and the Dykstra-Parsons permeability coefficient averages 0.7. Oil viscosity at reservoir temperature averages approximately 9 mPa·s, and the total salinity of the formation water varies from 3000 to 7000 mg/L. The field was discovered in 1959, and a waterflood was initiated in 1960. The world's largest polymer flood was implemented at Daqing, beginning in December 1995. By 2007, 22.3% of total production from the Daqing oil field was attributed to polymer flooding. Polymer flooding should boost the ultimate recovery for the field to more than 50% OOIP--10 to 12% OOIP more than from waterflooding. At the end of 2007, oil production from polymer flooding at the Daqing oil field was more than 11.6 million m3 (73 million bbl) per year (sustained for 6 years). The polymers used at Daqing are high-molecular-weight partially hydrolyzed polyacrylamides (HPAMs). During design of a polymer flood, critical reservoir factors that traditionally receive consideration are the reservoir lithology, stratigraphy, important heterogeneities (such as fractures), distribution of remaining oil, well pattern, and well distance. Critical polymer properties include cost-effectiveness (e.g., cost per unit of viscosity), resistance to degradation (mechanical or shear, oxidative, thermal, microbial), tolerance of reservoir salinity and hardness, retention by rock, inaccessible pore volume, permeability dependence of performance, rheology, and compatibility with other chemicals that might be used. Issues long recognized as important for polymer-bank design include bank size (volume), polymer concentration and salinity (affecting bank viscosity and mobility), and whether (and how) to grade polymer concentrations in the chase water. This paper describes the design procedures that led to favorable incremental oil production and reduced water production during 12 years of successful polymer flooding in the Daqing oil field.

Reasonable Injection Parameters for the Polymer Flooding Research in the Putaohua I1~2 Oil Layer of Xing IV Area

2014 ◽  
Vol 535 ◽  
pp. 705-708
Author(s):  
Li Jun Wang ◽  
Lin Qiang Li
Keyword(s):  
Oil Recovery ◽  
Theoretical Basis ◽  
Economic Benefit ◽  
Injection Rate ◽  
Polymer Flooding ◽  
Oil Field ◽  
Polymer Molecular Weight ◽  
Weight Concentration ◽  
Injection Parameters ◽  
Daqing Oil Field

In order to increase the oil production and ultimate recovery of Xingbei area of Daqing oil field, according to the geologic conditions of Xingbei region .The reasonable injection parameters of polymer flooding were discussed considering geologic information , experiments in lab, economic benefit . The study consists of analyzing the law governing of the remaining oil in Xingbei. By applying the methods of the combination of geological modeling and simulation for analyzing different polymer molecular weight, concentration, dosage and injection rate. concludes the influence of different injection parameters to ultimate oil recovery, This paper provides a theoretical basis and experimental support for apricot north polymer flooding of Xingbei area of Daqing oilfield .

The Application of Surfactin Biosurfactant as Surfactant Coupler in ASP Flooding in Daqing Oil Field

2009 ◽  
Author(s):  
Dawei Wang ◽  
Yuguang Zhang ◽  
Yongjian Liu ◽  
Chunlei Hao ◽  
Menghua Guo
Keyword(s):  
Oil Field ◽  
Asp Flooding ◽  
Daqing Oil Field

Commercial test of ASP Flooding in Daqing Oil Field

2008 ◽  
Author(s):  
Jiecheng Cheng ◽  
Dianping Xu ◽  
Bai Wenguang
Keyword(s):  
Oil Field ◽  
Commercial Test ◽  
Asp Flooding ◽  
Daqing Oil Field

Comparison of Strong-Alkali and Weak-Alkali ASP-Flooding Field Tests in Daqing Oil Field

2018 ◽  
Vol 33 (02) ◽  
pp. 353-362 ◽  
Author(s):  
Hu Guo ◽  
Yiqiang Li ◽  
Fuyong Wang ◽  
Yuanyuan Gu
Keyword(s):  
Field Tests ◽  
Oil Field ◽  
Asp Flooding ◽  
Daqing Oil Field

The Research on Influencing Factors of Polymer Flooding

2010 ◽  
Vol 150-151 ◽  
pp. 608-611
Author(s):  
Wen Xiang Wu ◽  
Si Nan Zhu
Keyword(s):  
Molecular Weight ◽  
Polymer Solution ◽  
Influencing Factors ◽  
Coefficient Of Variation ◽  
Solution Concentration ◽  
Displacement Efficiency ◽  
Polymer Molecular Weight ◽  
Displacement Effect ◽  
Molecular Weight Polymer ◽  
Reservoir Permeability

By using artificial non-homogeneous cores which coefficient of variation is 0.72 to simulate reservoir sandstone, and proceed the research of displacement effect on three aspects, which are polymer molecular weight, polymer solution concentration and reservoir permeability. The results show that polymer solution concentration and polymer molecular weight have greater influence on the displacement efficiency, while reservoir permeability has very little influence when it is more than 700md.

Sign in / Sign up

Export Citation Format

Share Document