New Polymer Gels for Reducing Water Production in High-Temperature Reservoirs

Author(s):  
Paola Albonico ◽  
Martin Bartosek ◽  
T.P. Lockhart ◽  
Emilio Causin
SPE Journal ◽  
2008 ◽  
Vol 13 (03) ◽  
pp. 337-345 ◽  
Author(s):  
Ghaithan A. Al-Muntasheri ◽  
Hisham A. Nasr-El-Din ◽  
Pacelli L.J. Zitha

Summary Organically crosslinked gels have been used to control water production in high temperature applications. These chemical systems are based on the crosslinking of a polyacrylamide-based polymer/copolymer with an organic crosslinker. Polyethyleneimine (PEI) has been used as an organic crosslinker for polyacrylamide-based copolymers to provide thermally stable gels. Literature reported that PEI can form aqueous gels with polyacrylamide (PAM) at room temperature. In this paper, we show for the first time the possibility of crosslinking polyacrylamide with PEI at temperatures up to 140°C (285°F) and pressures up to 30 bars (435 psi). This paper reports data both in bulk and in porous media. The gelation time of the PAM crosslinked with PEI at high temperatures up to 140°C (285°F) and pressures up to 435 psi (30 bars) was measured. The effects of polymer concentration, crosslinker concentration, temperature, salinity, initial pH value, and the initial degree of hydrolysis of the polymer on the gelation time were examined in detail. All measurements were conducted in the steady shear mode. 13C Nuclear Magnetic Resonance Spectroscopy (13C NMR) was used to relate the gelation time to changes in the structure of the polymer and hence explain the variation in the gelation time in terms of the gelling system chemistry. In bulk, thermally stable gels were obtained by crosslinking PAM with PEI at 130°C (266°F) for at least 8 weeks. The performance of the PAM/PEI system in sandstone cores at a temperature of 90°C (194°F) and pressure drops of 68.95 bars (1,000 psi) was examined. The system was found to be stable for 3 weeks, where the permeability was reduced by a factor of 100%. Introduction Water production is a serious problem in petroleum-producing operations. Additional costs are imposed by processing, treating, and disposing unwanted water. Of the available remediation techniques, chemical methods using polymer gels have been widely applied. The success rate of these chemical treatments depends, among other factors, on the understanding of gelation kinetics, gelant's compatibility with reservoir fluids, and thermal stability of the final gel. Polymer gels have been used to reduce water production through the disproportionate permeability reduction (DPR) (Zaitoun and Kohler 1988; Liang et al. 1995). In DPR, the relative permeability to water is reduced to a greater extent than that to oil (or gas). Polymer gels were also used to totally block the pore space of the water producing zones in both matrix (Vasquez et al. 2003) and fractures (Alqam et al. 2001). Polymer gels are generally classified into two categories based on the nature of polymer/crosslinker bonding chemistry. The first type is inorganic gel systems based on the crosslinking of the carboxylate groups on the partially hydrolyzed polyacrylamide chain (PHPA) with a trivalent cation like Cr(III) (Sydansk 1990; Lockhart 1994). This crosslinking is believed to rely on coordination covalent bonding. It should be mentioned that Cr(III)-carboxylate/acrylamide-polymer gels (CC/AP) were reported to be stable at temperatures up to 148.9°C (300°F) in Berea cores under pressure drops of 68.95 bars (1,000 psi) (Sydansk and Southwell 2000). The second class of polymer gels is based on covalent bonds between the crosslinker and the acrylamide-based polymer (Morgan et al. 1998; Moradi-Araghi 2000). High temperature applications require the use of thermally stable covalently bonded systems. However, these covalent bonds do not guarantee long-term stability. Literature reports (Moradi-Araghi 2000) highlight the importance of using a thermally stable polymer to produce thermally stable gels. Polyacrylamide-based polymers are known to hydrolyze at high temperatures causing gel syneresis (expulsion of water out of the gel structure due to over crosslinking) (Moradi-Araghi 2000), especially in brines with high contents of Mg+2 and Ca+2, where polymer precipitation may also occur (Moradi-Araghi and Doe 1984). Therefore, more thermally stable monomers are copolymerized with the acrylamide polymer to minimize excessive hydrolysis (Moradi-Araghi et al. 1987; Doe et al. 1987) and enhance thermal stability of the produced gel.


SPE Journal ◽  
2006 ◽  
Vol 11 (02) ◽  
pp. 145-157 ◽  
Author(s):  
Tuan Q. Nguyen ◽  
Don W. Green ◽  
G. Paul Willhite ◽  
C. Stanley McCool

Summary For some polymer gels applied in reservoirs to control water flow, a favorable disproportionate permeability reduction (DPR) occurs in which permeability to water is reduced to a much greater extent than it is to oil. Permeability reduction in sandpacks by partially hydrolyzed polyacrylamide-chromium acetate gels was studied as functions of gel composition and the pressure gradients imposed on the gels. For the range of parameters studied, increased gel composition increased the factors by which the permeabilities to water and oil were reduced. Increased gel composition also increased selectivity, a measure of the water-permeability reduction with respect to oil-permeability reduction. Applied pressure gradients during steady-state flows had little effect on oil permeability and a moderate effect on water permeability. Material balances on phases and components in the sandpacks provided insights into mechanisms responsible for the development of flow channels through gelled sandpacks and mechanisms contributing to favorable DPR. Increased pressure gradient during channel development decreased the selectivity of the treatment. Introduction High water production is a major concern in mature hydrocarbon reservoirs. Costs of handling and disposing of water produced from oil reservoirs often shorten the life of a production well. Disposal of the water is also an environmental concern. In order to reduce water production, polymer gels have been used to modify the mobility of water and oil in petroleum reservoirs. When some gels are placed in a petroleum reservoir, permeability reduction occurs to a much greater extent for water than for oil. This phenomenon is known as favorable DPR. Reduced permeability to water can lead to decreased production of water, and sometimes increased oil production, thereby prolonging the useful life of the reservoir. Results reported in the literature have shown that the application of several polymer gel systems can result in DPR. Mechanisms for DPR have been debated, and the magnitude of the effect has been unpredictable from one application to another. Mechanisms for DPR that have been proposed and studied by several researchers are shown in Table 1. The usual method to study DPR is to saturate a porous medium with gelant, allow time for gelation to occur, and then inject oil and water to steady-state conditions and determine permeabilities at 100% fractional flow of each fluid. One aspect of this procedure that most of these experimental works do not describe or examine is the process that occurs when oil or water is first injected into the gel-treated porous media. It is our experience that the medium has very little permeability at the start of injection and that considerable time is required for the injected fluid to develop channels or flow paths through the system before a steady state is approached.


SPE Journal ◽  
2021 ◽  
pp. 1-11
Author(s):  
Tao Song ◽  
Qi Feng ◽  
Thomas Schuman ◽  
Jie Cao ◽  
Baojun Bai

Summary Excessive water production from oil reservoirs not only affects the economical production of oil, but it also results in serious environmental concerns. Polymer gels have been widely applied to decrease water production and thus improve oil production. However, traditional polymer gels such as partially hydrolyzed polyacrylamide (HPAM)/chromium (III) gel systems usually have a short gelation time and cannot meet the requirement of some conformance control projects. This paper introduces a novel polymer gel system of which crosslinking time can be significantly delayed. A branched polymer grafted from arginine by the surface initiation method is synthesized as the backbone, chromium acetate is used as the crosslinker, and no additional additives are used for the gel system. The results show that the gelation time of this system can be delayed to 61 days at 45°C and 20 days at 65°C because of the rigid structure of the branched polymer and the excellent chromium (III) chelating ability of arginine. The polymer gels have been stable for more than 150 days at 45 and 65°C. Coreflooding and rheology tests have demonstrated that this branched polymer has good injectivity and shear resistance in high-permeabilityrocks.


2014 ◽  
Vol 962-965 ◽  
pp. 877-882
Author(s):  
Guang Qiang Cao ◽  
Yun Wang ◽  
Nan Li

Foaming deliquification is one of the most widely used technologies in the development of water production gas field. The key of this technology is the experimental optimization or develop the foaming agent suitable for gas field. With the development of a large number of high temperature and high pressure gas field, foam experimental evaluation methods used at present can not satisfy the temperature range of high temperature and high pressure evaluation requirements, in this case, used the Ross-Miles foam evaluation method as the foundation, built a new experimental evaluation method for foaming agent. Through an example, analyzes the influence of temperature and pressure on the foaming agent performance.


SPE Journal ◽  
2019 ◽  
Vol 25 (02) ◽  
pp. 938-950 ◽  
Author(s):  
Lin Sun ◽  
Daibo Li ◽  
Wanfen Pu ◽  
Liang Li ◽  
Baojun Bai ◽  
...  

Summary Preformed-particle-gel (PPG) treatments have been successfully used in injection wells to reduce excessive water production from high-temperature, high-salinity fractured reservoirs. However, PPG itself cannot be used in fractured producers because it tends to wash out after the wells resume production. Therefore, we proposed to combine curable resin-coated particles (CRPs) with PPG to control water production from fractured producers. In this paper, millimeter-sized tubes and fractured carbonate cores were designed to comprehensively investigate water-plugging behaviors of the combined system under the conditions of various fracture parameters and PPG/CRP sizes. Particular attention was given to control the PPG washout after production was resumed. The results showed the cured CRPs could generate immobile packs in fractures and dramatically mitigate the PPG washout. The small size of the CRPs and the small ratio of CRP size to tube diameter contributed low permeability and homogeneity to CRP packs. Meanwhile, the less-permeable and more-homogeneous CRP pack, as well as the larger-sized PPGs, contributed to a higher PPG breakthrough pressure gradient. Moreover, some of the PPG particles blocked in the CRP packs could be released through high-speed brine injection from producers, which indicated the recoverability of the water plugging. This study provides a promising approach to reduce the high-water-cut problem in fractured producers.


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