Control of Water Production in Reservoirs with High Temperature Produced by Water Drive

1992 ◽  
Author(s):  
M.L. Ventresca ◽  
G. Torres
Keyword(s):  
High Temperature ◽  
Water Production

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

1994 ◽  
Author(s):  
Paola Albonico ◽  
Martin Bartosek ◽  
T.P. Lockhart ◽  
Emilio Causin
Keyword(s):  
High Temperature ◽  
Polymer Gels ◽  
Water Production

A New Experimental Evaluation Technology for Foaming Agent in High Temperature and High Pressure Formation

2014 ◽  
Vol 962-965 ◽  
pp. 877-882
Author(s):  
Guang Qiang Cao ◽  
Yun Wang ◽  
Nan Li
Keyword(s):  
High Pressure ◽  
High Temperature ◽  
Experimental Evaluation ◽  
Evaluation Method ◽  
Water Production ◽  
Gas Field ◽  
Foaming Agent ◽  
Influence Of Temperature ◽  
Temperature Range ◽  
Temperature And Pressure

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.

Combining Preformed Particle Gel and Curable Resin-Coated Particles To Control Water Production from High-Temperature and High-Salinity Fractured Producers

SPE Journal ◽  
2019 ◽  
Vol 25 (02) ◽  
pp. 938-950 ◽  
Author(s):  
Lin Sun ◽  
Daibo Li ◽  
Wanfen Pu ◽  
Liang Li ◽  
Baojun Bai ◽  
...  
Keyword(s):  
High Temperature ◽  
High Speed ◽  
High Salinity ◽  
Fractured Reservoirs ◽  
Water Production ◽  
Combined System ◽  
Injection Wells ◽  
Coated Particles ◽  
Preformed Particle Gel ◽  
Control Water

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.

Performance of Silicate Gel and Polymer/Cr(III) Gel Treatments in High Temperature Reservoirs

2013 ◽  
Vol 316-317 ◽  
pp. 782-785 ◽  
Author(s):  
Guang Xi Shen ◽  
Ji Ho Lee ◽  
Kun Sang Lee
Keyword(s):  
High Temperature ◽  
Oil Recovery ◽  
Poor Performance ◽  
High Water ◽  
Water Flooding ◽  
Water Production ◽  
Reservoir Temperature ◽  
Treatment Results ◽  
Gel Treatment ◽  
Extensive Numerical Simulation

Gel treatment is increasingly used as permeability modifiers in reducing high water production. To analyze the influences of reservoir temperature on the performance of gel treatment, extensive numerical simulation study is undertaken to model the behavior of high temperature reservoirs. Polyacrylamide (PAM)/Cr3+ gel treatment and silicate gel method are compared with waterflooding through water-oil ratio and cumulative oil recovery. The results demonstrate that, for the case of common temperature, PAM/Cr3+ gel treatment results in highly decreased water-oil ratio compared with water flooding. PAM/Cr3+ gel have shown poor performance in high temperature reservoirs. However, silicate gel is still effective in high temperature reservoirs.

As(V) rejection by NF membranes using high temperature sources for drinking water production

2019 ◽  
Vol 8 ◽  
pp. 198-204 ◽  
Author(s):  
Bayardo Gonzalez ◽  
S.G.J. Heijman ◽  
L.C. Rietveld ◽  
D. van Halem
Keyword(s):  
Drinking Water ◽  
High Temperature ◽  
Water Production ◽  
Drinking Water Production

Gelation Kinetics and Performance Evaluation of an Organically Crosslinked Gel at High Temperature and Pressure

SPE Journal ◽  
2008 ◽  
Vol 13 (03) ◽  
pp. 337-345 ◽  
Author(s):  
Ghaithan A. Al-Muntasheri ◽  
Hisham A. Nasr-El-Din ◽  
Pacelli L.J. Zitha
Keyword(s):  
Thermal Stability ◽  
High Temperature ◽  
Gelation Time ◽  
Polymer Gels ◽  
Water Production ◽  
Thermally Stable ◽  
Covalent Bonds ◽  
Pressure Drops ◽  
Gelation Kinetics ◽  
Thermal Stability Of

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.

High-temperature fuel cells for fresh water production

Desalination ◽  
2005 ◽  
Vol 182 (1-3) ◽  
pp. 471-482 ◽  
Author(s):  
P. Lisbona ◽  
J. Uche ◽  
L. Serra
Keyword(s):  
Fuel Cells ◽  
High Temperature ◽  
Fresh Water ◽  
Water Production
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