Effective Gelation-Delaying Additives for Cr+3/Polymer Gels

Albonico, Paola; Burrafato, Giovanni; Lullo, A. Di; Lockhart, Thomas P.

doi:10.2118/25221-ms

Cited by 30 publications

(23 citation statements)

References 17 publications

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“…Gelling systems cross-linked with metal ions [11,[20][21][22][23][24][25][26][27][28][29][30][31][32][33][34][35] Several cases of success of field applications of in situ cross-linked gelling systems have been reported for the conformance-improvement treatment of high-permeability zones located near-wellbore (with radial penetration into the matrix lower than 5 m) and far-wellbore (with radial penetration into the matrix greater than 5 m). However, in situ cross-linked gelling systems still face a number of operational difficulties regarding the control of the gelation kinetics, the efficient mixing of the polymer and cross-linker within the reservoir, the prevention of undesirable separation of the gelant components into the heterogeneous matrix, and the risk of plugging the whole formation or areas containing oil [23].…”

Section: Formation Water Salinitymentioning

confidence: 99%

“…• the use of metal ions retardants to increase the gelant gelation time, for example, acetates, propionates, malonates, and ascorbates [17,[32][33][34][35]. Malonate ions are 33 times slower than acetate ions in the gelation of PAM-AMPS at 120°C.…”

Section: Gelling Systems Cross-linked With Metal Ionsmentioning

confidence: 99%

“…Under the same conditions, ascorbate ions are 51 times slower than acetate ions. Nevertheless, the use of complexes of metal ions results in the formation of weak hydrogels [34];…”

Section: Gelling Systems Cross-linked With Metal Ionsmentioning

confidence: 99%

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Hydrogels Applied for Conformance-Improvement Treatment of Oil Reservoirs

Tessarolli¹,

Gomes²,

Mansur³

2018

Hydrogels

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This chapter aims at presenting a review of gelling polymer systems that are commercially available or under academic development with potential to control the anisotropic permeability profile of heterogeneous oil reservoirs. In these reservoirs, the oil recovery and sweep efficiency tend to be low, even after applying secondary and enhanced oil recovery methods, because the injected fluid flows preferably through the matrix's most permeable regions leaving behind part of the displaceable oil retained at the nonswept volume. For that, cross-linked polymers can be used to plug the high-permeability main paths by means of: (i) the formation of an in situ hydrogel or (ii) the adsorption or swelling of precross-linked hydrogel within the reservoir pores, thus causing the diversion of the subsequently injected fluid to low-permeability zones and/or preventing the channeling and early breakthrough of the injected fluid (water or gas) in production wells. The selection of the most suitable hydrogel for the reservoir conformance-improvement treatment should take into account the nature of the conformance problem, the reservoir's lithology, mineralogy, temperature, pH value, salinity, and hardness of the formation water, as well as the gelling system toxicity and cost.

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Section: Formation Water Salinitymentioning

confidence: 99%

Section: Gelling Systems Cross-linked With Metal Ionsmentioning

confidence: 99%

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Hydrogels Applied for Conformance-Improvement Treatment of Oil Reservoirs

Tessarolli¹,

Gomes²,

Mansur³

2018

Hydrogels

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“…The gel viscosity was measured up to 100,000 mPa•s. Therefore, the gelation of polymer gel system has potential for low temperature reservoirs [31,32]. However, for low temperature and high salinity reservoirs, such as the Obangue oilfield in Gabon (reservoir temperature is 50 • C, water salinity is 286,257 ppm), the gelation behavior is not clear.…”

Section: Introductionmentioning

confidence: 99%

Gelation Behavior Study of a Resorcinol–Hexamethyleneteramine Crosslinked Polymer Gel for Water Shut-Off Treatment in Low Temperature and High Salinity Reservoirs

et al. 2017

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Mature oilfields usually encounter the problem of high watercut. It is practical to use chemical methods for water-shutoff in production wells, however conventional water-shutoff agents have problems of long gelation time, low gel strength, and poor stability under low temperature and high salinity conditions. In this work a novel polymer gel for low temperature and high salinity reservoirs was developed. This water-shutoff agent had controllable gelation time, adjustable gel strength and good stability performance. The crosslinking process of this polymer gel was studied by rheological experiments. The process could be divided into an induction period, a fast crosslinking period, and a stable period. Its gelation behaviors were investigated in detail. According to the Gel Strength Code (GSC) and vacuum breakthrough method, the gel strength was displayed in contour maps. The composition of the polymer gel was optimized to 0.25~0.3% YG100 + 0.6~0.9% resorcinol + 0.2~0.4% hexamethylenetetramine (HMTA) + 0.08~0.27% conditioner (oxalic acid). With the concentration increase of the polymer gel and temperature, the decrease of pH, the induction period became shorter and the crosslinking was more efficient, resulting in better stability performance. Various factors of the gelation behavior which have an impact on the crosslinking reaction process were examined. The relationships between each impact factor and the initial crosslinking time were described with mathematical equations.

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“…The use of stronger ligands, such as glycolate and malonate, is a possible way to delay the crosslinking time. However, dehydration synthesis can also occur when binding with Cr 3+ gets too strong . In addition, the stability of the gel decreases in higher temperature reservoirs because of the weakening of the ionic bonds.…”

Section: Introductionmentioning

confidence: 99%

New insights into phenol–formaldehyde‐based gel systems with ammonium salt for low‐temperature reservoirs

Ren

Jia

et al. 2014

J of Applied Polymer Sci

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Polymer gels are effective tools that are still widely used in mature oilfield development to stop unwanted fluid production from oil and gas wells, but conventional gelant formulations have become increasingly difficult to apply at low and ultralow temperatures. Because of this situation, the gelation performance of phenol-formaldehyde-based gel systems at a low temperature of 25 C is discussed in this article. The results show that the gelation time and strength of the gel systems can be perfectly controlled by the adjustment of the polymer concentration, the molecular weight, the crosslinking agent concentration, the ammonium salt concentration, and the composition. The polymer concentration and molecular weight can affect not only the gelation time and the gel strength but also its stability. The ammonium salt concentration affected not only the gelation time but also its viscosity before a detectable gel formed. Among them, the polymer concentration was the most important factor affecting the gel stability. For lowtemperature reservoirs, the phenol-formaldehyde-based gel system achieved a much longer gelation time. Polymer gels formulated with a combination of 0.2-0.4 wt % polymer, 0.5-1.0 wt % formaldehyde or phenol-formaldehyde, and 0.1-0.6 wt % ammonium salt, and we added 0.02-0.03 wt % resorcinol to provide a gelation time between 2 h and 2 days. The maximum gel strength reached code I. The results of this study suggest that the formaldehyde-based gel system could be used effectively in low-temperature reservoirs.

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Effective Gelation-Delaying Additives for Cr+3/Polymer Gels

Cited by 30 publications

References 17 publications

Hydrogels Applied for Conformance-Improvement Treatment of Oil Reservoirs

Hydrogels Applied for Conformance-Improvement Treatment of Oil Reservoirs

Gelation Behavior Study of a Resorcinol–Hexamethyleneteramine Crosslinked Polymer Gel for Water Shut-Off Treatment in Low Temperature and High Salinity Reservoirs

New insights into phenol–formaldehyde‐based gel systems with ammonium salt for low‐temperature reservoirs

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