Influence of electrolytes on the performance of a graft copolymer used as fluid loss additive in oil well cement

Salami, Oyewole Taye; Plank, Johann

doi:10.1016/j.petrol.2016.02.021

Cited by 22 publications

(7 citation statements)

References 5 publications

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“…Traditional polymer-based oil well cement retarders were mainly linear polymer, − which were prone to abnormal gelation or slurry thickening at the medium-high temperature (90 to 150 °C) range. In this research, high-temperature resistant monomers, AMPS and SSS, were used to synthesize polymeric retarders with linear and branched structures, respectively.…”

Section: Resultsmentioning

confidence: 99%

Synthesis and Evaluation of Highly Inhibitory Oil Well Cement Retarders with Branched-Chain Structures

Lv,

Zhang,

Xie

et al. 2023

ACS Omega

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Cementing at medium temperature and high temperature (90–150 °C) is facing challenges on account of the properties of the retarders. Except for the thermal stability, abnormal gelation, such as “bulging” and “stepping”, often takes place and results in safety problems. In this article, the synthesis of a new retarder DRH-150 was introduced. First, a main chain with thermal-resistant groups, 2-acrylamido-2-methylpropanesulfonic acid-acrylic acid (AMPS-IA-AA) was prepared by free radical polymerization. Second, the retarder with a branched structure was synthesized by the grafting reaction. Evaluation of the construction performance showed that, within the temperature range from 90 to 150 °C, the initial viscosity of the cement slurry with DRH-150 was less than 15 Bc, exhibiting an adjustable thickening time and a dosage sensitivity of less than 20%. Meanwhile, no abnormal gelation phenomenon was observed. Referring to the static gelation, both the transition time and the starting strength time (1 MPa) were short. The overall results proved that the retarder DRH-150 might ensure the safety of well cementing and improve the wellbore sealing effect in deep wells, ultradeep wells, and complex wells.

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Section: Resultsmentioning

confidence: 99%

Synthesis and Evaluation of Highly Inhibitory Oil Well Cement Retarders with Branched-Chain Structures

Lv,

Zhang,

Xie

et al. 2023

ACS Omega

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“…Based on preliminary experiments and the literatures [11][12][13][14], a monocarboxylic acid (AA) and dicarboxylic acids (MA and IA) were initially selected as different source monomers of carboxylic acid groups to synthesize fluid loss additives. To maintain an equal molar ratio of the carboxylic acid groups, the molar ratio of each reaction monomer for AMPS:AM:AA was 45:45:10, for AMPS:AM:MA was 45:45:5, and for AMPS:AM:IA was 45:45:5.…”

Section: Determination Of Monomer Ratiomentioning

confidence: 99%

Assessment of the Performances of Carboxylic Acid Monomers as Fluid Loss Additives for Oil-Well Cement

Liu¹,

Huang²,

Zheng³

et al. 2022

Fluid Dynamics &Amp; Materials Processing

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The application of polycarboxylic acid as a fluid loss additive for cement (i.e., a substance specifically designed to lower the volume of filtrate that passes through the cement) can prolong the thickening time of cement slurries. Given the lack of data about the effects of carboxylic acid monomers as possible components for the additives traditionally used for oil-well cement, in this study different cases are experimentally investigated considering different types of these substances, concentrations, temperatures, and magnesium ion contamination. The results demonstrate that itaconic acid has a strong retarding side effect, while maleic and acrylic acids have similar influences on the thickening time of the cement slurry. The rheological properties of the cement slurry tend to deteriorate when the carboxylic acid monomer content in the fluid loss additive is increased to 40%. If the temperature exceeds 80°C, there is a significant decrease in the related impact on the thickening duration. With an increase in the intrusion of magnesium ions to >0.5%, both the rheological properties of the cement slurry and the thickening time are affected in a negative way.

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“…Dias et al [7], Han and Zhang [8], and Cui et al [9] depicted that molecular structure characteristics of the polymeric fluid loss additive were the key points to improve fluid loss additive application effectiveness. Salami and Plank depicted that the highly dispersed grafting polymer structure was beneficial to overcome unnecessary side effects when contacting with electrolyte matters, such as metal ions [10]. Besides, Guo et al indicated the control ability of the carboxylic group to retard side effects of the AMPS-type fluid loss additive and fluid loss control ability improvement [11].…”

Section: Introductionmentioning

confidence: 99%

“…And Liu et al indicated that amphoteric polymers could be useful for anticalcium contamination [12]. Meanwhile, Salami and Plank depicted the influence of electrolytes to fluid loss additive, and their research results indicated that unsuitable cationic matters, such as Mg 2+ , were not beneficial for additive performance in oil well cement slurry [10]. So, as depicted by the above research results, for traditional AMPS-Na-type additives, which only showed physicochemical properties of the anionic polymer, the new components used for additive systems could become the key point to improve the effectiveness of the additive system.…”

Section: Introductionmentioning

confidence: 99%

Function Synergy of Cross-Linked Cationic PVA Polymer to AMPS-Type Fluid Loss Additive Used for Cement-Based Material

Wang

Zheng³

et al. 2020

International Journal of Polymer Science

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In this research, a kind of 2-acrylamido-2-methylpropanesulfonic acid sodium salt-(AMPS-Na-) type copolymer additive, the fluid loss additive (FLA), named as FLA A additive, was used for research. The performance of FLA A was tested and found to fail in the effective control of free water and to hinder the hydration process for delaying the breaking of the early hydration shell. The reason for it was the absorbed behavior and chelating effect of the AMPS-Na unit to Ca 2+ hydrating cement particles. Thus, a cationic polyvinyl alcohol (PVA) polymer, modified by glyoxal and boric acid, was discovered due to its excellence in associating with the FLA A additive for controlling the free cement-based material water amount and preventing the chelating effect of FLA A chains on the surface of the cement-based material. Glyoxal/boric acid-modified polyvinyl alcohol, abbreviated as PVAGB or PVA-G-B, was with special molecular properties, i.e., positive ZETA (ζ) potential characteristics and cross-linked molecular structure. Due to competitive absorbed behavior of glyoxal-modified hydroxyl groups and free Ca 2+ released by the hydration product, the chelating effect of AMPS-Na units to Ca 2+ was weakened and the possibility of FLA A chains being absorbed to the surface of the cement-based material was decreased. Then, the formation of a complete fluid loss system was obtained; i.e., the fluid loss volume decreased to less than 50 mL at 30°C and 108 mL at 80°C with 0.2 percentage by weight of cement (%BWOC) of PVAGB and 0.50%BWOC (percentage by weight of cement) of FLA A. Besides, the hydration process of cement-based material was accelerated due to formation of more C-S-H gels in the early hydration period. As a result, the cement-based material not only showed no worse compressive-strength retrogression but also showed a stable 28-day compressive strength of 28 MPa.

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Influence of electrolytes on the performance of a graft copolymer used as fluid loss additive in oil well cement

Cited by 22 publications

References 5 publications

Synthesis and Evaluation of Highly Inhibitory Oil Well Cement Retarders with Branched-Chain Structures

Synthesis and Evaluation of Highly Inhibitory Oil Well Cement Retarders with Branched-Chain Structures

Assessment of the Performances of Carboxylic Acid Monomers as Fluid Loss Additives for Oil-Well Cement

Function Synergy of Cross-Linked Cationic PVA Polymer to AMPS-Type Fluid Loss Additive Used for Cement-Based Material

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