Synthesis, characterization, and working mechanism of a synthetic high temperature (200°C) fluid loss polymer for oil well cementing containing allyloxy-2-hydroxy propane sulfonic (AHPS) acid monomer

2012 ◽  
Vol 128 (1) ◽  
pp. 851-860 ◽  
Author(s):  
Constantin Tiemeyer ◽  
Johann Plank
Keyword(s):  
High Temperature ◽  
Fluid Loss ◽  
Oil Well ◽  
Working Mechanism

Performance Evaluation of Polycarboxylic Acid Dispersant for Oil Well Cementing

2020 ◽  
Vol 993 ◽  
pp. 1341-1350
Author(s):  
Xiu Jian Xia ◽  
Yong Jin Yu ◽  
Jian Zhou Jin ◽  
Shuo Qiong Liu ◽  
Ming Xu ◽  
...  
Keyword(s):  
High Temperature ◽  
Salt Resistance ◽  
Strength Development ◽  
Fluid Loss ◽  
Oil Well ◽  
Polycarboxylic Acid ◽  
Cement Slurry ◽  
Deep Wells ◽  
Oil Well Cement ◽  
Well Cement

The conventional oil-well cement dispersant has the characteristics of poor dispersion at high temperature, poor compatibility with other additives, and environmental pollution during the production process. In this article, with ultra-early strong polyether monomer, acrylic acid, 2-acrylamine-2-methylpropyl sulfonic acid, sodium methacrylate as copolymer monomers, an environmentally friendly polycarboxylic acid dispersant, DRPC-1L, was prepared by the aqueous solution free-radical polymerization. The chemical composition and thermal stability of the synthetic copolymer were characterized by FTIR and TGA techniques. The evaluation results show that DRPC-1L has a wide temperature range (30~210 °C), good salt-resistance and dispersing effect. It can significantly improve the rheological performance of cement slurry, and it is well matched with oil-well cement additives such as fluid loss agent, retarder and so on. Moreover, it is beneficial to the mechanical strength development of set cement, especially the early compressive strength. It can also inhibit the abnormal gelation phenomenon of cement slurry, flash set, that occurs during high temperature thickening experiments, which plays an important role in enhancing the comprehensive performance of cement slurry. Consequently, the novel polycarboxylic acid dispersant has good application prospects in deep and ultra-deep wells cementing.

scholarly journals Impact of Temperature on the Solution Conformation and Performance of AMPS®- and AHPS-based Fluid Loss Polymers in Oil Well Cement

2014 ◽  
Vol 69 (11-12) ◽  
pp. 1131-1140 ◽  
Author(s):  
Constantin Tiemeyer ◽  
Johann Plank
Keyword(s):  
High Temperature ◽  
Sulfonic Acid ◽  
Temperature Stability ◽  
Temperature Treatment ◽  
High Temperature Treatment ◽  
Fluid Loss ◽  
Water Retention Capacity ◽  
Oil Well ◽  
Retention Capacity ◽  
And Performance

Abstract A copolymer composed of 2-acrylamido-2-methyl propane sulfonic acid (AMPS®) and N,Ndimethylacrylamide (NNDMA) as well as a forpolymer based on AMPS®, NNDMA, 1-allyloxy- 2-hydroxy propane sulfonic acid (AHPS) and acrylic acid (AA) were synthesized and tested for their temperature stability. Both polymers were dissolved and aged in cement pore solution at temperatures between 100 and 220°C and 35 bar pressure, simulating conditions in actual well cementing. The influence of this high-temperature treatment on the fluid loss performance was assessed via highpressure filtration tests. Water retention capacity and adsorption of AMPS®-co-NNDMA was found to decrease as a result of temperature-induced shrinkage of the stiff, linear polymer chain, as evidenced by dynamic light scattering (DLS) measurement of its hydrodynamic radius. Oppositely, the AHPS-based fluid loss additive did not exhibit coiling under high-temperature conditions. Therefore, its adsorption remained unaffected, and a stable fluid loss performance was observed

Synthesis and Properties of Dispersive Type High Temperature Filtrate Reducer Used in Oil Well Cement

2013 ◽  
Vol 734-737 ◽  
pp. 2136-2140
Author(s):  
Di Hui Ma ◽  
Zhen Wei ◽  
Zong Gang Wang
Keyword(s):  
High Temperature ◽  
Rheological Property ◽  
Mass Fraction ◽  
Salt Resistance ◽  
Fluid Loss ◽  
Oil Well ◽  
Cement Slurry ◽  
Oil Well Cement ◽  
Cement Strength ◽  
Well Cement

The advanced dispersive type high temperature filtrate reducer used in oil well cement was synthesized with 2-acryloyl-2-methyl-propyl sulfonic (AMPS) , N, N-dimethylacrylamide (DMAA) and organic acids. When the mass fraction of synthetic filtrate reducer was 1%, the filter loss of the cement slurry was 30ml/30min at 120 °C and 49ml/30min at 150°C respectively, and the cement strength was 25MPa after 24 hours, and the rheological property of the cement slurry was well when the mass fraction of synthetic filtrate reducer was 2%, and liquidity factor was 0.85, and the consistency was 0.43. The results showed that the filtrate reducer had good dispersity and could control the fluid loss efficiently, and the ability of resistance to high temperature and salt resistance was good.

Liquid Strength Retrogression Control Additive

2021 ◽  
Author(s):  
Rahul Jadhav ◽  
Thomas Pisklak
Keyword(s):  
High Temperature ◽  
Free Water ◽  
Fluid Loss ◽  
Oil Well ◽  
Cement Slurry ◽  
Study Results ◽  
Different Temperatures ◽  
Improved Performance ◽  
Slurry Stability ◽  
Well Cement

Abstract To mitigate strength retrogression at temperatures, higher than 230°F, well cement designs typically include strength retrogression control additives (SRCAs). Solid siliceous materials (e.g., silica flour, fume, and sized-sands) are commonly used SRCAs that are incorporated into cements using dry-blending techniques. This study highlights liquid silica compositions as alternative SRCAs to dry-blended silica for high-temperature cementing. Liquid additives can be managed easily, delivered accurately, and offer a reduced on-site footprint, thus making them particularly advantageous for operations offshore and in remote locations. This paper presents a study on the use of liquid silica compositions as SRCAs and their effect on cement slurry properties, such as thickening time, mixability, fluid loss, rheology, and free water. The cement slurry used during the current study was prepared and tested according to API RP 10B-2 (2005). The performance of the liquid silica composition was tested at temperatures up to 400°F. Set cement samples were prepared using the liquid silica composition and silica flour, cured for up to 14 days at different temperatures. In addition, permeability testing was also performed on the samples. This paper presents the findings of this research, including strength and permeability test results on cement blends cured at temperatures of 300, 330, 350, and 400°F. The liquid silica composition, which provided silica to the cement formulation equivalent to 35% BWOC dry silica (48% BWOC liquid SRCA), functioned effectively as an SRCA at temperatures up to 330°F. Signs of strength retrogression were observed at 350°F and were more pronounced at 400°F. A greater concentration of the liquid silica composition may be necessary to prevent strength retrogression at temperatures higher than 330°F. The liquid silica composition also demonstrated mild retardation and a dispersing effect on the slurry. However, it helped enable improved slurry stability and suspension, thus providing improved control over free water without adverse effects on fluid loss and sedimentation. The study results demonstrate that a liquid SRCA can help improve the performance of annular cement designs to provide dependable barriers and effective zonal isolation during high-temperature cementing applications. The improved performance enabled by this liquid silica composition verifies its potential use as an alternative SRCA for high-temperature oil well cementing operations.

scholarly journals Working mechanism of nano-SiO2 sol to alleviate the strength decline of oil well cement under high temperature

2019 ◽  
Vol 6 (5) ◽  
pp. 517-523
Author(s):  
Chengwen Wang ◽  
Xin Chen ◽  
Wei Zhou ◽  
Yonghong Wang ◽  
Yucheng Xue ◽  
...  
Keyword(s):  
High Temperature ◽  
Oil Well ◽  
Working Mechanism ◽  
Nano Sio2 ◽  
Oil Well Cement ◽  
Well Cement

Preparation of a novel forpolymer as fluid loss additive for high temperature oil well cementing

2014 ◽  
Vol 87 (9) ◽  
pp. 1377-1381 ◽  
Author(s):  
Qiang Xiao ◽  
Pinhua Rao ◽  
Wenfa Xiao ◽  
Xinxin Liu ◽  
Wenqi Zhang
Keyword(s):  
High Temperature ◽  
Fluid Loss ◽  
Oil Well ◽  
Fluid Loss Additive
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