Preparation and properties of a dispersing fluid loss additive based on humic acid graft copolymer suitable for cementing high temperature (200°C) oil wells

Salami, Oyewole Taye; Plank, Johann

doi:10.1002/app.38980

Cited by 44 publications

(18 citation statements)

References 19 publications

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“…The humic acid graft copolymer was synthesized by grafting lateral chains of 2-acrylamido-tertiary-butyl sulfonic acid, N, N-dimethylacrylamide and acrylic acid onto a backbone of humic acid using aqueous free radical copolymerization as described in literature (Salami 2013). The proposed chemical structure is shown in Fig.…”

Section: Humic Acid-atbs-nndm-aa Graft Copolymermentioning

confidence: 99%

Temperature-Induced Changes in the Solved Conformation of Cement Fluid Loss Polymers and the Consequences for Their Performance

Plank

Hurnaus

Tiemeyer

et al. 2015

SPE International Symposium on Oilfield Chemistry

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On deep and ultra-deep wells, high temperature stable additives are applied to control the properties of cement slurries. For fluid loss control, polymers based on 2-acrylamido-tertiary-butyl sulfonic acid (ATBS) are commonly used. However, at elevated temperatures the performance of such polymers can decrease. The mechanism behind this change is mostly attributed to temperature-induced decomposition of the polymer, e.g. via oxidation.In our study, we investigated the effect of high temperature on four synthetic fluid loss additives (FLAs) containing ATBS monomer. All FLAs were dissolved in cement pore solution and exposed to 100 -220°C for 8 hours. The heat-treated polymer solutions were then added to cement slurries, and the respective fluid loss of these slurries was determined.At increased ageing temperatures, a decrease in fluid loss performance was observed for the ATBS-NNDMA copolymer while two others, a humic acid-ATBS-NNDMA-AA graft copolymer and an ATBS-NNDMA-AHPS-AA forpolymer showed consistent performance over the entire temperature range of 100 -220°C. The performance of the fourth polymer, a lignite based ATBS-NNDMA graft copolymer, was most surprising: it decreased gradually until 200°C, but improved very strongly after ageing at 220°C .To understand these different behaviors, all polymer samples were characterized regarding their molecular weight, anionic charge, radius of gyration, hydrodynamic radius and adsorbed conformation on cationic polystyrene nanoparticles as a model system for cement particles. For the ATBS-NNDMA copolymer significant coiling occurred, thus reducing its ability to plug the pores of the cement filter cake. Opposite to this, the ATBS-NNDMA-AHPS-AA forpolymer and the humic acid graft copolymer resisted to such coiling. Interestingly, the lignite based graft copolymer undergoes gradual temperature induced coiling up to 200°C, but expands significantly after ageing at 220°C. This effect greatly improves its fluid loss performance.The results can help to better understand the high temperature behavior of FLAs and other polymeric additives in cement, drilling or completion fluids.

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Section: Humic Acid-atbs-nndm-aa Graft Copolymermentioning

confidence: 99%

Temperature-Induced Changes in the Solved Conformation of Cement Fluid Loss Polymers and the Consequences for Their Performance

Plank

Hurnaus

Tiemeyer

et al. 2015

SPE International Symposium on Oilfield Chemistry

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“…These copolymers exhibit better anti-high temperature performance and salt resistance than natural polymers. [13][14][15][16][17][18] Perricone et al used AMPS, AM, and alkyl AM monomers to synthesize a copolymer (named COP) through inverse microemulsion polymerizations. In a field experiment, water-based mud with the COP copolymer can withstand 150 C. 19 Also, Wu et al synthesized AM/AMPS/itaconic acid (IA)/N-vinyl caprolactam by solution polymerization.…”

Section: Introductionmentioning

confidence: 99%

Synthetic copolymer (AM/AMPS/DMDAAC/SSS) as rheology modifier and fluid loss additive at HTHP for water‐based drilling fluids

Huang

Zhang

Zheng

2019

J of Applied Polymer Sci

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In the petroleum industry, high temperature and high pressure (HTHP) would dramatically worsen rheological properties and increase fluid loss volumes of drilling fluids. Synthetic polymer as an indispensable additive has attracted more and more attention recently. In this article, a new copolymer (named AADS) of 2‐acrylamide‐2‐methylpropanesulfonic acid, acrylamide, dimethyl diallyl ammonium chloride, and sodium styrene sulfonate was synthesized through aqueous solution polymerization. The chemical structure of the copolymer was characterized by Fourier transform infrared spectroscopy and nuclear magnetic resonance. Moreover, its thermal stability was simultaneously analyzed using a differential scanning calorimetry. The results showed that the synthetic polymer contained all the designed functional groups, and its structure was consistent to the desired one. Under contamination of sodium chloride, AADS solution maintained relatively high viscosity in high concentration brine, showing a good antisalt capacity. Furthermore, the effect of AADS content and temperature on rheological behavior and fluid loss volume of the water‐based drilling fluid (WBDF) containing the synthesized product were investigated according to the American Petroleum Institute standard. Results showed that the rheological and filtration properties of the prepared WBDF were improved with the increase in the AADS concentration before and after the thermal aging test. In addition, in the temperature range of 80–240 °C, a reversible rheological behavior was observed during the heating–cooling process, and the HTHP fluid loss was controlled within 22.5 mL, suggesting that the copolymer AADS was suitable for making WBDF s with high temperature resistance. © 2019 Wiley Periodicals, Inc. J. Appl. Polym. Sci. 2019, 136, 47813.

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“…Moreover, when drilling through salt beds, salt intrusion caused another undesired situation for the same phenomenon occurs. High temperature and salt intrusion result in unacceptable rheological and filtration properties for the use of fresh water drilling fluid . Therefore, improving the temperature resistance ability and salt resistance ability of the WDFs is necessary.…”

Section: Introductionmentioning

confidence: 99%

Hydrophobic‐associated polymer‐based laponite nanolayered silicate composite as filtrate reducer for water‐based drilling fluid at high temperature

Shen

Huang

et al. 2019

J of Applied Polymer Sci

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Wellbore instability caused by water invasion is the main problem in oil and gas drilling operation. This study reports the utilization of a hydrophobic-associated polymer-based laponite nanolayered silicate composite as a filtrate reducer in water-based drilling fluids (WDFs). The thermal performance and micromorphology of the composite were analyzed by thermogravimetric analysis, transmission electron microscope, and field emission scanning electron microscopy. The results indicated that the composite possessed a "bean pod" structure and a good thermal stability. The rheological properties of the composite solution were evaluated. The results showed that the hydrophobic association interaction of the composite is weak but existent, and the crosslink network structure is variable. The applied performances of WDFs containing the composite were also evaluated. Evaluation results showed that the composite could improve the properties of the thermal stability, salt tolerance, and fluid loss control of WDFs. The particle size distribution of WDFs and the micrographs of filter cakes explained the improving. The composite was expected to be applied as an efficient filtrate reducer for developing high performance drilling fluids.

show abstract

Preparation and properties of a dispersing fluid loss additive based on humic acid graft copolymer suitable for cementing high temperature (200°C) oil wells

Cited by 44 publications

References 19 publications

Temperature-Induced Changes in the Solved Conformation of Cement Fluid Loss Polymers and the Consequences for Their Performance

Temperature-Induced Changes in the Solved Conformation of Cement Fluid Loss Polymers and the Consequences for Their Performance

Synthetic copolymer (AM/AMPS/DMDAAC/SSS) as rheology modifier and fluid loss additive at HTHP for water‐based drilling fluids

Hydrophobic‐associated polymer‐based laponite nanolayered silicate composite as filtrate reducer for water‐based drilling fluid at high temperature

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