Quantitative characterization of polyacrylamide–shale interaction under various saline conditions

Koteeswaran, Samyukta; Pashin, Jack C.; Ramsey, Joshua D.; Clark, Peter E.

doi:10.1007/s12182-017-0166-1

Cited by 17 publications

(7 citation statements)

References 46 publications

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“…Nonionic polymers such as poly(ethylene glycol) (PEG) and its derivatives are also often used, as they tend to adsorb in the interlayers of the clays by interaction with the interlamellar cations, thus avoiding increased hydration . Anionic polymers such as partially hydrolyzed polyacrylamides (PHPA) are often used, due to their ability to adsorb on the shales surface preventing the hydration . The most efficient are the cationic polyelectrolytes which replace interlamellar cations and prevent swelling.…”

Section: Introductionmentioning

confidence: 99%

Cationic starch derivatives as reactive shale inhibitors for water‐based drilling fluids

Cescon

Quartarone

Silva

et al. 2018

J of Applied Polymer Sci

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One of the major problems associated with the use of water‐based drilling fluids is the interaction of water with specific rock formations, such as shales, and the consequent swelling of reactive clays that may be present in that type of rock. Several types of clays reactivity inhibitors have been used by the oil industry, and the most effective ones are the cationic polyelectrolytes, such as the poly(diallyldimethylammonium chloride) (PDADMAC). However, this polyelectrolyte is very toxic. In this work, a series of cationic starch derivatives with different cationic degrees were synthesized with the objective of evaluating their potential as environmentally correct shale reactivity inhibitors. The results showed that the synthesized derivatives presented a good capacity of adsorption on bentonite and an efficient inhibition of the shale reactivity. The derivative with an intermediate cationic degree presented the best performance. In the tests with the formulated fluids this derivative provided an intact cuttings recovery of 84.8% and a total recovery of 92.3%. These values are very close to those found for the PDADMAC additive, therefore indicating that this cationic starch derivative presents a good potential as inhibitor of the shale reactivity. © 2018 Wiley Periodicals, Inc. J. Appl. Polym. Sci. 2018, 135, 46621.

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Section: Introductionmentioning

confidence: 99%

Cationic starch derivatives as reactive shale inhibitors for water‐based drilling fluids

Cescon

Quartarone

Silva

et al. 2018

J of Applied Polymer Sci

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“…A high value of ζ-potential indicates more degree of repulsion, which means particles are in suspension as required in drilling fluid properties. As the value of ζ-potential is less, the system will be more unstable as the chance of aggregation of the solid particles increases. , The values of the different drilling fluid samples are shown in Figure . The results show that the surface charge of the drilling fluid is dominated by a negative charge.…”

Section: Resultsmentioning

confidence: 99%

Development of a High-Performance Drilling Fluid Additive for Application in Indian Shale Gas Formations

et al. 2023

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With increasing energy demand, it has become pertinent to develop high-performing drilling fluids and additives with environmental compatibility for troublesome shale gas formations. In this research work, carboxymethyl chitosan (CM-CS) was synthesized using carboxymethylation reactions and characterized using advanced analytical techniques. The synthesized CM-CS was used as an additive in a water-based drilling fluid system comprising clay, carboxymethyl cellulose, polyanionic cellulose, and xanthan gum. The experimental investigation results of the drilling fluid properties, including the filtration and rheological tests, showed improvement compared with poly-(ethylene glycol) (PEG), a conventional shale inhibitor. At 0.3, 0.6, and 0.9 (w/v%) CM-CS, the filtrate loss was reduced by 38.75, 50, and 53.12% in comparison to the base fluid. Other tests included ζ-potential and shale recovery tests. The ζ-potential was used to determine the suspension stability of the drilling fluid. Shale recovery tests were conducted to assess the effectiveness of the fluid to address the wellbore instability issues for the chosen shale samples. The primary shale recovery percentages of CM-CS and PEG in drilling fluids were compared. Results show that the primary recovery factors increased by 32.42, 33.81, and 34.12 (wt%) when 0.3, 0.6, and 0.9 (w/v%) CM-CS was used as an additive. CM-CS shows minimum interaction of the fluid with the Indian shale samples based on shale recovery tests and filtration studies, which suggests that it can be better suited for the drilling fluid application in troublesome shale gas formation.

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“…This rate inhibition could be explained by the presence of external ions (Wicks and Groves, 1993). At field sites, the adsorbed PAM also remains in the fracture network, thus decreasing the permeability of shale and posing an adverse impact on gas production (Grattoni et al, 2004;Carman and Cawiezel;Koteeswaran et al, 2017;Sun et al, 2017;Guo et al, 2018). Hence, PAM polymer not only retards calcite dissolution and pore generation (as discussed in section 3.2), but it also causes formation damage (decreased permeability).…”

Section: Discussionmentioning

confidence: 99%

Effect of polyacrylamide friction reducer on calcite dissolution rate at 25 °C and implication for hydraulic fracturing

Walkinshaw

Belshaw

et al. 2021

Journal of Natural Gas Science and Engineering

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Hydraulic fracturing is widely used to create cracks and increase the size and connectivity of existing fractures, leading to higher permeability of shale rocks and production of unconventional hydrocarbon sources. The main chemicals used in hydraulic fracturing fluids can initiate fractures in shale reservoirs by acid induced carbonate dissolution, and minimise energy loss during the pumping process by friction reducer enhanced fluid viscosity. Here, using batch reactor experiments we investigate the effect of non-ionic polyacrylamide polymer (friction reducer) on the dissolution rate of calcite in acidic solutions (0.2 M buffer solution of sodium acetate/acetic acid) at 25 °C. The results demonstrate that polyacrylamide (from 0 to 30 mg) slows down the dissolution rate by a factor of 4. Hydrogen bonding and surface complexation between non-ionic polyacrylamide and calcite potentially trigger an adsorption mechanism that protects calcite from dissolving.This research provides new insights into friction reducer (polyacrylamide) influenced pore generation, enabling engineers to optimise the fracturing fluid design (amount of polyacrylamide) and to consider suitable actions to prevent the polymer from having a negative impact on productivity.

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Quantitative characterization of polyacrylamide–shale interaction under various saline conditions

Cited by 17 publications

References 46 publications

Cationic starch derivatives as reactive shale inhibitors for water‐based drilling fluids

Cationic starch derivatives as reactive shale inhibitors for water‐based drilling fluids

Development of a High-Performance Drilling Fluid Additive for Application in Indian Shale Gas Formations

Effect of polyacrylamide friction reducer on calcite dissolution rate at 25 °C and implication for hydraulic fracturing

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