Synthetic polymers: A review of applications in drilling fluids

Davoodi, Shadfar; Al-Shargabi, Mohammed; Wood, David A.; Rukavishnikov, Valeriy S.; Minaev, Konstantin M.

doi:10.1016/j.petsci.2023.08.015

Cited by 21 publications

(10 citation statements)

References 178 publications

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“…Another assessment of the most used polymer, xanthan gum (XG), by Alves et al (2019) on the XG influence on flow properties of a water-based drilling fluid shows XG increasing content (0.15% to 0.55%) rise in the plastic viscosity and yield point by 28% and 40%, respectfully . Such observations about fluid loss control and rheological improvement by several research studies − have increased the global drilling polymer industry, which is currently reporting a global market forecast of USD 2,705.4 million by 2030…”

Section: Introductionmentioning

confidence: 99%

RETRACTED: On Improving Water-Based Drilling Mud Swelling Control Using Modified Poly(Vinyl Alcohol)s

Poungui,

Sugai,

Nguele

et al. 2024

ACS Omega

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One of the most challenging issues when drilling under high-temperature, high-pressure (HT/HP) conditions is wellbore instability caused by clay swelling and fluid loss of the drilling mud. One of the most difficult issues when drilling under high-temperature, high-pressure (HT/HP) conditions is wellbore instability caused by clay swelling and fluid loss in drilling mud. Two modified PVOHs, nonionic and cationic polymers made from sodium bentonite clay and deionized water at concentrations of 0.08, 0.28, and 0.49 wt.%, were introduced to WBM percent. A series of specific gravity and mud rheology experiments at 25, 55, and 85 °C indicated that both values drop monotonically with increasing temperature, regardless of PVOH addition or concentration. A temperature increase of 30 °C decreases the mud viscosity of WBM (without PVOH) by 18% from its starting value, on average. Only 0.1% of cationic and nonionic polymer reduces viscosity by 10% and 0%, respectively. Experimenting with mud samples for 5 h revealed that adding nonionic polymers enhances mud filtration by up to 34.7%, 1.25 times more than that achieved from cationic polymers under the same filtration circumstances. Increasing the filtration temperature moderately affects mud cake generation due to increased mud swelling index and preferential adsorption by nonionic polymer. The latter observation was corroborated by determining the polymer content of the filtrates. Therefore, it was shown that nonionic polymers adsorbed more (118.9 mg/g) than cationic polymers (84.51 mg/g). Increased filtration temperature moderately affects mud cake generation due to increased mud swelling index and preferential adsorption by nonionic polymer. The latter observation was corroborated by testing the filtrates for the polymer content. As a result, it was discovered that nonionic polymer adsorbed more (118.9 mg/g) than cationic polymer (84.51 mg/g). Thermogravimetry analysis (TGA) finally tested the thermal stability of polymers.

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Section: Introductionmentioning

confidence: 99%

RETRACTED: On Improving Water-Based Drilling Mud Swelling Control Using Modified Poly(Vinyl Alcohol)s

Poungui,

Sugai,

Nguele

et al. 2024

ACS Omega

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“…Drilling uids oen display non-Newtonian behavior due to factors like clay particles and electric charges on clay surfaces, causing viscosity to change with shear rate. 8,35 The Bingham plastic, power law, and Herschel-Bulkley models are employed to predict the rheological behavior of drilling uid, as outlined below:…”

Section: Performance Evaluationmentioning

confidence: 99%

“…Consequently, rheology modiers and uid loss additives such as surfactants, polymers, and nanoparticles were incorporated into the formulation to improve the rheological properties and minimize the uid loss to the formation. 7,8 Polyethyleneimine (PEI) is categorized as a cationic polymer, indicating its positivity is derived from the inclusion of amino groups (-NH 2 ) within its polymer chain, rendering it cationic in nature. This property, stemming from the amino groups, further underlined the feasibility of employing positively charged polymers as drilling uid's additive within high-temperature reservoirs.…”

Section: Introductionmentioning

confidence: 99%

An experimental investigation into the rheological behavior and filtration loss properties of water-based drilling fluid enhanced with a polyethyleneimine-grafted graphene oxide nanocomposite

Abdullah,

Ridha,

Mohshim

et al. 2024

RSC Adv.

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“…One of the major disadvantages of OBDFs is their potential environmental impact The use of OBDFs can lead to the release of hydrocarbons into the environment, posing a risk to aquatic life and ecosystems 13 . Also, OBDFs are generally more expensive than WBDFs due to the higher cost of the base oil and the need for additional additives to achieve the desired performance 14 – 16 . Moreover, if circulation losses occur during drilling, it can be challenging to stop the losses with OBDFs.…”

Section: Introductionmentioning

confidence: 99%

Investigating the efficacy of novel organoclay as a rheological additive for enhancing the performance of oil-based drilling fluids

Mahmoud,

Gajbhiye,

Elkatatny

2024

Sci Rep

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Oil-based drilling fluids (OBDFs) are extensively used in the drilling industry due to their superior performance in challenging drilling conditions. These fluids control wellbore stability, lubricate the drill bit, and transport drill cuttings to the surface. One important component of oil-based drilling fluids is the viscosifier, which provides rheological properties to enhance drilling operations. This study evaluates the effectiveness of Claytone-IMG 400, a novel rheological agent, in enhancing the performance of OBDFs under high-pressure and high-temperature (HPHT) conditions. A comparative analysis was conducted with a pre-existing organoclay (OC) to assess the improvements achieved by Claytone-IMG 400. The OCs were analyzed using X-ray diffraction (XRD), X-ray fluorescence (XRF), scanning electron microscopy (SEM), and particle size distribution (PSD) to identify their mineral and chemical compositions, morphologies, and particle sizes. The drilling fluid density, electrical stability, sagging tendency, rheological properties, viscoelastic properties, and filtration properties were studied to formulate a stable and high-performance drilling fluid. The results confirmed that the novel OC does not affect the drilling fluid density but enhances the emulsion stability with a 9% increment compared with the drilling fluid formulated with MC-TONE. The sagging experiments showed that Claytone-IMG 400 prevented the sagging issues in both static and dynamic conditions. Also, Claytone-IMG 400 improved the plastic viscosity (PV), yield point (YP), and apparent viscosity (AV). The PV, YP, and AV were improved by 30%, 38%, and 33% increments respectively compared with the drilling fluid formulated with MC-TONE. The YP/PV ratio increased with a 6% increment from 1.12 to 1.19. Moreover, the gel strength (GS) was significantly increased, and the filtration properties were enhanced. The filtration volume was reduced by 10% from 5.0 to 4.5 cm3, and the filter cake thickness had a 37.5% reduction from 2.60 to 1.89 mm. The novelty of this study is highlighted by the introduction and evaluation of Claytone-IMG 400 as a new rheological additive for safe, efficient, and cost-effective drilling operations. The results indicate that Claytone-IMG 400 significantly improves the stability and performance of OBDFs, thereby reducing wellbore instability and drilling-related problems.

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Synthetic polymers: A review of applications in drilling fluids

Cited by 21 publications

References 178 publications

RETRACTED: On Improving Water-Based Drilling Mud Swelling Control Using Modified Poly(Vinyl Alcohol)s

RETRACTED: On Improving Water-Based Drilling Mud Swelling Control Using Modified Poly(Vinyl Alcohol)s

An experimental investigation into the rheological behavior and filtration loss properties of water-based drilling fluid enhanced with a polyethyleneimine-grafted graphene oxide nanocomposite

Investigating the efficacy of novel organoclay as a rheological additive for enhancing the performance of oil-based drilling fluids

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