Effect of surfactant composition on reservoir wettability and scale inhibitor squeeze lifetime in oil wet carbonate reservoir

Ghosh, Bisweswar; Li, Xin

doi:10.1016/j.petrol.2013.04.012

Cited by 17 publications

(4 citation statements)

References 20 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…Scale-inhibitor (SI) squeeze treatments are recognized to be one of the most economically and technically favorable options for scale management in both conventional and subsea oil fields. − Squeeze treatments commonly consist of injecting a scale inhibitor, usually by “bullhead” injection, into the near wellbore area followed by an overflush brine, which displaces the SI deeper into the formation. After a shut-in period to allow the chemical to adequately “retain” in the formation rock, the well is put back on production. − The efficiency and lifetime of the squeeze treatment depends on the interaction of the SI with the rock minerals in the porous medium. − Scale inhibitors are retained within porous media by the two main mechanisms of adsorption (Γ) and precipitation (Π) as shown schematically in Figure .…”

Section: Introductionmentioning

confidence: 99%

Experimental Investigation of the Interaction between a Phosphate Ester Scale Inhibitor and Carbonate Rocks for Application in Squeeze Treatments

et al. 2019

View full text Add to dashboard Cite

Studying the interaction between scale inhibitors (SIs) and chemically reactive carbonate minerals is crucial for determining SI retention in “squeeze” treatments. This study investigated the retention of the environmentally friendly SI, polyhydric alcohol phosphate ester (PAPE), on calcite and dolomite substrates. Elemental analysis of the supernatant solution as well as pH measurement and environmental scanning electron microscopy (ESEM) with energy dispersive X-ray analysis (EDX) were all used to investigate SI retention and to identify the morphology/composition of the resultant SI–Ca precipitates. Results revealed that PAPE was retained by calcite via pure adsorption at an initial test pH (pH0) of 4 and then precipitated at pH0 6. In contrast, the PAPE/dolomite system was found to be effectively pH-independent, with precipitation dominating at both pH0 values. Any temperature effect was negligible for dolomite/PAPE retention, whereas with calcite, retention was smaller at lower temperature, which is attributed to the temperature-dependence of the substrate solubility. Overall, the final pH of the system and the resulting degree of SI dissociation contributed more to PAPE retention than did the final calcium concentration. EDX analysis confirmed scale-inhibitor phosphorus in the deposited solids, indicating coupled adsorption/precipitation. This phosphorus increased with the amount of precipitation and with the temperature, confirming the corresponding static adsorption test results.

show abstract

Section: Introductionmentioning

confidence: 99%

Experimental Investigation of the Interaction between a Phosphate Ester Scale Inhibitor and Carbonate Rocks for Application in Squeeze Treatments

et al. 2019

View full text Add to dashboard Cite

show abstract

“…Several technologies have been developed to increase scale inhibitor retention on a rock formation at reduced water volume to reduce hydrostatic head pressure and to improve the wettability of the rock for inhibitor attachment. Ghosh et al tested an anionic surfactant and an alkaline base in the preflush solution to effectively clean the oil-wet formation rock and improve aqueous inhibitor retention during squeeze (Ghosh and Li 2013;Ghosh et al 2016).…”

Section: Non-aqueous Scale Treatmentmentioning

confidence: 99%

The state of the art in scale inhibitor squeeze treatment

2020

View full text Add to dashboard Cite

The mechanistic understanding of the reactions that govern the inhibitor retention and release, modeling, and the state-ofthe-art innovation in squeeze treatment are reviewed. The retention and release are governed by (1) the amount of calcite that can dissolve prior to inhibitor-induced surface poisoning; (2) calcite surface poisoning after ~ 20 molecular layers of surface coverage by the adsorbed inhibitors to retard further calcite dissolution; (3) less base, CO 2− 3 , is released into the aqueous solution; (4) formation of the more acidic inhibitor precipitates; (5) phase transformation and maturation of the more acidic inhibitor precipitates; and (6) dissolution of the less soluble crystalline inhibitor precipitates. The trend to advance squeeze technologies is through (1) enhancing scale inhibitor retention, (2) optimizing the delivery of scale inhibitors to the target zone, and (3) improving monitoring methods. Lastly, a prototype yardstick for measuring the squeeze performance is used to compare the squeeze life of 17 actual squeeze treatments. Even though the various squeeze treatments appear to be different, all published squeeze durations can be rated based on the normalized squeeze life per unit mass of inhibitors.

show abstract

“…Furthermore, the wellbore clean-up is another crucial challenge, and the current research indicates that the clean-up solutions composed of a wide range of components such as strong acids, weak acids, enzymes, chelating agents, and oxidizers are used. , The ability of the clean-up solution to remove the deposited filter cake varies significantly based on its content. Strong acids such as hydrochloric and hydrofluoric acids tend to react with downhole equipment and tubulars, causing severe corrosion, and often result in non-uniform clean-up because of the formation of wormholes.…”

Section: Introductionmentioning

confidence: 99%

Development of Hybrid Drilling Fluid and Enzyme–Acid Precursor-Based Clean-Up Fluid for Wells Drilled with Calcium Carbonate-Based Drilling Fluids

et al. 2020

Self Cite

View full text Add to dashboard Cite

Significant formation damage can occur during drilling operations because of the invasion of drilling fluid fines and filtrates that lead to pore blocking and saturation alteration mechanisms. This study demonstrates the ways to minimize drilling fluid-related damage and the removal of the deposited filter cake in the carbonate reservoir through judicious selection of bridging particles using “ideal packing theory” and formulation of an enzyme-based clean-up fluid with an acid precursor. The polymer-based drill-in-fluid with a mixed grade of CaCO 3 bridging particles resulted in a compact filter cake with reduced filtration loss preventing internal pore damage significantly. Several ester hydrolysis reaction kinetics were studied, and finally, one combination was chosen as the suitable acid precursor because of its ability to generate a required concentration of acid within the downhole condition. The return permeability of mud-damaged carbonate core plugs was higher than 95% after exposure to the clean-up solution. The corrosion rates were found to be significantly below the industry limits, and the use of acid corrosion inhibitors is eliminated.

show abstract

Effect of surfactant composition on reservoir wettability and scale inhibitor squeeze lifetime in oil wet carbonate reservoir

Cited by 17 publications

References 20 publications

Experimental Investigation of the Interaction between a Phosphate Ester Scale Inhibitor and Carbonate Rocks for Application in Squeeze Treatments

Experimental Investigation of the Interaction between a Phosphate Ester Scale Inhibitor and Carbonate Rocks for Application in Squeeze Treatments

The state of the art in scale inhibitor squeeze treatment

Development of Hybrid Drilling Fluid and Enzyme–Acid Precursor-Based Clean-Up Fluid for Wells Drilled with Calcium Carbonate-Based Drilling Fluids

Contact Info

Product

Resources

About