Design and Application of High-Temperature Raw-Seawater-Based Fracturing Fluids

Almubarak, Tariq; AlKhaldi, Mohammed; Ng, Jun Hong; Nasr‐El‐Din, Hisham A.

doi:10.2118/195597-pa

Cited by 29 publications

(23 citation statements)

References 19 publications

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“…Also, diammonium EDTA and sodium gluconate formed complexes, with the borate ion preventing the cross-linking from taking place. Almubarak et al 160 also investigated the possibility of using seawater for hydraulic fracturing, instead of fresh water. The study suggested using polyphosphates and organophosphorus as scale inhibitors, where they act as chelating agents.…”

Section: Chelating Agents As Hydraulic Fracturingmentioning

confidence: 99%

Applications of Chelating Agents in the Upstream Oil and Gas Industry: A Review

et al. 2020

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Chelating agents show very effective performance in different applications in the upstream oil and gas industry. This study presents a critical review of the application of chelating agents in acidizing, scale removal, filter cake removal, wettability alteration, enhanced oil recovery (EOR), and hydraulic fracturing treatments. The advantages and disadvantages of using several types of chelating agents for improving the well/reservoir productivity and enhancing the oil recovery from sandstone and carbonate reservoirs are discussed. Also, detailed comparisons between different chelating agents and their applications in many oil and gas areas are presented. Moreover, the combination of chelating agents with different chemicals to achieve better performance is addressed. Hydroxy amino carboxylic acids [such as ethylenediaminetetraacetic acid (EDTA) and glutamic acid diacetic acid (GLDA)] have replaced conventional acids, such as hydrochloric acid (HCl), hydrofluoric acid (HF), and organic acids, at high temperature and salinity conditions to stimulate carbonate and sandstone reservoirs without any side effects on the formation integrity. Furthermore, diethylenetriaminepentaacetic acid (DTPA) and GLDA are effective in removing different types of scales, such as carbonate, sulfate, and sulfides, without releasing hydrogen sulfide (H 2 S) and using corrosion inhibitors. Also, DTPA, EDTA, and GLDA are very active in dissolving filter cake layers formed by different drilling fluids. Aminopolycarboxylic groups can be injected into sandstone and carbonate reservoirs to adjust the wettability conditions and enhance oil recovery. Chelating agents, such as GLDA, EDTA, and DTPA, optimize the fracture conductivity and, meanwhile, minimize the number of additives in hydraulic fracturing, which significantly cut the cost of the operation. Overall, chelating agents are economically attractive chemicals for various upstream operations since produced, and seawater can be used without further treatment.

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Section: Chelating Agents As Hydraulic Fracturingmentioning

confidence: 99%

Applications of Chelating Agents in the Upstream Oil and Gas Industry: A Review

et al. 2020

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“…Another test with sodium sulfate as the brine was conducted to test the effect of sulfate ions on the foam decay. Sulfate ions are commonly available in seawater brines [29]. The presence of sulfate ions was detrimental to foam stability.…”

Section: Hpvc Foam Testsmentioning

confidence: 99%

Insights into CO2 Foaming Behavior of Ethoxylated Amines

Ramanathan

Almubarak

et al. 2021

Energies

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Switchable ethoxylated amine surfactants are readily soluble in CO2 and high-saline brines. The objective of the current work is to maximize the foamability and stability of CO2 foam at 150 °F (65 °C) through adjustments in the surfactant concentration, pH, and brine salinity. From the results, the authors recommend potential applications of Ethomeen C12 (EC12) for CO2 foam in the oil/gas industry. Foam stability tests helped determine the optimum parameters for CO2 foam stability at 77 °F (25 °C) and 150 °F (65 °C). The surface tension of EC12 as a function of concentration was evaluated using a drop-shape analyzer. Maximum foam stability was observed for a solution comprising of 1.5 wt% EC12, 25 wt% NaCl, and pH 6.5 at 150 °F (65 °C). The interactions with the salts allowed closer packing of the surfactant molecules at the lamellae and strengthening the foam. At a pH of 2.5, the absence of salt led to poor foam stability. However, at the same pH and in the presence of sodium chloride, the foam was stable for longer periods of time due to the salt influence. The surface tension gradients had a direct relationship to foam stability. There was a strong resistance to foam degradation when multivalent ions were present with the surfactant.

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“…HEDTA and EDTA were used as additives for produced and seawater fracturing fluids. Compatible chelating/water solutions were achieved at a salinity level of 101 000 ppm, and reasonable fluid viscosity was generated at 180 °F and 100 s –1 shear rate. − …”

Section: Introductionmentioning

confidence: 99%

Chelating Agents as Acid-Fracturing Fluids: Experimental and Modeling Studies

et al. 2021

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Acid-fracturing operations are applied to improve the productivity of carbonate reservoirs by creating rough fracture surfaces that remain conductive for reservoir fluids after the fracture closure. Different acid types have been used over the history of acid fracturing, including weak organic and strong HCl acids. Organic acids have low dissolving power, generating low fracture conductivity, while HCl acid is corrosive and requires numerous additives. For the first time, this study investigates the performance of the chelating agents, namely, ethylenediaminetetraacetic acid (EDTA) and glutamic acid N,N-diacetic acid (GLDA), in creating sufficient fracture conductivity. Several experiments/measurements were performed, such as coreflooding, fracture conductivity, computed tomography scan imaging, fracture face permeability, scratch test strength, impulse hammer hardness, inductively coupled plasma analysis of effluents, and nuclear magnetic resonance (NMR). The lab-scale outcomes were reproduced numerically, and field-scale simulations were carried. EDTA and GLDA treatments resulted in comparable fracture conductivity outcomes to the HCl acid treatment. However, they were associated with less rock strength reduction, which is essential for long-term sustainable fracture conductivity. The connectivity of the fracture and rock matrix was improved, as concluded from the NMR measurements. The study recommends injecting chelating agents in different cycles separated with soaking periods if higher dissolution/conductivity is desirable. Field-scale simulations showed that EDTA and GLDA chelating agents would result in lower dissolution magnitudes compared to HCl acid. Nevertheless, they could etch 60−70% of the created fracture length compared to 20% etched length created by HCl acid.

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Design and Application of High-Temperature Raw-Seawater-Based Fracturing Fluids

Cited by 29 publications

References 19 publications

Applications of Chelating Agents in the Upstream Oil and Gas Industry: A Review

Applications of Chelating Agents in the Upstream Oil and Gas Industry: A Review

Insights into CO2 Foaming Behavior of Ethoxylated Amines

Chelating Agents as Acid-Fracturing Fluids: Experimental and Modeling Studies

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