Rheological study of CO2 foamed chelating stimulation fluids under harsh reservoir conditions

Kadafur, Ibrahim; BinGhanim, Ahmed; Aljawad, Murtada Saleh; Kamal, Muhammad Shahzad; AlYousef, Zuhair

doi:10.1016/j.petrol.2021.109201

Cited by 11 publications

(7 citation statements)

References 29 publications

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“…Under the high salinity and high temperature conditions that are observed in most reservoirs, most polymers and surfactants break down . Chelating agents are introduced as unconventional fluids to address these breakdown issues because of their distinct properties, low costs, and eco-friendliness. ,− During chelation, ions and molecules are chemically bonded to metal ions. To form a chelating agent, two or more different coordinate bonds must be developed between a central atom and a ligand with multiple bonds.…”

Section: Chelating Agents Effects On Seawater Fluidmentioning

confidence: 99%

“…GLDA is environmentally friendly and more resistant to high temperatures and salinity. ,, Additionally, it has the ability to increase the viscosity of the stimulation fluid. An environmentally friendly stimulation fluid has been developed by adding GLDA to polymeric gel solutions .…”

Section: Chelating Agents Effects On Seawater Fluidmentioning

confidence: 99%

“…In this experiment, GLDA increased the gel solution’s stability and viscosity. At a low shear rate (100–500 s –1 ), the addition of 15 wt % GLDA was able to raise the foam viscosity by 15 cP …”

Section: Chelating Agents Effects On Seawater Fluidmentioning

confidence: 99%

“…At a low shear rate (100−500 s −1 ), the addition of 15 wt % GLDA was able to raise the foam viscosity by 15 cP. 65 Chelating chemicals have been recommended to be added to fracturing fluids in order to improve the consistency of excessively saline fracturing fluids. 71 This technique produces fracturing fluids with greater stability.…”

Section: With Seawater Fluidmentioning

confidence: 99%

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Seawater-Based Fracturing Fluid: A Review

Budiman,

Alajmei

2023

ACS Omega

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Hydraulic fracturing uses a large amount of fresh water for its operation; conventional wells can consume up to 200 000 gallons of water, while unconventional wells could consume up to 16 million gallons. However, the world's fresh water supply is rapidly depleting, making this a critical and growing problem. Freshwater shortages during large-scale hydraulic fracturing in regions that lack water, such as the Arabian Peninsula and offshore operations, need to be addressed. One of the ways to address this problem is to substitute fresh water with seawater, which is a sustainable, cheap, and technically sufficient fluid that can be utilized as a fracturing fluid. However, its high salinity caused by the multitude of ions in it could induce several problems, such as scaling and precipitation. This, in turn, could potentially affect the viscosity and rheology of the fluid. There are a variety of additives that can be used to lessen the effects of the various ions found in seawater. This review explains the mechanisms of different additives (e.g., polymers, surfactants, chelating agents, cross-linkers, scale inhibitors, gel stabilizers, and foams), how they interact with seawater, and the related implications in order to address the above challenges and develop a sustainable and compatible seawater-based fracturing fluid. This review also describes several previous technologies and works that have treated seawater in order to produce a fluid that is stable at higher temperatures, that has a considerably reduced scaling propensity, and that has utilized a stable polymer network to efficiently carry proppant downhole. In addition, some of these previous works included field testing to evaluate the performance of the seawater-based fracturing fluid.

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Section: Chelating Agents Effects On Seawater Fluidmentioning

confidence: 99%

Section: Chelating Agents Effects On Seawater Fluidmentioning

confidence: 99%

Section: Chelating Agents Effects On Seawater Fluidmentioning

confidence: 99%

Section: With Seawater Fluidmentioning

confidence: 99%

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Seawater-Based Fracturing Fluid: A Review

Budiman,

Alajmei

2023

ACS Omega

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“…Li et al (2022) investigated the rheology properties of thickened liquid CO 2 by measuring the viscosity of thickened liquid CO 2 in different physical parameters of this prepared thickener and explained the causes of the rheological changes [ 29 ]. Kadafur et al (2022) investigated the rheology of a CO 2 foamed chelating agent, L-glutamic acid-N, N-diacetic acid (GLDA), which was conducted at 100 C, 1000 psi, 3.5 pH level, and various water salinities, resembling harsh reservoir conditions [ 30 ]. Tariq et al (2022) established a data pool, which was analyzed using four machine learning techniques: Artificial Neural Network (ANN), Decision Trees (DT), Random Forest Regressor (RFR), and K-Nearest Neighbor (KNN), and it provides a simplified ANN-based model which can be used on the fly to predict the effective bulk foam viscosity in both laboratory and field conditions [ 31 ].…”

Section: Introductionmentioning

confidence: 99%

Experimental Evaluation of the Rheological Properties and Influencing Factors of Gel Fracturing Fluid Mixed with CO2 for Shale Gas Reservoir Stimulation

Wang

Wu²,

Chen

et al. 2022

Gels

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Foam gel fracturing fluid has the characteristics of low formation damage, strong flowback ability, low fluid loss, high fluid efficiency, proper viscosity, and strong sand-carrying capacity, and it occupies a very important position in fracturing fluid systems. The rheological properties of gel fracturing fluid with different foam qualities of CO2, under different experimental temperatures and pressures, have not been thoroughly investigated, and their influence on it was studied. To simulate the performance of CO2 foam gel fracturing fluid under field operation conditions, the formula of the gel fracturing fluid was obtained through experimental optimization in this paper, and the experimental results show that the viscosity of gel fracturing fluid is 2.5 mPa·s (after gel breaking at a shear rate of 500 s−1), the residue content is 1.3 mg/L, the surface tension is 25.1 mN/m, and the interfacial tension is 1.6 mN/m. The sand-carrying fluid has no settlement in 3 h with a 40% sand ratio of 40–70-mesh quartz sand. The core damage rate of foam gel fracturing fluid is less than 19%, the shear time is 90 min at 170 s−1 and 90 °C, the viscosity of fracturing fluid is >50 mPa·s, and the temperature resistance and shear resistance are excellent. The gel fracturing fluid that was optimized was selected as the base fluid, which was mixed with liquid CO2 to form the CO2 foam fracturing fluid. This paper studied the rheological properties of CO2 foam gel fracturing fluid with different CO2 foam qualities under high temperature (65 °C) and high pressure (30 MPa) and two states of supercooled liquid (unfoamed) and supercritical state (foamed) through indoor pipe flow experiments. The effects of temperature, pressure, shear rate, foam quality, and other factors on the rheological properties of CO2 foam gel fracturing fluid were considered, and it was confirmed that among all the factors, foam quality and temperature are the main influencing factors, which is of great significance for us to better understand and evaluate the flow characteristics of CO2 foam gel fracturing fluid and the design of shale gas reservoir fracturing operations.

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Review of underbalanced drilling techniques highlighting the advancement of foamed drilling fluids

Al-Darweesh

Aljawad

Ramadan

et al. 2022

J Petrol Explor Prod Technol

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Overbalanced drilling is the most common drilling technique; nevertheless, it has several disadvantages such as formation damage, mud losses, and stuck pipes; challenges that are common in high permeability zones and highly fractured formations. To overcome those issues, the underbalanced drilling method could be implemented. The underbalanced drilling (UBD) technique is widely utilized in hard, under pressure, depleted, and fractured/vuggy formations. Low-density drilling fluids are usually used in UBD operations and could be categorized into a gas (i.e., air, nitrogen, and natural gas) or two-phase (i.e., mist and foam). Although foamed fluid attracted attention in enhanced oil recovery and hydraulic fracturing operations, it is ideal for UBD operations due to its low density and efficient transport capacity. This paper highlights the applications, limitations, advantages, and disadvantages of UBD operations. It also discusses the drilling foam chemistry, structure, characterization, and rheological properties. Finally, this paper highlights a few successful UBD operations utilizing foamed drilling fluids worldwide.

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Rheological study of CO2 foamed chelating stimulation fluids under harsh reservoir conditions

Cited by 11 publications

References 29 publications

Seawater-Based Fracturing Fluid: A Review

Seawater-Based Fracturing Fluid: A Review

Experimental Evaluation of the Rheological Properties and Influencing Factors of Gel Fracturing Fluid Mixed with CO2 for Shale Gas Reservoir Stimulation

Review of underbalanced drilling techniques highlighting the advancement of foamed drilling fluids

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