The Impairment of Scale Inhibitor Function by Commonly Used Organic Anions

Barthorpe, R.T.

doi:10.2118/25158-ms

Cited by 9 publications

(5 citation statements)

References 3 publications

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“…Hydroxylamine hydrochloride is used to keep iron ions in ferrous state. The reduction reaction is expressed in equation (1) and (2) (Bengtsson et al, 2002).…”

Section: Maintenance Of Anoxic Conditionmentioning

confidence: 99%

“…in 1993. It was found that chelating agents like EDTA and citric acid can render some commonly used scale inhibitors (phosphonates, polycarboxylates and phosphate esters) completely ineffective at concentrations as low as 0.1 mg/l and the effect is maximized at pH 4.0 and 6.0 (Barthorpe et al, 1993). But why the addition of citric acid is found effective in reversing the Fe 3ϩ detrimental effect on DTPMP is not clear.…”

Section: Spe-173770-msmentioning

confidence: 99%

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Ferrous Iron Impact on Phosphonate and Polymeric Scale Inhibitors at Temperature Ranging from 25 to 70°C

Zhang

Wang

et al. 2015

Day 1 Mon, April 13, 2015

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Ferrous iron (Fe 2ϩ ) is one of the most common cations existing in oil and gas production water. Most Fe 2ϩ ions come from dissolution of siderite in reservoir and corrosion of steel pipes. Compared to Ca 2ϩ and Mg 2ϩ , Fe 2ϩ has a higher complex stability constant with some common inhibitor function groups like phosphonate and carboxyl due to its transition metal structure. Therefore, understanding the influence of Fe 2ϩ on inhibitors is important to enhance inhibition performance. Work still remain to be done to understand the effect of Fe 2ϩ on scale inhibition, including a systematic study of the Fe 2ϩ influence on phosphonate and polymeric scale inhibitors at different pH, values and molar ratios. Little research has been done at temperatures above room temperature, probably due to the difficulty of developing strictly anoxic test apparatus. In this study, a new anoxic laser apparatus is designed to test inhibitor performance. This newly designed apparatus features constant Argon gas headspace purging during an experiment to guarantee a strict maintenance of anoxic condition. This anoxic apparatus is based on laser detection method of nucleation induction time. It is easy to operate and enables experiments to be conducted at temperatures up to 200°F.

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“…Hydroxylamine hydrochloride is used to keep iron ions in ferrous state. The reduction reaction is expressed in equation (1) and (2) (Bengtsson et al, 2002).…”

Section: Maintenance Of Anoxic Conditionmentioning

confidence: 99%

Section: Spe-173770-msmentioning

confidence: 99%

Ferrous Iron Impact on Phosphonate and Polymeric Scale Inhibitors at Temperature Ranging from 25 to 70°C

Zhang

Wang

et al. 2015

Day 1 Mon, April 13, 2015

View full text Add to dashboard Cite

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“…Trace amounts of chelating agents, such as EDTA, citric acid, or gluconic acid, may lower the efficiency of scale inhibitors [65]. The concentration of calcium ions and magnesium ions affects the inhibition of barium sulfate [66].…”

Section: Chelating Agentsmentioning

confidence: 99%

Scale inhibitors

2015

Petroleum Engineer's Guide to Oil Field Chemicals and Fluids

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In certain operations in petroleum industries, such as production, stimulation, and transport, there is some risk of scale deposition. Scaling can occur when a solution becomes supersaturated, which occurs mostly if the temperature changes in the course of injection operations.Also, if two chemicals that will form a precipitate are brought together, a scale is formed, for example, if a hydrogen fluoride solution meets calcium ions. From a thermodynamic perspective, there is a stable region, a metastable region, and an unstable region, which are separated by the binodal curve and the spinodale curve, respectively.Scales may consist of calcium carbonate, barium sulfate, gypsum, strontium sulfate, iron carbonate, iron oxides, iron sulfides, and magnesium salts [1]. In the literature some monographs, for example, Corrosion and Scale Handbook [2], as well as reviews [3] on scale depositions are available. Case studies have been presented for North Sea carbonate reservoirs [4, 5] and Gulf of Mexico [6]. A more recent work focuses on green systems [7]. SCALE PREDICTIONAn overview of scale prediction and control has been presented [8]. The challenges of scale prediction at high temperature, high pressure, and high total dissolved solids and an accurate model to predict pH, scale indices, density, and inhibitor needs at these conditions have been discussed and reviewed. CLASSIFICATION AND MECHANISMThe problem is basically similar to preventing scale inhibition in washing machines. Therefore similar chemicals are used to prevent scale deposition. Scale inhibition can be achieved either by adding substances that react with potential scale forming substances so that from the view of thermodynamics the stable region is reached or by adding substances that suppress crystal growth.Petroleum Engineer's Guide to Oil Field Chemicals and Fluids. http://dx.

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“…The only scale inhibitors studied that remained unaffected by these interferences were poly(vinyl sulfonate)s [151]. The scale inhibitor concentrations studied were 50 and 100 mg l −1 .…”

Section: Interference Of Chelate Formersmentioning

confidence: 99%

Fracturing fluids

2015

Petroleum Engineer's Guide to Oil Field Chemicals and Fluids

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Hydraulic fracturing is a technique to stimulate the productivity of a well. A hydraulic fracture is a superimposed structure that remains undisturbed outside the fracture. Thus the effective permeability of a reservoir remains unchanged by this process. The increased productivity results from the increased wellbore radius, because in the course of hydraulic fracturing, a large contact surface between the well and the reservoir is created.The literature from 2004 to 2014, more than 100 references concerning waterbased fracturing fluids for fracturing ultralow-to moderate-permeability reservoirs has been reviewed [1].Guar-based polymers are still used in fracturing at temperatures less than 150 • C. To minimize the damage associated with this class of polymers, several approaches are known. These include the use of a lower polymer concentration in formulating these fluids and the use of different crosslinking agents. Higher viscosities with lower polymer loadings can be achieved. In addition, cleaner guar-based polymers are used now, because commercial guar contains some 5% of residues, which may cause a damage of proppant packs.It has been found that shear and pressure effects on the rheological behavior of borate crosslinked gels are important. Although these fluids recover their viscosity after shear, they have been observed to lose a significant portion of their viscosity under high pressures.When fracturing is done in deeper wells, i.e., in hotter reservoirs, a new class of thermally stable polymers became relevant. These are poly(acrylamide)-based polymers. These synthetic polymers show a sufficient viscosity at temperatures up to 230 • C [1]. Examples are 2-acrylamido-2-methylpropanesulfonic acid and copolymers of partially hydrolyzed acrylamide, 2-acrylamido-2-methylpropanesulfonic acid, and vinyl phosphonate. High-density brines have been used to increase the hydrostatic pressure by 30% for high-pressure pumping.Also, new breaker materials emerged [1]. These breakers destroy the gel by a reaction with the crosslinking agent. They form ligands with the metallic crosslinking agents and displace them from the crosslinking moieties of the guar-based polymers. Examples of these breakers include poly(succinimide) derivates and lignosulfonate derivates.To minimize the environmental impact of using massive amounts of fresh water and to minimize costs associated with treating produced water, the use of produced water in hydraulic fracturing treatments has been reported. Petroleum Engineer's Guide to Oil Field Chemicals and Fluids. http://dx.567 568 CHAPTER 17 Fracturing fluids B HO 17.3 Types of hydraulic fracturing fluids 571 TYPES OF HYDRAULIC FRACTURING FLUIDSGenerally, a hydraulic fracturing treatment involves pumping a proppant-free viscous fluid, or pad, usually water with some fluid additives to generate high viscosity, into a well faster than the fluid can escape into the formation so that the pressure rises and the rock breaks, creating artificial fractures or enlarging existing fractures.After fracturing...

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The Impairment of Scale Inhibitor Function by Commonly Used Organic Anions

Cited by 9 publications

References 3 publications

Ferrous Iron Impact on Phosphonate and Polymeric Scale Inhibitors at Temperature Ranging from 25 to 70°C

Ferrous Iron Impact on Phosphonate and Polymeric Scale Inhibitors at Temperature Ranging from 25 to 70°C

Scale inhibitors

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