An Environmentally Friendly Stimulation Fluid for High-Temperature Applications

LePage, James N.; Wolf, Corine De; Bemelaar, Josine; Nasr‐El‐Din, Hisham A.

doi:10.2118/121709-pa

Cited by 82 publications

(20 citation statements)

References 22 publications

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“…GLDA is used for iron control as well as stimulation of carbonate and sandstone reservoir. It has high solubility in both water and highly concentrated acid solutions (LePage et al 2011). This is because of the larger groups attached to the iminodiacetic acid part which reduces the likelihood of crystallization and therefore increasing solubility (De Wolf et al 2014).…”

Section: Glda (L-glumatic Acid N N-diacetic Acid)mentioning

confidence: 99%

Effect of Fe III and Chelating Agents on Performance of New VES-Based Acid Solution in High-Temperature Wells

Zebarjad

Nasr‐El‐Din

Badraoui³

2017

SPE International Conference on Oilfield Chemistry

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Viscoelastic surfactant (VES)-based acid systems are used in acid-diversion applications. However, high-temperature, interaction of the VES and Fe(III) (as a contaminant), addition of alcohol-based additives, and chelating agents all interfere with the apparent viscosity of the VES-based acid and reduce its effectiveness. This research introduces a new VES-based acid system that can be used for diversion in hightemperature formation matrix acidizing. This VES-based acid system exhibits high thermal stability in the presence of Fe(III) contamination and chelating agents. Also, this work elucidates the reaction mechanisms between VES, Fe(III), and two chelating agents (hydroxyethylethylenediaminetriacetic acid (HEDTA), and Glutamic acid diacetic acid (GLDA)) in spent acids. To study the rheological properties of the VES-based acid, three different formulations of spent acid (20 wt% hydrochloric acid (HCl), 5 vol% VES) were examined. By comparing the apparent viscosity of the three samples as a function of temperature, the same trend (similar viscosity at same temperatures) was illustrated. Moreover, the effect of chelating agents and Fe(III) on VES viscosity in spent acids was investigated. To understand the VES interaction with Fe(III) in spent conditions, a compatibility test was conducted on the live VES-acid and Fe(III) system. The results showed that the maximum concentration of the Fe(III), which is compatible with live VES-based acid, is 5,000 ppm; however, at higher Fe(III) concentrations, the VES interacted with the Fe(III) and precipitated. iii Rheological measurements were conducted on the spent VES based system with different Fe(III) concentrations as a function of temperature (80-400°F) at pH in the range of 4-5. At Fe(III) concentrations lower than 6,000 ppm, the apparent viscosity of the VESbased solutions increased in temperatures below 150°F as the Fe(III) concentration was increased. At higher temperatures (150-400°F), the maximum viscosities reduced with iron concentration, but generally they exhibited excellent thermal stability (150 cp at 400°F). The spent VES-based solution, when combined with 6,000 ppm Fe(III), entirely loses its viscosity. Experimental results indicated that the first peak of apparent viscosity of the VESbased solution increases at low concentrations (0.010 mol/L) of the chelating agents, HEDTA and GLDA, but for both chelating agents at higher concentrations (0.053 and 0.107 mol/L), the apparent viscosity reduces. Inclusively, the apparent viscosity remained above 140 cp with the highest concentration of chelating agents in the temperature range of 80-400°F. Furthermore, both chelating agents were added (1:1 molar to Fe(III)) to VES-based acid solutions with Fe(III) concentrations of 5,000 and 6,000 ppm. The results demonstrated that the negative impact of the chelating agents on the apparent viscosity does not superimpose on the negative effect of Fe(III). Chelating agents rebuilt the viscosity of the VES-based solution with 6,000 ppm Fe(III). For the 5,000 ppm Fe(III) solu...

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Section: Glda (L-glumatic Acid N N-diacetic Acid)mentioning

confidence: 99%

Effect of Fe III and Chelating Agents on Performance of New VES-Based Acid Solution in High-Temperature Wells

Zebarjad

Nasr‐El‐Din

Badraoui³

2017

SPE International Conference on Oilfield Chemistry

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“…As a replacement for HCl, GLDA is significantly safer and less corrosive [240]. GLDA has low toxicity and aquatic toxicity characteristics.…”

Section: Matrix Acidizingmentioning

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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“…Overall, GLDA and HEDTA (Frenier et al 2004) chelating agents are a safe, environmentally friendly, and effective stimulation solution that can help improve the well productivity with the least possible well integrity or HSE concerns. According to the Organization of Economic Cooperation and Development (OEDC 1992), GLDA chelating agent was listed as a nontoxic and biodegradable chemical (LePage et al 2011;Mahmoud et al 2011b).…”

Section: Introductionmentioning

confidence: 99%

Stimulation of Seawater Injectors by GLDA (Glutamic-Di Acetic Acid)

Mahmoud

Abdelgawad

Elkatatny

et al. 2016

SPE Drilling &Amp; Completion

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Seawater is injected to maintain the reservoir pressure that supports the oil production from carbonate and sandstone reservoirs. In certain regions, the seawater contains more than 4,000 ppm sulfate, and the formation contains more than 19,000 ppm calcium; this will cause calcium sulfate precipitation at the reservoir conditions. The precipitate at the reservoir conditions will be anhydrite, and it will cause formation damage that will reduce the well injectivity. Stimulation treatments are required to recover the well injectivity; this requires stopping water injection to perform the stimulation treatments, and also it requires flowing back the well after stimulation treatment.In this study, we are proposing a new method that we can use to stimulate water injectors without stopping the water injection. The new method includes adding a chelating agent to the injected seawater at the wellhead at 15 wt% concentration. The fluid will be injected at the surface with the seawater with a specific dose to achieve the required concentration. Several solubility and coreflooding tests were performed with actual carbonate cores and GLDA (glutamic-di acetic acid) chelating agent at different temperatures. The chemical injection does not need coiled tubing and can be injected at the surface with the seawater. The chelating agents will sequester all calcium in solution and will prevent the calcium sulfate precipitation. GLDA chelating agent will be used with seawater, with no need to use treated or fresh water. Also, flowing back the well is not required because the fate of GLDA in the aquifer is soluble.Solubility tests up to 250 F at high pressure showed that the GLDA is stable with seawater. Coreflood experiments and computed-tomography scans showed the ability of GLDA in the creation of dominant wormholes through 6-and 1.5-in. carbonate cores at 212 and 150 F, respectively. GLDA chelating agent can be used to stimulate seawater injectors without additives because this chemical is stable and mild with the well tubulars. Previous corrosion studies on GLDA showed that its corrosion rate is in the allowable range without adding corrosion inhibitors.

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An Environmentally Friendly Stimulation Fluid for High-Temperature Applications

Cited by 82 publications

References 22 publications

Effect of Fe III and Chelating Agents on Performance of New VES-Based Acid Solution in High-Temperature Wells

Effect of Fe III and Chelating Agents on Performance of New VES-Based Acid Solution in High-Temperature Wells

Fracturing fluids

Stimulation of Seawater Injectors by GLDA (Glutamic-Di Acetic Acid)

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