Scale-fragment formation impairing geothermal energy production: interacting H2S corrosion and CaCO3 crystal growth

Boch, Ronny; Leis, Albrecht; Haslinger, Edith; Goldbrunner, J. E.; Mittermayr, Florian; Fröschl, Heinz; Hippler, Dorothee; Dietzel, Martin

doi:10.1186/s40517-017-0062-3

Cited by 36 publications

(38 citation statements)

References 40 publications

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“…Abbreviations: Pl = Pleistocene; H = Holocene. 6 Geofluids will form but corrosion cannot happen, whereas if it is more than 6.8, the water is aggressive [41]. Selected and representative scale-fragment samples from both study sites were investigated via mineralogical and petrographic methods.…”

Section: Methodsmentioning

confidence: 99%

“…For production wells of the studied cascade systems, relatively low RSI values (<6.2) also reflect that scale will form, whereas RSI 12 Geofluids data for two reinjection wells together with the value for Anna well indicate an aggressive water, so corrosion could be significant. Relatively high chloride content (up to 420 mg/l), as a corrosive constituent, could also promote steel corrosion and the products may constitute an attractive crystallization substrate for carbonate scales [6][7][8]. Results of a case study, however, indicate that strongly reducing redox conditions at pH~6, high sulfide, chloride, and gaseous CO 2 contents together with high thermal fluid temperatures (>100°C in the aquifer) is necessary to promote efficient and rapid steel corrosion [6].…”

Section: Thermal Water Chemistrymentioning

confidence: 99%

“…Geothermal systems are often characterized by the interaction of complex processes as discussed elsewhere [1]. Therefore, geothermal exploration is increasingly focusing on the extensive integration of multidisciplinary data from production technology to hydrogeochemistry and geological researches [1][2][3][4][5][6][7][8]. Unfortunately, many geothermal installations (e.g., hydrothermal cascade systems) face important operational challenges such as unwanted scaling accompanying the exploitation of high-temperature waters with high salinity and gas content from deep wells [6].…”

Section: Introductionmentioning

confidence: 99%

“…Therefore, geothermal exploration is increasingly focusing on the extensive integration of multidisciplinary data from production technology to hydrogeochemistry and geological researches [1][2][3][4][5][6][7][8]. Unfortunately, many geothermal installations (e.g., hydrothermal cascade systems) face important operational challenges such as unwanted scaling accompanying the exploitation of high-temperature waters with high salinity and gas content from deep wells [6]. General characteristics of scales depend on natural conditions (e.g., geological setting, reservoir type, physicochemical properties, and hydrogeological and hydrochemical features) as well as man-made ones (e.g., well depth, flow rate, operating pressure, substrate material, and effects of biological processes) [5][6][7][8].…”

Section: Introductionmentioning

confidence: 99%

“…As a scale component, calcium carbonate (CaCO 3 , aragonite, and/or calcite) precipitation is widespread in low-to moderate-enthalpy geothermal facilities tapping deep limestone and dolomite aquifers [6,7]. Although the aquifers of the Szeged Geothermal Systems (SE Hungary, Great Hungarian Plain) are traditionally considered being siliciclastic ones (mainly very fineto fine-grained sandstones) with dominantly Na-HCO 3 -type thermal water [3,9], relatively high carbonate scale deposition rates have been observed especially in the pipes between the production wells and their buffer tanks [7].…”

Section: Introductionmentioning

confidence: 99%

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Cements, Waters, and Scales: An Integrated Study of the Szeged Geothermal Systems (SE Hungary) to Characterize Natural Environmental Conditions of the Thermal Aquifer

et al. 2019

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The study area, Pannonian Basin (Central Europe), is characterized by high heat flow and presence of low-enthalpy geothermal waters. In the Szeged Geothermal Systems (Hungary), having Miocene to Pliocene sandstone aquifers with dominantly Na–HCO3-type thermal water, unwanted carbonate scaling was observed. An integrated approach consisting of host rock and scale mineralogical and petrographic analyses as well as water chemistry led to a better understanding of the characteristic natural (geogenic) environmental conditions of the geothermal aquifers and to highlight their technical importance. Analyses of the reservoir sandstones showed that they are mineralogically immature mixed carbonate-siliciclastic rocks with significant macroporosity. Detrital carbonate grains such as dolomite and limestone fragments appear as important framework components (up to ~20–25%). During water–rock interactions, they could serve as a potential source of the calcium and bicarbonate ions, contributing to the elevated scaling potential. Therefore, this sandstone aquifer cannot be considered as a conventional siliciclastic reservoir. In mudrocks, a significant amount of organic matter also occurs, triggering CO2 producing reactions. Correspondingly, framboidal pyrite and ferroan calcite are the main cement minerals in all of the studied sandstone samples which can suggest that calcite saturation state of the thermal fluid is close to equilibrium in oxygen-depleted pore water. Analysis of the dominant carbonate crystals in the scale can suggest that growth of the feather dendrites of low-Mg calcite was probably driven by rapid CO2 degassing of CO2-rich thermal water under far-from-equilibrium conditions. Based on hydrogeochemical data and related indices for scaling and corrosion ability, the produced bicarbonate-rich (up to 3180 mg/l) thermal water has a significant potential for carbonate scaling which supports the aforementioned statement. Taking into consideration our present knowledge of geological setting of the studied geothermal systems, temporal changes in chemical composition and temperature of the thermal water during the heating period can indicate upwelling fluids from a deep aquifer. Regarding the pre-Neogene basement, hydrologic contact with a Triassic carbonate aquifer might be reflected in the observed chemical features such as decreased total dissolved solids and increased bicarbonate content with high scale-forming ability. The proposed upflow of basin-derived water could be channeled by Neogene to Quaternary fault zones, including compaction effects creating fault systems above the elevated basement high. The results may help to understand the cause of the high carbonate scale precipitation rates in geothermal systems tapping sandstone aquifers.

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Section: Methodsmentioning

confidence: 99%

Section: Thermal Water Chemistrymentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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Cements, Waters, and Scales: An Integrated Study of the Szeged Geothermal Systems (SE Hungary) to Characterize Natural Environmental Conditions of the Thermal Aquifer

et al. 2019

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The fate of a travertine record: Impact of early diagenesis on the Y‐10 core (Mammoth Hot Springs, Yellowstone National Park, USA)

Boever

Jaramillo‐Vogel

Bouvier

et al. 2021

The Depositional Record

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Spring systems are efficient and fast precipitating non‐marine carbonate factories, but they are also prone to (early) diagenesis. Evidence of diagenesis in travertines remains controversial as the resulting textures have been considered primary in other deposits and the impact on geochemical/palaeo‐environmental signals is often poorly addressed. This study revisits the Y‐10 core, taken in 1967 at one of the upper terraces of Mammoth Hot Springs in Yellowstone National Park (USA). The travertine depositional facies in the upper 50 m of the core show a general distal to proximal facies trend upwards. To unravel the nature, impact and timing of early diagenesis, fabrics and geochemical signatures are also compared to modern hot spring carbonates. Secondary ion mass spectrometry and detailed microscopy proved powerful in determining the stable isotope signature of different cement generations, thereby detangling the fluid history. Diagenesis starts during spring activity, but these warm waters not only precipitate CaCO3 at the top, they also seem to have circulated through the porous spring fabrics below. It resulted in coarsening and homogenization of the primary textures through neomorphism of aragonite and calcite cementation, often resulting in new intracrystalline microporosity within the calcite crystals. Subsequent circulation of meteoric fluids led to dissolution and cementation, particularly near the top of the core. Careful interpretation of U/Th dates suggests that travertine deposition started at the beginning of the Holocene/end Pleistocene. Calculated depositional (precipitation) rates vary between 2 and 20 mm/year, assuming a constant rate between samples at different depths. Aragonite deposits are completely transformed to calcite below depths of 5–10 m, corresponding to a time span of 4,000 years. Core and petrography observations, together with dating, suggest that travertine strata below marine sandstones in the lower part of the core may relate to fault displacement after the onset of travertine deposition.

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Preventing sour gas kicks during workover of natural gas wells from deep carbonate reservoirs with anti‐hydrogen sulfide fuzzy‐ball kill fluid

Yan

Okere

Zeng

et al. 2022

Energy Science & Engineering

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Workover of natural gas wells in deep carbonate gas reservoirs (DCRs) is facing multiple challenges such as fluid leakage, high temperature, and hydrogen sulfide (H2S) gas kick. Hence, well‐killing fluids with satisfactory plugging ability, high‐temperature tolerance, and anti‐H2S ability are necessary. In this study, we developed a multifunctional anti‐hydrogen sulfide fuzzy‐ball kill fluid (AFKF) for preventing sour gas kicks in DCRs. The performance of the AFKF was optimized and analyzed via experiments and verified through a case study application. The results showed that the fuzzy‐ball structures in the AFKFs demonstrated good stability under extreme H2S aging. The rate of change of certain critical rheological parameters such as apparent viscosity, dynamic plastic ratio, and density of AFKFs before and after hot rolling were no more than 5%. After plugging the fractures with the AFKFs at temperatures between 110°C and 150°C, the inlet driving pressure of the fractures increased from 20.73°C to 21.07 MPa, and no fluid loss was observed at the core outlet after a secondary displacement of formation water. The permeability recovery rate was greater than 90%. Application of AFKF in well DW‐2 showed that the shut‐in pressure rose to 24.6 MPa with no trace of H2S gas at the wellhead after 4 days. The investigation of the H2S mitigation mechanisms revealed that the plugging of the seepage channels by AFKFs forms interconnected bonds that improve the mechanical properties of the reservoir. Additionally, AFKFs absorb H2S gases by protonation and dissociation reactions which convert the hazardous gas into an aqueous solution of sulfide ions (S2−). The proposed AFKF has proven to be effective means of mitigating H2S in DCRs, and minimize the negative impacts of environmental polution, health risks, and equipment corrosion.

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Scale-fragment formation impairing geothermal energy production: interacting H2S corrosion and CaCO3 crystal growth

Cited by 36 publications

References 40 publications

Cements, Waters, and Scales: An Integrated Study of the Szeged Geothermal Systems (SE Hungary) to Characterize Natural Environmental Conditions of the Thermal Aquifer

Cements, Waters, and Scales: An Integrated Study of the Szeged Geothermal Systems (SE Hungary) to Characterize Natural Environmental Conditions of the Thermal Aquifer

The fate of a travertine record: Impact of early diagenesis on the Y‐10 core (Mammoth Hot Springs, Yellowstone National Park, USA)

Preventing sour gas kicks during workover of natural gas wells from deep carbonate reservoirs with anti‐hydrogen sulfide fuzzy‐ball kill fluid

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