Insight Into Strontium and Calcium Sulfate Scaling Mechanisms in a Wet Producer

Shen, J.; Crosby, C.C.

doi:10.2118/10597-pa

Cited by 41 publications

(17 citation statements)

References 12 publications

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“…The advantage of using experimental solubility data is that the activities of the respective metal ions and the anion of interest need not be determined directly but are included implicitly in the conditional constants. Solubility data were obtained from the literature for gypsum (Blout and Dickson, 1973; Liu and Nancollas, 1971; Nancollas et al, 1978; Shen and Corsby, 1983; , for hemihydrate and anhydrite (Tempelton and Rodgers, 1960), for celestite (Liu and Nancollas, 1971), and barite (Collins and Leinweber, 1956; Leon and Scott, 1987; Lindlof and Stoffer, 1983). Pressure data for the CaSO, systems can be found in or calculated from data given in Collins and Leinweber (1 956), Davis and Collins (1971), Hunton and Gilbert (1982), Nancollas and Liu (1975) and Tempelton (1960).…”

Section: Estimation Of Scale Formation Potentialmentioning

confidence: 99%

Prediction of Scale Formation Problems in Oil Reservoirs and Production Equipment due to Injection of Incompatible Waters

Moghadasi

Sharif

Müuller-Steinhagen

et al. 2006

Dev. Chem. Eng. Mineral Process.

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Section: Estimation Of Scale Formation Potentialmentioning

confidence: 99%

Prediction of Scale Formation Problems in Oil Reservoirs and Production Equipment due to Injection of Incompatible Waters

Moghadasi

Sharif

Müuller-Steinhagen

et al. 2006

Dev. Chem. Eng. Mineral Process.

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“…The solubility product constants (K sp ) for different carbonate and sulfate scales decrease with temperature for a temperature range of 60-300°F (Nassivera and Essel 1979;Essel and Carlberg 1982;Shen and Corsby 1983). Oddo et al (1991); Oddo and Tomson (1994) showed that the formation of calcium sulfate scale depends on temperature and does not depend on pH and can precipitate at low as well as high pH values.…”

Section: Introductionmentioning

confidence: 99%

Using high- and low-salinity seawater injection to maintain the oil reservoir pressure without damage

Mahmoud

Elkatatny

Abdelgawad

2016

J Petrol Explor Prod Technol

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The oil reservoir pressure declines due to oil production, and this decline will lead to reduction in the oil productivity. The reservoir pressure maintenance is a practice in the oil industry in which seawater is injected into the aquifer zone below the oil zone to support the reservoir pressure. Calcium sulfate scale is one of the most serious oilfield problems that could be formed in sandstone and carbonate reservoirs. Calcium sulfate may precipitate during the injection of seawater with high sulfate content into formation brine with high calcium content. Mixing seawater and formation water may cause precipitation of calcium sulfate, barium sulfate, and/or strontium sulfate. Seawater treatment does not remove the entire sulfate ions from the injected water. Low sulfate concentrations may cause damage. Enhanced oil recovery processes such as smart water injection, which originally is diluted seawater, may cause calcium sulfate precipitation as the reduction of water salinity will increase the sulfate precipitation and decrease its solubility. This study was conducted to investigate the damage caused by the deposition of calcium sulfate precipitation. A solution is proposed to prevent the damage due to calcium sulfate by using chelating agents. Several coreflooding experiments were conducted using Berea sandstone and Indiana limestone cores at reservoir conditions of pressure and temperature using seawater (high and low salinity) and formation water. Chelating agents used in this study are: EDTA (ethylenediaminetetraacetic acid), HEDTA (hydroxyethylenediaminetriacetic acid), and HEIDA (hydroxyethyliminodiacetic acid). HEDTA and HEIDA chelating gents are environmentally friendly and can be used in marine environment. High-salinity water injection caused severe formation damage, and the injectivity will decline faster compared to the low-salinity water injection. HEDTA and EDTA chelating agents at low concentrations performed better than HEIDA chelating agents in both Berea sandstone and Indiana limestone cores. HEDTA and EDTA chelating agents were able to prevent the damage due to calcium sulfate precipitation and enhanced the core permeability.

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“…Most of the field scale barium sulfate deposits also contain strontium sulfate (Essel and Carlberg, 1982;Shen and Corsby, 1983).…”

Section: Strontium Sulfate Scalementioning

confidence: 99%

The Effect of Temperature, Pressure, and Mixing Ratio of the Injection Water With Formation Water on Strontium Sulfate Scale Formation in the Siri Oilfield

Amiri

Moghadasi

Pordel

2012

Petroleum Science and Technology

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Enhanced oil recovery methods are used to recover the percents of oil that are not naturally recoverable from reservoirs. Water injection as a secondary recovery is used to maintain the pressure in water-drive reservoirs. An important point for having a successful injection is the compatibility of injection and formation waters. OLI ScaleChem software predicts mineral scaling potentials of 54 solids for virtually any oil and gas well and processing facility in the world. There are several advantages over other commercially available scaling software: (a) by including all brines in the calculations, the well and processing facility are modeled more accurately; (b) scaling potential and scale buildup are reported at each calculation point; (c) automatic correction of pH and charge balance, therefore the chance of unexpected problems from bad water analyses decreases. Also, more effective treatment can be made, including: (d) automatic removal of organic acid concentrations from the measured alkalinity, therefore producing a true brine alkalinity; (e) accurate prediction of the behavior of any mixture of chemicals in water and mixed solvent. The authors present the predicting of strontium sulfate scale tendency of formation water, injection water, and mixing of injection water with formation water at different conditions. The experimentally measured chemical analyses of formation water and injection water were used by OLI ScaleChem software to determine the tendency of scale formation at different conditions.

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Insight Into Strontium and Calcium Sulfate Scaling Mechanisms in a Wet Producer

Cited by 41 publications

References 12 publications

Prediction of Scale Formation Problems in Oil Reservoirs and Production Equipment due to Injection of Incompatible Waters

Prediction of Scale Formation Problems in Oil Reservoirs and Production Equipment due to Injection of Incompatible Waters

Using high- and low-salinity seawater injection to maintain the oil reservoir pressure without damage

The Effect of Temperature, Pressure, and Mixing Ratio of the Injection Water With Formation Water on Strontium Sulfate Scale Formation in the Siri Oilfield

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