The Effect of Brine Supply on CO2 Injectivity Impairment Due to Salt Precipitation

2019 ◽  
Author(s):  
Jelena Todorovic ◽  
Martin Raphaug ◽  
Thomas Monge Oia ◽  
Alv-Arne Grimstad ◽  
Pierre Cerasi
Keyword(s):  
Salt Precipitation

Numerical modelling framework of continuous salt precipitation from super-critical water

2017 ◽  
Vol 53 (10) ◽  
pp. 1580-1591
Author(s):  
Akshay Yadav ◽  
Nilesh Gandhi ◽  
Rakesh Kumar ◽  
Supriya Apegaonkar ◽  
Ramesh Bhujade ◽  
...  
Keyword(s):  
Numerical Modelling ◽  
Salt Precipitation ◽  
Modelling Framework

scholarly journals EVIDENCE THAT THE L-ASPARAGINASE OF GUINEA PIG SERUM IS RESPONSIBLE FOR ITS ANTILYMPHOMA EFFECTS

1963 ◽  
Vol 118 (1) ◽  
pp. 99-120 ◽  
Author(s):  
J. D. Broome
Keyword(s):  
Guinea Pig ◽  
Guinea Pigs ◽  
Serum Proteins ◽  
Deae Cellulose ◽  
Salt Precipitation ◽  
Asparaginase Activity ◽  
Pig Serum

A number of the properties of the L-asparaginase present in guinea pig serum have been examined and shown to be indistinguishable from those of the agent responsible for inhibiting cells of lymphoma 6C3HED in vivo. The patterns of instability of the enzyme to changes in temperature and pH were found to parallel closely those of the antilymphoma agent. L-Asparaginase activity was essentially absent from the serum of newborn guinea pigs and this failed to inhibit 6C3HED cells. On separating guinea pig serum proteins by salt precipitation, electrophoresis, and chromatography on DEAE cellulose, antilymphoma activity was found only in fractions which contained L-asparaginase.

scholarly journals Analytical Solution to Evaluate Salt Precipitation during CO2 Injection in Saline Aquifers

2009 ◽  
Vol 1 (1) ◽  
pp. 1775-1782 ◽  
Author(s):  
Mehdi Zeidouni ◽  
Mehran Pooladi-Darvish ◽  
David Keith
Keyword(s):  
Analytical Solution ◽  
Saline Aquifers ◽  
Co2 Injection ◽  
Salt Precipitation

Experimental and Modeling Study of Salt Precipitation During Injection of CO2 Contaminated With H2S Into Depleted Gas Fields in the Northeast of the Netherlands

SPE Journal ◽  
2014 ◽  
Vol 19 (06) ◽  
pp. 1058-1068 ◽  
Author(s):  
P.. Bolourinejad ◽  
R.. Herber
Keyword(s):  
The Netherlands ◽  
Carbonic Acid ◽  
Co2 Storage ◽  
Mineral Dissolution ◽  
Co2 Injection ◽  
Salt Precipitation ◽  
Geological Time ◽  
Core Samples ◽  
Carbon Dioxide Co2 ◽  
Gas Fields

Summary Depleted gas fields are among the most probable candidates for subsurface storage of carbon dioxide (CO2). With proven reservoir and qualified seal, these fields have retained gas over geological time scales. However, unlike methane, injection of CO2 changes the pH of the brine because of the formation of carbonic acid. Subsequent dissolution/precipitation of minerals changes the porosity/permeability of reservoir and caprock. Thus, for adequate, safe, and effective CO2 storage, the subsurface system needs to be fully understood. An important aspect for subsurface storage of CO2 is purity of this gas, which influences risk and cost of the process. To investigate the effects of CO2 plus impurities in a real case example, we have carried out medium-term (30-day) laboratory experiments (300 bar, 100°C) on reservoir and caprock core samples from gas fields in the northeast of the Netherlands. In addition, we attempted to determine the maximum allowable concentration of one of the possible impurities in the CO2 stream [hydrogen sulfide (H2S)] in these fields. The injected gases—CO2, CO2+100 ppm H2S, and CO2+5,000 ppm H2S—were reacting with core samples and brine (81 g/L Na+, 173 g/L Cl−, 22 g/L Ca2+, 23 g/L Mg2+, 1.5 g/L K+, and 0.2 g/L SO42−). Before and after the experiments, the core samples were analyzed by scanning electron microscope (SEM) and X-ray diffraction (XRD) for mineralogical variations. The permeability of the samples was also measured. After the experiments, dissolution of feldspars, carbonates, and kaolinite was observed as expected. In addition, we observed fresh precipitation of kaolinite. However, two significant results were obtained when adding H2S to the CO2 stream. First, we observed precipitation of sulfate minerals (anhydrite and pyrite). This differs from results after pure CO2 injection, where dissolution of anhydrite was dominant in the samples. Second, severe salt precipitation took place in the presence of H2S. This is mainly caused by the nucleation of anhydrite and pyrite, which enabled halite precipitation, and to a lesser degree by the higher solubility of H2S in water and higher water content of the gas phase in the presence of H2S. This was confirmed by the use of CMG-GEM (CMG 2011) modeling software. The precipitation of halite, anhydrite, and pyrite affects the permeability of the samples in different ways. After pure CO2 and CO2+100 ppm H2S injection, permeability of the reservoir samples increased by 10–30% and ≤3%, respectively. In caprock samples, permeability increased by a factor of 3–10 and 1.3, respectively. However, after addition of 5,000 ppm H2S, the permeability of all samples decreased significantly. In the case of CO2+100 ppm H2S, halite, anhydrite, and pyrite precipitation did balance mineral dissolution, causing minimal variation in the permeability of samples.

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