Influence Mechanism of Coexisting Ions on the Extraction Efficiency of Lithium from Oil and Gas Field Water

In order to provide a theoretical basis for reasonable material selection in oil and gas field, according to the actual situation of a water source well, materials N80, 3Cr, H13, 13Cr and super 13Cr were selected as the research objects. The microstructure and hardness of N80, 3Cr, H13, 13Cr and super 13Cr were studied by metallographic observation and hardness test. By simulating the actual corrosion environment of the water source well, the experiment of autoclave hanging sheet and detection of corrosion products by X ray diffraction and the CO2 corrosion resistance of N80, 3Cr, H13, 13Cr and super 13Cr were analyzed. Besides, some suggestions for material selection of oil and gas wells were put forward. It is found that super 13Cr has higher hardness and CO2 corrosion resistance, 13Cr and 3Cr are second. When selecting oil and gas field water well material, it is recommended to choose super 13Cr first, then 13Cr and 3Cr.

Data collected in two counties in north central Texas were used to empirically explore issues associated with public perception of desalinated water from oil and gas field operations. The data reveal that small percentages of respondents are extremely familiar with the process of desalination and extremely confident that desalinated water could meet human drinking water quality and purity standards. The data also indicate that respondents are more favorably disposed toward the use of desalinated water for purposes where the probability of human or animal ingestion is lessened. Lastly, the data show that respondents who are more familiar with desalination technology are more likely than those who are less familiar to believe that desalinated oil and gas field water could safely be used for selected purposes. Possible implications of these findings are advanced, as are suggestions for future research.

Thermally assisted efficient electrochemical lithium extraction from simulated seawater

Samples of oil-field water (oil wells, injectate, disposal ponds) and groundwater near selected oil and gas fields in southern California were analyzed for dissolved organic carbon (DOC) concentration and by optical spectroscopic techniques (i.e., absorbance and fluorescence) to assess whether these measurements can be used to distinguish between oil-field water (Oil Field), native groundwater (WGnat), and native groundwater mixed with oil-field water from surface (WGsurf) or subsurface sources (WGsub), and if so whether commonly reported optical measurements can be used as a screening tool to identify such water. Concentrations of DOC were significantly (p < 0.0001) higher (67 to 2934 mg C L−1) in oil-field water compared to native groundwater samples (<5.0 mg C L−1). Individual optical properties varied by water category and frequently overlapped. However, multivariate statistical analysis showed that when evaluated in combination, 10 optical properties were determined by discriminant analysis to be significant (p < 0.05) in distinguishing among water categories. Principal component analysis of those 10 optical properties showed that these properties can be used to successfully distinguish Oil Field samples from WGnat, WGsurf, and WGsub even when mixing fractions are low (approximately 10 %).

Chapter Fourteen - Special Focus on Produced Water in Oil and Gas Fields: Origin, Management, and Reinjection Practice

&lt;abstract&gt; &lt;p&gt;Nowadays, the concentration of mineral cations and anions in the formation water of oil and gas fields is a challenging issue for oil industry technicians managing the formation of mineral deposits during water injection operations. For this reason, the analysis of formation water mineral ions during exploitation operations can be a valuable solution for the efficient management of oil production. Therefore, in this research, the thermodynamic and geochemical evaluation of formation water in the Reg-e Sefid oil and gas field is considered. Based on the results of this study, the formation of calcium sulfate and calcium carbonate can be expected due to the concentration of mineral ions dissolved in the formation water in the Reg-e Sefid oil and gas field according to the StimCad2 software. Also, based on the evaluation of ion ratios, the studied oil and gas field formation has ideal conditions for hydrocarbon production. Based on the results obtained from the comparison of the water and rock formation of the Rag-e Sefid oil and gas field, the source of ions (except calcium and magnesium ions) is related to ancient sea water.&lt;/p&gt; &lt;/abstract&gt;

Determination of inorganic ions in oil field waters by single-column ion chromatography

_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 215585, “Lithium Extraction From North Sea Oilfield Brines Using Ion-Exchange Membranes,” by Botelho Disu, Roozbeh Rafati, and Amin S. Haddad, University of Aberdeen, et al. The paper has not been peer reviewed. _ The annual demand for lithium for low-carbon technology applications has been growing exponentially. A necessity exists in the current environment for continuous lithium production from both conventional sources and novel extraction sites from alternative brine resources such as oil fields and geothermal sites. in the complete paper, the lithium potentiality of the UK North Sea is evaluated. Identification of North Sea Lithium-Rich Oil and Gas Fields Maps show lithium-ion concentration diffusing from 55 ppm in the western region into low concentrations in the central, northern, and eastern regions of the UK North Sea. Such estimates suggest lithium enrichment in oilfield brine from the Beatrice, Clymore, Gannet, Cly, Auk, and Flumar fields. However, because such map distribution of lithium is achieved based only on one-third of the imputed data, a correlative evaluation with the entire body of data is needed to provide a much more feasible interpretation. When lithium distribution was evaluated simultaneously with strontium/iron/potassium (Sr/Fe/K) total dissolved solids, the rich brine was primarily located across the central, eastern, southern, and western fields. The central and eastern concentrations were estimated to have a lithium-rich brine with concentrations of up to 40 ppm, with lithium-ion presence gradually increasing toward the east. Most of the fields in this region are oil fields, including Montrose, Arbroath, Ula, Nelson, Brisling, Gyda, Ekofisk, and Bream, with Harald possibly being the only gas field with lithium-enriched brine. On the other hand, the lithium-rich fields in the southern and western regions are all gas fields, including the Esmond, Anglia, Lemman, Ann, and Viking fields. Statement of Theory and Definition The economic feasibility of lithium extraction from brine has been observed to be a function of its initial concentration. For oilfield brines, when using novel direct-lithium-extraction (DLE) technologies, the brine concentration economic feasibility for production is reduced to a cutoff benchmark of 50 ppm. However, ongoing developments in DLE technologies envision a feasible, efficient, and highly selective recovery of lithium from brines with low concentrations, even sea water. Manganese ion-sieve powder is a DLE technology that has gathered growing interest. However, one of the main challenges of its application in continuous industrial processes consists of operational challenges that its original powder form can cause. Therefore, forming is necessary if ion-sieve adsorbents are to have an industrial application. This paper has reported and discussed the experimental results of forming the adsorbent powders into different ion-exchange membranes (foam, flat sheet, and granular spherical beads) and their application for lithium extraction from simulated North Sea brine. The complete paper details the description and application of experimental equipment and processes.

Based on studies of the decomposition of pe­ta­lite ore, the hydrothermal method for the extraction of lithium and aluminum compounds from lithium aluminosilicate Li[AlSi4O10] (petalite) has been developed. The studied sample of ore contains, wt. %: Li2O – 0.75 and Al2O3 – 14.65. For unenriched petalite ore with low lithium content, it is proposed to use the hydrochemical method of aluminosilicate processing – Ponomarev – Sazhin method. According to this method, the decomposition of ore is carried out directly in autoclaves by chemical interaction of ore components with NaOH solution in the presence of calcium oxide. The conditions (high temperature and pressure) for the destruction of petalite and the transition of lithium into the liquid phase are created exactly in the hydrothermal process. In this case, lithium and aluminum compounds pass into the solution, and calcium and silicon form a partially soluble compound in the solid phase – sodium-calcium hydrosilicateNa2O·2CaO·2SiO2·2H2O. The degree of extraction of lithium reaches 89–94 %, aluminum reaches 77–95 % within 1 hour at a tempe­rature of 240–280 °C, given caustic modulus 14–18, the concentration of the initial solution of 400–450 g/dm3 of Na2O and the ratio of CaO : SiO2 = 1 : 1 in the reaction mixture. Aluminate or lithium carbonate and other compounds can be obtained from an aluminate solution containing 1.5–2.5 g/dm3 of Li2O and 32–44 g/dm3 of Al2O3. The solid phase formed as a result of decomposition, with a high degree of extraction of lithium from the ore contains a small amount of Li2O in its composition and therefore can be used in the cement industry. Depending on the quality of the decomposed raw material, the course of the hydrothermal process is influenced by a set of factors. With a small content of lithium and aluminum in the ore, the caustic modulus of aluminate solutions (αк = 1,645*Na2O/Al2O3) formed after decomposition is important. Its calculation is required in order to determine the amount of alkaline solution of the required concentration to ensure almost complete decomposition of the ore. This value should be higher the lower the decomposition temperature and the concentration of the initial solution to achieve the same degree of recovery of useful components in the liquid phase. With the same caustic modulus, the efficiency of ore decomposition increases significantly with increasing process temperature and increasing the concentration of the initial solution. This can be seen in the values of the degree of extraction of aluminum, which increases by 12 % with increasing temperature from 240 to 280 °C, while the extraction of lithium remains practically unchanged.

Current production conditions and development of oil fields are complicated by the development of increasingly difficult-to-recover reserves as well as by the consequences of 2020, which include a change in the structure of demand and a collapse of the oil market, the global trend towards low-carb fuel systems and the implementation of the principles of environmental, social and managerial responsibility (ESG). This research paper is focused on diversification of the oil and gas business by extracting lithium from reservoir waters of oil and gas condensate fields. This method allows to increase the profitability of deposits. The paper also carries out a technical and economic assessment of the process of the sorption lithium extraction from the formation waters of oil fields.

Currently, special attention is required at the government level in Kazakhstan to the exploration and development of lithium deposits, in the future-industrially cost-effective technologies for the production of this light rare earth metal. Lithium is an important raw material for developed countries. In Kazakhstan, 7 lithium deposits have been explored in the East Kazakhstan region, which are not involved in industrial processing. Recently, the production of lithium from salt solutions has been developing rapidly Salt solutions usually contain high concentrations of magnesium, potassium and sodium, as well as many other elements, including Boron, in addition to lithium. From the salt solution, sodium, potassium and magnesium chlorides evaporate in the sun to crystallize, leaving a concentrated solution of lithium chloride. It is estimated that lithium carbonate mining using salt ponds is 30-50% cheaper than lithium mining in hard rocks. Evaporation of brine Although the use of open ponds is nominally cheap, the evaporation process requires a lot of time, large land resources, and also the most important resource, water is used irrationally. Therefore, there is a growing trend towards the development of technology and processes for the "direct extraction" of lithium from salt solutions for geothermal and traditional lithium sources. These are methods of direct extraction, sorption, and precipitation. The number of scientific publications devoted to the extraction of lithium from various sources is constantly growing, but there is very little data on specific processes or technologies for the extraction of lithium from salt solutions of oil fields. Several technologies can be used to extract lithium from various salt solutions, such as solar evaporation, precipitation, adsorption, ion exchange, solvent extraction and membrane processes. However, when it comes to extracting lithium from oilfield salt solutions, only some of the methods mentioned can be used. He developed a technology for lithium enrichment of individual deposits of salt solutions. Despite numerous recently published scientific papers concerning the development of new methods for direct lithium extraction, in almost all the cases described above, adsorption processes only in lithium-ion sieves are used to extract lithium from salt solutions of oil fields on a large scale (unlike laboratory solutions).

Scale inhibitors are an extremely important chemical in upstream oil and gas field operations and water treatment industries. These inhibitors prevent nucleation and/or crystal growth of scales such as calcite and barite. This keeps the pipes and other equipment and surfaces free from deposits, allowing the maximum flow of aqueous fluids. However, many classes of scale inhibitors are poorly biodegraded, especially in seawater, making them unacceptable in regions with strict environmental regulations. Tetrasodium iminodisuccinate (TSIDS) is a biodegradable, industrial-scale dissolver that we imagined could have potential as a scale inhibitor, given the correct derivatization. We first synthesized phosphonated derivatives of TSIDS (TSIDS-P) and the homologue phosphonate made from ethylenediamine disuccinate (TSEDAS-P). In particular, TSIDS-P was shown to be a good calcite scale inhibitor with good calcium compatibility but also exhibited over 70% biodegradation (BOD28) in the OECD 306 seawater test. This should make TSIDS-P a readily biodegradable scale inhibitor of great interest to the petroleum and water treatment industries.

The quality of produced water in oil and gas field is complex and difficult to treat. Ultrasonic water treatment technology has a good effect on degradation of organic polymers and demulsification, but its application is limited due to energy consumption and other reasons, and it has not been industrialized in oil and gas field water treatment. Through ultrasonic mechanism research, water quality characteristics analysis and a large number of small simulation tests, the test results show that for complex produced water with high salt content, high turbidity and high emulsification, under the ultrasonic frequency of 39.5kHz, ultrasonic time of 30min and operation conditions of 25°C, the oil removal effect can be achieved at 66W power. The oil content is reduced from 77.9mg/L in the inlet water to 1.87mg/L in the outlet water, and the oil removal rate can reach more than 95% to meet the expected demand. In the case of the mature development of green electricity technology, this study provides a new technical idea for the efficient treatment of produced water in oil and gas fields, and provides a basic research basis for the industrial application of ultrasonic treatment process and the collaborative application of combined with other processes.

Lithium sources are of great significance for developing the next generation of lithium ion batteries. Most of the world’s lithium sources are found in salt lake brines. The main challenge of lithium extraction from salt lake brine is the separation of lithium ions from other coexisting ions, especially the separation of Li+ and Mg2+. However, the traditional precipitation method for salt lake lithium extraction is cumbersome. In this project, a new electrolytic device with a solid-state electrolyte was developed for high-efficient lithium extraction from salt lake brines. Li1+xAlxTi2−x(PO4)3 (LATP) is a promising NASICON-type solid-state electrolyte, which exhibits high ionic conductivity ( >10-4 S/cm) at room temperature. LATP can be used as a lithium ion conductor, that is only lithium ions can transfer through it, which is ideal for separating lithium ions from other ions in salt lake brines. In this project, high-quality LATP was fabricated at a low cost. An electrolytic device was developed for lithium extraction, in which LATP was used together with a sacrificial anode, molten salts, and an inert cathode. Salt lake brines need to be concentrated by solar and/or wind evaporation before lithium extraction. The electrolytic device was operated above the melting point of the concentrated brine water, at which LATP exhibits a higher ionic conductivity for fast lithium ion transfer. A tiny voltage was applied across the two electrodes to drive the electrochemical reaction. The composition of lithium sources before and after extraction was investigated by inductively coupled plasma-optical emission spectroscopy (ICP-OES). Results show that lithium sources with a higher purity level were successfully extracted with high efficiency. Impurity ions were almost completely blocked by LATP.

The formation of calcium carbonate mineral scale is a persistent and expensive problem in oil and gas production, especially in the high temperature and high pressure (HTHP) wells. Scaling of metallic or insulating walls in contact with hard water may cause unscheduled equipment shutdown and loss of production. The aim of this paper is to develop environmentally friendly calcium carbonate scale inhibitors for HTHP squeeze application in the oil and gas field water treatment. Typical commercial scale inhibitors, including several phosphonate based squeeze scale inhibitors and patented environmentally friendly polyacrylic copolymers have been tested based on thermally stability test, formation water compatibility test, dynamic scale loop test and coreflood test. In this paper, an environmentally friendly calcium carbonate scale inhibitor has been developed to inhibit calcium carbonate scale deposition effectively under HTHP conditions. The characteristics of this product are as following: Thermally stable at high temperatureExcellent calcium tolerance at high temperatureGood inhibition performance on CaCO3 deposition at high temperatureLong squeeze life and no formation damage based on coreflood testEnvironmentally friendlyEasy residual analysis by ICP, HPLC and hyamine methods This paper will give a comprehensive study of developing environmentally friendly calcium carbonate scale inhibitors for squeeze application for HTHP wells in the oil and gas fields, which includes thermally stability, dynamic scale loop performance, adsorption and desorption performance, compatibility, residual analysis and environmental regulation.