Search

The effect of calcium carbonate on drilling fluid densities after damage to the reservoir during the liquid flow was considered in the present paper. To test the initial / final permeability and fluid flow rate as well as the damage ratio, the damage tests have been completed and several Binghamian drilling formulation that were carefully prepared in the laboratory are used. Based on the obtained results, there is a minimal quantity of surfactant and the DR significantly changes beyond this limit. The drilling fluids containing 3 % of calcium carbonate and 2-3 % of the emulsifiers and wetting agent show a high flow pressure and display an immense damage ratio of about 43 %. It is also that these drilling fluids containing calcium carbonates provide the rheological properties close to those used in the field level. Such drilling fluids are stable over time, giving the yield stress between 5-10 Pa to allow the fluid flow.

A method of extracting natural gas from shale rock formations is hydraulic fracturing. The nearly water-based fracking fluid consists of cross-linking agents, mineral salts, pH-adjusting agents, and other components to control rheological behaviour. The fracturing fluid is pumped deep into a well at high pressure to crack the shale layer in order to access the natural gas. Once the fractures are formed, proppants, usually crystalline silica, keep them open, filling in the cracks created to allow the proper flow of hydrocarbons. This research explores the rheological properties of XLFC-1B polymer (gel-forming) and a borate complex (crosslinker XLW-56) as additives solutions, existing components used in hydraulic fracturing using local sands, including aoelian and quarries sands. Tests have shown that liquids exhibit viscoelastic behavior that allows them to hold the proppants and place them in fractures. It must also be established that these fluids ' minimal stress allows the liquid to flow.

Sand as proppants are synthetic or natural grains used for holding fractures open around the wellbore in the gas / oil well drilling industry to enhance fluid extraction after hydraulic fracturing. These proppant must have an ideal spherical shape with two values defined: roundness and sphericity. The supporting agent's other important characteristic is its solubility in acid. The acid solubility test determines a supporting agent's suitability for use in fracturing process where the supporting agent may come into contact with acids as well as the resistance to strength. The results shows that In all tests of sphericity and roundness dune sands proppants performed better than sand from the quarries. Also, results indicate that quarry sands are more solubility tolerant and do not exceed the 3% standard's criterion. Finally, we found that aoelian sands are resistant to the exerted stresses, except for one which has no good resistance to crushing.

The main objective of this study is focused on the mechanical preparation of Algerian crude feldspar with a view to extract the information about the comminution and the coloring iron rate distribution, on the one hand, and to remove the iron oxides, on the other hand, main impurities of crude feldspar by magnetic separation, flotation and more particularly by chemical leaching. In this process, the nitric acid and dithionite as reducing agent are used to replace sulfuric acid whose the application tests have yielded negative results. Research results shows that using a nitric acid in a reducing medium as ammonium bifluoride (HF,NH4F) process is effective and pushes the degree of iron oxides (Fe2O3) removal around 0.01\%. The hydro-metallurgical process applied especially to size fractions [-0.8 + 0.1] mm intended for the glass industry previously undergo a high intensity magnetic field reduces iron levels up to 0.054 \% with a yields in terms of weight of 58.32\% compared to those of all comers.