COMPOSITIONS AND TECHNOLOGIES FOR IMPROVED OIL RECOVERY AND TREATMENT BOTTOM-HOLE ZONE Technology for combined treatment of the reservoir on the basis of surfactant compositions (SNPCH-95M) Technology for treatment of producing wells applying the reagents SNPCH-9630 and SNPCH-9633 Recovery of injection well injectivity employing surfactant composition Technology for increase of productivity of producing wells or injectivity of injection wells Hydrocarbon-base surfactant compounds for treating the oil reservoir through the injection wells Technological fluid of SNPCH-3100 type Composition SNPCH-9030 for combined treatment of formation zone close to the well Inhibited hydrochloric acid for the oil industry (SNPCH-HCLI) Acid corrosion inhibitors of SNPCH-6500 type Technology for killing wells under abnormal geological conditions Technology for application of fiber-dispersion system (FDS) for improved oil recovery Technology for stimulation of hard- recoverable oil production Technology for isolation of injected water inflow using polymer-dispersion-filled system (PDFS) Technology for improved oil recovery at the later stage of oil field development using polymer-dispersion systems Technology for application of polymer-dispersion systems (PDS) with stabilizing agents Petroleum bitumen product and methods for improved oil recovery using it Ecologically safe method for the oil reservoir development using suspension of fine-dispersed minerals activated by grinding Technology for reservoir treatment using the composition based on alkali wastes of caprolactam production and hydrochloric acid Technology for oil reservoir development based on alkali wastes of caprolactam production and aqueous solutions of polyvalent cations Composition for increased productive rate of low producing wells (SNPCH-9010) Method of testing fluids in porous media TECHNOLOGY FOR COMBINED TREATMENT OF THE RESERVOIR ON THE BASIS OF SURFACTANT COMPOSITIONS (SNPCH-95M) The technology SNPCH-95M has been used for increased oil recovery during conventional waterflooding under the conditions of the heterogeneous reservoirs, high mineralization of formation and injected water and water content of produced fluids (60-90%). The technology involves the successive injection of the blocking and oil-driving working agents of polymer-dispersion system and surfactant composition. The application of the method provides: decrease of the flushed zones’ permeability and levelling of displacement front of flooding fluid; improvement of oil-driving properties of water in the unswept low-permeability zones. The approximate volume of the injected polymer-dispersion system is 200 m3 per 1 m of the perforated formation thickness but not more than 1200 m3 per 1 well treatment; the approximate volume of the aqueous dispersion of surfactant composition is 50-150m3 per 1 m of the perforated formation thickness but not more than 400 m3 per 1 well treatment. The surfactant composition is produced as a concentrate deluted with water to required concentration on site. Several grades of the reagent SNPCH-95 having varied composition have been developed and used under the varied geological and physical conditions and with injected waters having varied mineralization. All grades have good rheological characteristics, they are homogeneous and stable over the temperature range of -5 - +30°C for a long period of time. The technology has been tested in Romashkino oil field in Tatarstan. 5 injections have been made in 1987-1989. 52,2 thousand tons of incremental oil was recovered. On the average the action has been efficient for 3,5 years. The efficiency of the method was 78% in 32 zones treated in 1994-2001. More than 3 thousand tones of incremental oil has been recovered per 1 well treatment the period of action averaging 27 months. The action continues in 11 zones.    TECHNOLOGY FOR TREATMENT OF PRODUCING WELLS APPLYING THE REAGENTS SNPCH-9630 AND SNPCH-9633 The technology is used for reducing water content of produced fluids and increasing oil production rate from the carbonate and terrigenous reservoirs having high water content of produced fluids (60-99%), low reservoir temperature (15-50°C) and varied mineralization of waters flooding the well (15-300 g/l). The method is based on plugging of the water-saturated formation zones with high-viscosity emulsions formed in a process of injection of hydrocarbon-base surfactant compound (SNPCH-9630 and SNPCH-9633). The emulsions formed in the flushed formation zones are resistant to watering and decompose being in contact with oil. It provides high selectivity of the method and doesn’t decrease permeability of the oil-saturated layers. Besides, the reagents have water-repellent effect, they are capable of dissolving and dispersing ARPD and reducing oil viscosity. Different grades of the reagents SNPCH-9630 and SNPCH-9633 having varied composition have been developed. The grade of the reagent is selected depending on the geological and physical conditions of the selected reservoirs. The reagents are homogeneous and stable over the temperature range of -35°C- +35°C for a long period of time, they have low viscosity (1,5-3 mPa·s) and pour point (below minus 600°С). The reagents are low-toxic and fall into the 4th and 3d class of hazard. They are authorized to be applied in the oil industry. The technology comprises the injection of 1-3 m3 of the reagent per 1m of the working (perforated) formation zone. The slug is squeezed into the formation with water. The well has been kept for control for 24-48 hours and then is put on production. The reagent can be injected without pulling the equipment out. The technology has been successfully tested in the carbonate and terrigenous reservoirs in the oil fields of Tatarstan, Perm region, Bashkortostan and Udmurtia (about 300 wells were treated): efficiency of treatment is 57-85%; the action has been efficient for 1-2 years and even more; incremental oil production is more than 20-90 t per 1t of the reagent or 500-1300 t per 1 well treatment when water production reduces by 400-8000 t per 1 well treatment.    RECOVERY OF INJECTION WELL INJECTIVITY EMPLOYING SURFACTANT COMPOSITION The technology is used for recovery of the injection well injectivity under the conditions of the heterogeneous formations having varied mineralization of formation and injected waters and formation temperature 20-100°C. The method is based on the ability of the aqueous-base surfactant solution to remove contaminations, water-oil emulsions and asphalt-resin-paraffin deposits from the bottom-hole formation zone. The reagent can be prepared from the starting components or by diluting surfactant compound concentrate with injected water directly in the oil field. Several grades of the surfactant compounds have been developed. The composition of the compound or its concentrate depends on the conditions for application and is selected depending on the geological and physical conditions of the specific reservoirs. Viscosity of the compound solution doesn’t exceed 5 mPa·s and viscosity of the concentrate ranges from 40 mPa·s to 150 mPa·s at 20°C depending on the composition and content of active base. The reagent is low-toxic and falls into the 4-th class of hazard. The reagent is homogeneous and stable over the temperature range of -5 - +30°C. It is authorized to be applied in the oil industry. The technology for the reagent application comprises the injection of 3-15 m3 of the surfactant compound solution per 1 m of the working formation zone. The slug is driven by injected water into the formation. The pilot field tests carried out in the oil fields of Tatarstan and West Siberia verified that injectivity of the injection wells increased 1.3-2.0 times and in addition, productivity increased 1.5-2 times. The action is efficient not less than a year.    TECHNOLOGY FOR INCREASE OF PRODUCTIVITY OF PRODUCING WELLS OR INJECTIVITY OF INJECTION WELLS The technology is used for improving the factors of the development of the oil pools having the heterogeneous carbonate and terrigenous reservoirs at formation temperature of 20-60°C. The method is based on an increase of the efficiency of acid treatment by the preliminary temporary plugging of the high permeability zones. The permeable zones are plugged employing viscous emulsion jelly-like systems. The systems form by mixing successively injected slugs of hydrocarbon-base surfactant compounds and hydrochloric or mud acid. The acid travels not into the high permeability zones but into the oil-saturated low permeability zones. When the acid reacts with formation rock and its activity decreases the resistance and viscosity of the emulsion systems drastically reduce recovering permeability of the plugged zones. Variation of the surfactant compound composition allows to carry out the directed acid treatments in combination with not temporary but complete plugging of the high permeability water-saturated formation zones. Several grades of the surfactant compounds varying in composition have been developed. The grade of the reagent is selected depending on the geological and physical conditions of the productive formations. The reagents are homogeneous and stable over the temperature range of -35 to +35°C for a long period of time, they have low viscosity (1,5÷3 mPa·s) and pour point (below - 60°C). The reagents are low-toxic (fall into the 4th and 3d class of hazard). They are authorized to be employed in the oil industry. The technology comprises the injection of the surfactant compound and acid in amount of 1-3 m3 and 0,5-2 m3 per 1m of the net productive section, respectively. The slugs are driven by water and the well has been kept for control for 24-48 hours and then is put on production. The method was tested in 23 wells drilled in the terrigenous and carbonate reservoirs in the oil fields of Tatarstan in 1992-2001. About 800 t of incremental oil was produced per 1 well treatment when water production reduced by more than 2000 t. The action continues in 3 wells.    HYDROCARBON-BASE SURFACTANT COMPOUNDS FOR TREATING THE OIL RESERVOIR THROUGH THE INJECTION WELLS The technology based on solvents and surfactant compounds has been used for improving the factors of the oil field development under the conditions of the heterogeneous reservoirs having varied mineralization of formation and injected water and high water content of produced fluids. The method is based on the ability of the reagents "hydrocarbon solvent - surfactant compound- mineralized water" to form viscous stable gelatinous emulsions having external hydrocarbon phase over the temperature range of 20 - 50°С. The method comprises injection of 1-3 m3 of hydrocarbon-base surfactant compound (SNPCH-9630, SNPCH-9633) per 1 m of drilled oil reservoir thickness (but not less than 35 m3) followed by squeeze of reagent slug into the formation using mineralized water. When the reagents' slugs mix with formation and injected mineralized water they form viscous system promoting filtration redistribution and levelling of displacement front in the injection wells finally reducing water content of produced fluids and increasing oil production rate in the producing wells. Besides, the reagents have water-repellent effect; they are capable of dissolving and dispersing ARPD and decreasing oil viscosity. Several modifications (grades) of the reagents SNPCH-9630 and SNPCH-9633 have been produced. They have varied composition adapting the method for a wide range of the geological and physical conditions. The surfactant compound solutions have low pour point ( below minus 60°C), low viscosity (1,5-3,0 mPa·s) and they are stable and homogeneous over the wide temperature range (-35°C - +50°С) for a long period of time (more than a year). The pilot tests of the technology carried out in the Devonian reservoirs in 1995-2001verified good prospects for it. 46,7 thousand tons of incremental oil or about 1,7 thousand tons of oil per 1 well treatment has been produced in 28 pilot zones. The action continues in 7 wells.    TECHNOLOGICAL FLUID OF SNPCH-3100 TYPE The fluid of SNPCH-3100 type is applied for killing the producing and injection wells before well servicing and workover. SNPCH-3100 is manufactured as per Specification ТУ-39-0576570-ОП-210-95. The modifications of the technological fluid having the following technical characteristics have been developed for the various climatic and geological-and-physical conditions.   SNPCH-3110 SNPCH-3110А SNPCH-3120 SNPCH-3120А SNPCH-3130 Density, кg/м3 1350-1360 1410-1450 1240-1250 1260-1280 1290-1300 Relative filterability* 0,007 0,007 0,004 0,008 0,006 Pour point, °С -25 -38 -35 -38 -30 Viscosity, cs 35-50 20-40 25-40 30-50 26-50 Concentration of Н+ ions, рН 6-7 6-7 6-7 6-7 6-7 * "Relative filterability" is a relation of SNPCH-3100 filtration and filtration of calcium chloride solution determined in BM-6 device The application of the fluid of SNPCH-3100 type provides: keeping of reservoir properties in killing and low flow rate of the reagent by insufficient penetration into the formation; control of fluid density by dilution with saline water having specified mineralization and varied mineral and salt composition; repeated use of the fluid; killing of the wells with abnormal intake or high gas factor when the special technological methods are employed or the chemical modifiers are added. The technological fluid of SNPCH-3100 type is non-flammable, noncorrosive and low toxic (4th class of hazard). It is delivered in tank cars. Various grades of SNPCH-3100 type have been widely tested in Tatarstan, Bashkortostan, Republic of Komi and West Siberia. The technological effect of SNPCH-3100 application averages 240 t of oil per 1 well by reducing the time of well start and completion. The operation conditions are restored within a day while the well productivity retained after workover. The experts have all engineering specifications required on the composition and technology for its application under the various geological and field conditions.    COMPOSITION SNPCH-9030 for combined treatment of formation zone close to the well The composition SNPCH-9030 is used for increased productive capacity of the wells operating in the formations having low permeability reservoirs. They reduce their productive capacity because of the secondary technogenic contamination of the bottom-hole formation zone (penetration of drilling mud and mechanical impurities) as well as for completion of the drilled wells. 3 grades of SNPCH-9030: A, B and V used for various mineralogical reservoir composition and well category have been produced according to the specification (ТУ 39-05765670-ОП-231-97). The efficiency of applying the composition SNPCH-9030 is achieved by using the functionally designed components of the composition dissolving and dispersing aluminosilicate rock component without forming the secondary deposits and preventing formation of viscous acid emulsions in the bottom-hole formation zone during its treatment. Besides, the organic solvent and surfactant remove organic contamination of ARPD type from porous medium. The combined action of SNPCH-9030 makes additional operations for washing the formation zone close to the well using some types of the reagents unnecessary shortening the operation period and reducing net cost of treatment. The composition SNPCH-9030 has been used in the largest oil companies of the Russian Federation. It is delivered in the special tank cars. It is reasonable to select the composition grade and to apply it using services of the composition and technology developers. The composition was patented, patent of the Russian Federation No. 2100587.    INHIBITED HYDROCHLORIC ACID FOR THE OIL INDUSTRY (SNPCH-HCLi) NIIneftepromchim developed the composition and technical documentation for inhibited hydrochloric acid on the basis of hydrochloric acid produced by Cheboksar JSC "Chimprom". 2 grades of inhibited hydrochloric acid: A and B have been produced. In quality characteristics the inhibited hydrochloric acid meets the requirements specified in the oil industry.   grade A grade B Appearance dark liquid Mass weight of HCL,%, not more than 22-25 20-25 Mass weight of acetic acid, % - 0,9-1,1 Mass weight of ferrum, %, not more than 0,03 0,03 Corrosion rate of Steel Ст3, not more than, g/m2 hour 0,20 0,20 The inhibited hydrochloric acid has been authorized to be applied in the oil industry, it falls into the 3d class of hazard. The inhibitors of SNPCH-6500 type are added to acid for reducing acid corrosion. The reagent is used in various oil regions: West Siberia, Tatarstan and Bashkortostan. The inhibited hydrochloric acid is delivered by NIIneftepromchim. Delivery: tank car.    ACID CORROSION INHIBITORS OF SNPCH-6500 TYPE Hydrochloric acid and mixtures of hydrochloric and hydrofluoric (mud acid) acids are one of the most common reagents used in the chemical industry for stimulation of oil production (deep treatment of the bottom-hole formation zone), repairs in the wells as well as for using in other industries. The acids contact with metal constructions - pipes, reservoirs and pumping equipment exposed to severe acid corrosion during application of the acids in the wells as well as storage and transportaton. The most effective and economical method for reducing corrosiveness of hydrochloric acid is its inhibition by injecting the special reagents - inhibitors having pronounced ability to reduce metal corrosion during some period. The corrosion inhibitors of SNPCH-6500 type are used for reducing acid corrosion caused by contact of hydrochloric acid and mixture of hydrochloric and hydrofluoric acids with ferrous metal. The inhibitors can be injected into the acid in the enterprise delivering it to the customers or in the plants for reagents’ preparation for oil production immediately before acid application. Two grades of the acid corrosion inhibitor: SNPCH-6501A and SNPCH-6502D have been produced taking into account the geological and physical characteristics of the formation and applied acids. Characteristics   SNPCH-6501А SNPCH-6502 D Appearance dark liquid Density at 20°С, kg/m3 965-1030 990-1020 Corrosion rate of Steel Ст3, not more than, g/m2 hour, not more than 0,20 0,20 Pour point, °С -30 -55 The corrosion inhibitors SNPCH-6501A and SNPCH-6502D have been delivered in steel or plastic drums in tank cars.    TECHNOLOGY FOR KILLING WELLS UNDER ABNORMAL GEOLOGICAL CONDITIONS The technology is used for killing the producing and injection wells operating in the abnormal intake beds having permeability more than 1 mcm2 (because of high porosity and fractures) and abnormally high formation pressure or gas factor. The well is killed by substituting well fluid for technological fluid of SNPCH-3100 type (plugging fluid) of the suitable grade into which the specially selected modifying additive - wood flour is added and for displacing fluid the density of which is less than the density of plugging fluid. SNPCH-3100 and modifier are selected taking into account the geological and physical characteristics of the reservoirs, the method of well operation and technical condition of the underground field equipment. The density of the reagent with the modifier may range from 1250 to 1500 kg/m3 and conventional viscosity may range from 10 to 100 s (on VZ - 246) depending on the grade of original SNPCH-3100 and modifier’s content. The efficiency of the killing technology application is achieved by plugging the perforated interval when well fluid is substituted for plugging fluid and part of this fluid is squeezed into the reservoir zone close to the well. The amount of the plugging fluid SNPCH-3100 is specified on the basis of the well productivity factor. The use of the technology for killing applying the modified technological fluid of SNPCH-3100 type provides: effective and rapid killing of wells and their subsequent completion; small chemicals’ consumption and preservation of reservoir properties; solation of the abnormal intake zones simultaneously with killing in the reservoirs of fractured and cavern type; A wide choice of ecologically safe raw materials is available for use of the technology. The technology was patented and tested in JSC "Surgutneftegas".    TECHNOLOGY FOR APPLICATION OF FIBER-DISPERSION SYSTEM (FDS) FOR IMPROVED OIL RECOVERY The technology is used for improved oil recovery from the high-watered heterogeneous reservoirs by an increase of the reservoir sweep. The effect is achieved by sweeping the unswept low-permeability  zones. The technology involves the successive-alternate injection of the medium-volume slug (700-1000 m3) of the aqueous suspensions of wood flour and clay powder into the reservoir. Interaction of slug components in the reservoir results in formation of swelling system stable against watering which increases filtration resistance of the watered high-permeability zones. FDS is not subjected to the attack of formation microflora and it doesn't promote its development. It is used as a bactericide for sulfate reducing bacteria. Under the specific geological and field conditions the technology can be implemented by applying only aqueous suspension of wood flour having suitable dispersion ability. In 1992-2000 the technology has been tested and used in 489 areas of 14 oil fields in West Siberia (Samotlorskoye, Zapadno-Surgutskoye, Lyantorskoye, Yuzhno-Yagunskoye etc.) and the Republic of Tatarstan. 2,187 mln. tons of incremental oil has been recovered. The specific technological efficiency ranged from 1,5 to 24,2 thousand tons of incremental oil per 1 treatment in the separate areas, the action has been efficient for 1-4 years and efficiency of treatment was 90%. FDS is economically viable means for improved oil recovery. The expenses for implementation of the technology have been paid for themselves within three-four months. The technology has been tested for the simultaneous mass effect on the separate oil zones by FDS injection into the high-pressure lines of the repressuring system. The technology is efficient for any water salinity when the reservoir temperature is up to 300°C. The technology is particularly effective for the fractured-cavernous-porous terrigenous reservoirs water content of produced fluids exceeding 90%. A wide choice of the cheap and ecologically safe raw materials is available for use of the technology. The technology was patented and it is provided with the standard and technical documentation.    TECHNOLOGY FOR STIMULATION OF HARD-RECOVERABLE OIL PRODUCTION The technology is used for increased production rate of producing wells or injectivity of injection wells operating in the low-permeability terrigeneous reservoirs and for primary well completion. The technology is used by combining physical and chemical treatment of the reservoir applying the reagents for various functional purpose or the composition of combined action SNPCH-9030 (ТУ 39-05765670-011-231-97) and depression method for recovery of waste reagents with contaminants and destructed rock particles. The efficiency is achieved by deep treatment of the bottom-hole formation zone changing the structure of the pore space providing good hydrodynamic communication of the formation and well. The most efficient is application of the technology in one hydrodynamically communicating area having injection well and producing wells. Oil production rate can increase up to 10 times by applying the technology. The technology has been used in the oil companies of West Siberia and Ural-Volga region. It is reasonable to test the technology under the new geological and field conditions with methodical and technological assistance of the technology developers. The method for applying the technology was patented, patent of the Russian Federation No. 2140531.    TECHNOLOGY FOR ISOLATION OF INJECTED WATER INFLOW USING POLYMER-DISPERSION-FILLED SYSTEM (PDFS) The technology for isolation of injected water inflow using polymer-dispersion-filled system is used for increased oil production by reducing water content of produced fluids. The technology is based on formation of extended water-isolating FDS barrier consisting of dispersion particles of wood flour and clay followed by its strengthening with polymer-dispersion-filled system (PDFS). PDFS is a cross-linking composition based on polyacrylamide, cross-linking agent, wood flour and water. The high structural and mechanical PDFS properties prevent removal of the reagents from the formation when the well is completed and operated after repair and isolation work providing high long-term effect. The technology has been tested in 48 producing wells in Fedorovskoye, Savuiskoye, Rodnikovskoye (JSC "Surgutneftegas"), Romashkinskoye (JSC "Tatneft"), Yuzhno-Yagunskoye and Povkhskoye (TPE "Kogalymneftegas") fields in 1995-2000. 60 thousand tons of incremental oil has been produced by treatment while water production reduced by 336,3 thousand tons. The average specific efficiency was 1258 t of incremental oil per 1 well treatment when the efficiency of treatment was 87%.    TECHNOLOGY FOR IMPROVED OIL RECOVERY AT THE LATER STAGE OF OIL FIELD DEVELOPMENT USING POLYMER-DISPERSION SYSTEMS PDS is a new highly efficient compound for improved oil recovery at the later stage of oil field development after the vast flushed zones have been formed in them. The technology is very simple and is based on the injection of rock suspensions and polymer solutions into the reservoir increasing filtration resistance of the watered zones in the oil- and water saturated reservoir and of sweep efficiency. The technology for PDS application has been tested and used in 1380 highly watered (up to 99%) areas of the oil fields having various physical and geological conditions. More than 5000 thousand tons of incremental oil was recovered. PDS is: up to 27 thousand tons of incremental oil per 1 treated area water content of produced fluids ranging from 90 to 99%; more than 4,5 thousand tons of incremental oil per 1 ton of injected polymer; 10-20 times excess of profit above expences. PDS application: sweeps the unswept layers with impaired reservoir properties; increases the sweep efficiency factor by 10-25%; increases oil recovery from the highly watered reservoirs at the later stage of their exploitation by 1,5-2,5%. PDS is a base for efficiency increase of the known physical and chemical methods for improved oil recovery. PDS modification using various reagents controls its properties over a wide range for solving the problems of improved oil recovery under the various geological and physical reservoir conditions.    TECHNOLOGY FOR APPLICATION OF POLYMER-DISPERSION SYSTEMS (PDS) WITH STABILIZING AGENTS The technology for treatment of the oil- and water saturated reservoir using PDS and the stabilizing agents (SPDS) is used for: improved oil recovery from the flooded heterogeneous reservoirs under the conditions of high water content of produced fluids of 80-99% at the later stage of exploitation of the oil fields, separate reservoirs and areas; restriction of high-pressure injected water inflow into the producing wells for increased oil recovery from the productive reservoirs; elimination of circulation in the injection wells having high productivity. SPDS has higher resistance and improved structural and mechanical characteristics. The stabilizing agents structurize the formed PDS floccula increasing the filtration resistance of the watered reservoir zones. The technology has been tested in the producing wells in the oil fields of West Siberia. SPDS application reduces water content of produced fluids from 96-99% by 5-20% and increases the oil production rate from 1,4-30 t/day up to 9,1-49 t/day. 2750 t of incremental oil was produced per a well while the action has been still efficient.   Water content, % Production rate of oil, t/day, before Production rate of oil, t/day, after Duration period of action, month Incremental oil production, thousand t 1 97 2,5 23,8 7 4,2 2 98 1,4 9,2 8 1,8 3 96 5,6 10,1 8 2,6 4 99 30,0 48,0 9 1,6 5 99 50,0 50,0 7 0,2    PETROLEUM BITUMEN PRODUCT AND METHODS FOR IMPROVED OIL RECOVERY USING IT A series of the highly efficient technologies for improved oil recovery using petroleum bitumen product by limiting the flushed zones’ conductivity in the developed areas and limiting inflow into the producing wells and by increased oil displacement has been developed. The petroleum bitumen product originates from the native bitumen under the conditions of intensive mixing at high temperature and pressure fluctuation. It is a composite mixture of hydrocarbons having varied structural group composition and their heteroderivatives having a wide range of the physical and chemical characteristics providing their stability and reactivity. Injection of the petroleum bitumen product into the watered formation increases the efficiency of oil dicplacement by means of several factors: the petroleum bitumen product forms stable emulsion when it interacts with water; the heavy fractions of the petroleum bitumen product tend to form dispersion system (0,78-1,56 mcm); asphaltenes of the petroleum bitumen product are the structurized two-dimensional laminated systems associating into 5-6 layer crystal-like structures having imperfect hexagonal and planar package of carbon atoms; micelles are the optimum oil-displacing agent because of their polarity and size comparable with the pore channels’ size. Besides, the production of the petroleum bitumen product doesn’t require import and expensive components giving an advantage over the compositions used today. The petroleum bitumen product was patented, the patent RF No. 2140529.    ECOLOGICALLY SAFE METHOD FOR THE OIL RESERVOIR DEVELOPMENT USING SUSPENSION OF FINE-DISPERSED MINERALS ACTIVATED BY GRINDING Oil is recovered from the formation by the alternate injection of the aqueous slugs of solids activated by grinding in suspension and the additives stabilizing the system under the conditions of the high-watered heterogeneous reservoirs, into the injection wells. The size of activated materials (required level of grinding) has been specified by the ratio: d>0,1Dp, where: d- average size of solids, mcm, Dp- average size of pore diameter, mcm. The mechanical activation has been made in the specially designed energy-intensive planetary activators-grinders the centrifugal force-gravity relation ranging from 20 to 40. Breadly mill (RSA) and its foreign analogues belong to this type of the grinders. The mechanical activation in the presence of the additives results in the variation of their physical and chemical characteristics by the penetration of metals into the amorphorized layers of grinded materials owing to the structural defects. The variation of the physical and chemical characteristics affects the efficiency of the magnetic and electrostatic separation, filtration, flocculation and other technological processes. When reacting with water such materials can release a large amount of atomic hydrogen which is an active reductant. The effect is achieved by sweeping the unswept low-permeability zones having mobile oil. The method is efficient for any salinity of formation water and reservoir temperature under the conditions of the fractured-porous reservoirs having varied permeability water content of produced fluids exceeding 80%. The technological efficiency in the pilot zone of Almetyevsk area in Romashkino oil field including 3 injection wells was 24939 tons of incremental oil. A wide choice of the cheap and ecologically safe raw materials is available for using the method. The technology was patented, the patent of RF No. 2116437.    TECHNOLOGY FOR RESERVOIR TREATMENT USING THE COMPOSITION BASED ON ALKALI WASTES OF CAPROLACTAM PRODUCTION AND HYDROCHLORIC ACID The technology based on alkali wastes and hydrochloric acid (AWCP) has been developed for treating the bottom-hole zone of the injection wells and improved oil recovery from the terrigenous and carbonate formations. The technology comprises the successive-alternate injection of AWCP and hydrochloric acid slugs of 12-24% concentration in 0,7-1,3:1 volume ratio at the rate of 5-10 m3 per 1 m of the productive formation thickness. The efficiency of the composition treatment is specified by the properties of its components. Thus, hydrochloric acid promotes dissolution and removal of the carbonate component and alkali wastes promote crystal and chemical reconstruction of clay substance losing interstratal water, large potassium and sodium cations and its swelling properties as a result of hydrolysis of organic carbon acid sodium salts involved in it. Testing of the composition before and after the interaction verified it by the highly efficient exclusion liquid chromatography and X-ray-diffraction analysis of the carbonate and clay component (for montmorillonite injected into the reservoir cleavage spacing of basal reflection reduces from 15,237 to 14,828A and for mixed-layer phase from 10,32 to 9,95A). The technology has been tested in the oil fields of West Siberia and Tatarstan. The technological efficiency was 2797 tons of incremental oil in West Siberia and 2005 tons of incremental oil in Tatarstan per 1 treatment. Duration of action is up to 2 years. The technology has been used employing the home equipment and chemical products which are cheap production wastes. The technology was patented, the patent of RF No. 1648108.    TECHNOLOGY FOR OIL RESERVOIR DEVELOPMENT BASED ON ALKALI WASTES OF CAPROLACTAM PRODUCTION AND AQUEOUS SOLUTIONS OF POLYVALENT CATIONS The technology for improved oil recovery from the heterogeneous terrigenous reservoirs being at the later stage of development and characterized by high water content of produced fluids and gradual decrease of oil recovery involves the sequential injection of the slugs of alkali wastes of caprolactam production (AWCP) and 5 - 25% solution of polyvalent cations in 1: (0,05-0,5) volume ratio. When the original components move through the reservoir conductivity of the flushed zones is limited by formation of deposit in a form of coagulation structures in porous medium. The deposit consists of polyvalent metals’ salts hydrolized in water and has high adsorption and adhesion properties. Colloid contamination particles available in injected water colliding with flocs of hydrolyzed salts adhere to them and form gel-dispersion system. The technology has been tested in the pilot zone of Central-Aznakayevo area of Romashkino oil field. As a result of the experiment the conditions of producing well operation changed affecting oil displacement - technological effect ranged from 50 to 150 tons of oil per 1 t of the injected reagent. The technology was patented, the patent of RF No. 1596845.    COMPOSITION FOR INCREASED PRODUCTIVE RATE OF LOW PRODUCING WELLS (SNPCH-9010) Composition having various modifications is used for increased productive rate of the low producing injection and producing wells operating in the carbonate reservoirs. Efficiency of application is provided by: increase of the formation active drainage range by partial dissolution of rock skeleton; removal of asphalt-resin-paraffin deposits, impurities and clay particles from pore channels. Characteristics Appearance homogeneous dark-brown liquid Dynamic viscosity @ 20°C, mPa·s not more than 5 Pour point, °C, not more than -30 Corrosiveness decrease for inhibited HCl (structural steel) 1,5-2 times The modification of the composition is selected depending on the reservoir temperature and type. The bottom-hole formation zone is treated using the standard oil-field equipment. The technological parameters of the process are selected depending on the geological and field characteristics of the treated wells. The composition has been tested in JSC "Tatneft", JSOC "Bashneft" and JSC "LUKoil-Permneft". The technological efficiency is more than 600-1000 t of incremental oil per a well. The daily incremental oil production rate is 1,3-3,5 t. The action has been efficient for 24 months. Efficiency of treatment is 86%.    METHOD OF TESTING FLUIDS IN POROUS MEDIA NIIneftepromchim carries out a group of laboratory tests using pulse nuclear magnetic resonance spectroscopy. We propose measurements without contact as they don’t break down structure of porous medium and fluids. You will have both qualitative and quantitative evaluation of porous medium as well as the process of fluid displacement and filtration. Highly-skilled scientists-chemists, physicists and experts in oil field development and petrophysics carry out the following forms of work: determination of porous medium characteristics (porosity, permeability, connate water content, oil saturation, viscosity and reservoir type); evaluation of porous medium structure variation, properties and distribution of fluids saturating it before, during and after water drive or displacement by various chemical reagents; study of physical and chemical processes in porous medium during the injection of chemically active reagents; study of kinetics of cross-linking, thickening and gelation (solidification) of chemical reagents in free space and porous medium; evaluation of effect of various chemical reagents applied or projected for application in the oil fields on the efficiency of demulsifiers, depressants, corrosion and paraffin inhibitors.