Control method of oil pool development
FIELD: oil and gas industry.
SUBSTANCE: according to the method a pool zone is selected with hydrodynamically related wells. Product is withdrawn from producers with production rate analysis. Displacement agent is injected to injectors, at that contour lines of wells mutual influence are defined and production rates of producers are corrected. Analysis of production rate for producers and displacement agent injection to injectors is based on detected interconnections of injectors with the respective producers against their total production rate. Real operation data is considered for the selected zones using historic data within the period from 1 up to 20 years with increment size of 1-3 months and current data for the time of optimization operations performance. By production rate control in the producers the volume of injection to the injectors is changed and redistributed considering impact of the respective producers and injectors. Total volume of injection is changed not more than per 10%. Cycles of withdrawal and pressure recovery at producers are regulated including time of cyclic forced product withdrawal during 2-3 months from producers with maintained or slightly increased water cut with further pressure recovery for these wells. At that remaining reserves are depleted using current stock of wells with increase in total production rate and decrease in total water production. Flows of fluid motion are redistributed till remaining oil reserves are depleted.
EFFECT: increasing oil recovery factor due to optimized operation modes for injectors and product withdrawal from producers.
4 dwg, 1 ex
The invention relates to the oil industry, in particular to methods of regulating the development of oil deposits, and can be used for automated selection of operating modes operating Fund of injection wells waterflood oil fields by reassigning agent injected into the formation and optimization of selection of products in production wells to reduce the water content and increase oil production.
A method of developing oil fields in the formation of a monolithic structure (patent RU №2386798, IPC EV 43/20, publ. 20.04.2010). This method includes drilling of wells, monitoring of the energy state of each well, water injection wells and extraction of oil from producing wells. According to the invention calculate the value of reservoir pressure for each of the production wells, corresponding to the planned extraction of oil in this well, in accordance with the analytical dependence. Then define the effective volume of water injection, assure the displacement of the fluid from the producing well count in accordance with the analytical dependence. Carry out the injection of water into each injection well in an amount equal to the sum of the effective injection volumes attributable to producing wells, located in W�not the impact of the injection wells. Thus stop or reduce the intensity of the current of fluid from the production wells or compensate for the volume of water accumulated in the selection of oil from producing wells, an equal volume of water pumped into injection wells.
The disadvantage of this method is that when the distribution of the energy state of each well there is no accounting for the interaction of adjacent injection and production wells included in the system development of operational object, and possible hydrodynamic links between them. Also no accounting done in the area of geological and technological measures of changing hydrodynamic interference between wells.
The closest to the proposed is a method of regulating the development of oil deposits (patent RU №2328592, IPC EV 43/16, publ. 10.07.2008). The known method provides increase of efficiency of development of oil reserves. The method involves extraction of oil from producing wells, water injection wells, maintaining the bottomhole pressure at the producing wells above the saturation pressure of oil gas and injection wells is below the pressure of hydraulic fracturing, the measurement of technological modes of wells. According to the invention using a geological model of the field perform the sweep flow rates of about�boron liquid, same on all producing wells, from a minimum flow rate with a fixed step increment of the flow rate of the fluid until the pressure on the bottom of wells equal to the saturation pressure of oil gas. Upon reaching the bottom of any producing well saturation pressure of oil gas the flow rate of the fluid is fixed and further testing will not change. Then at each step is sucient volume of water injection to maintain reservoir pressure in General, the object of development is taken equal volume of extracted fluid. The distribution of injection wells perform in proportion to the injectivity of the wells. On each step in the sweep of the flow of fluid producing wells define the contours plots of the interaction of the wells in each feature development of this field. Distribute in time the flow rate for each well for oil to reach 100% of irrigation wells - achieve the highest possible oil recovery factor than implement the optimal distribution of production rates of production and injection wells on the evaluation date.
The disadvantage of this method is that not taken into account deposits held at various technical measures for repair and maintenance of reservoir pressure maintenance system and production of changing hydrodynamic interference between wells. Selection Optim�found the volume of water injection to injection wells is carried out on plots with the same modes of extraction and discharge, which significantly reduces the scope for the implementation of the method requires a significant increase in the volume of water injection, which requires additional costs for pumping additional water volumes.
The technical task of the invention is the extension of the scope to different modes of injection and production wells, as well as reducing material costs, reducing the water content of produced fluids and increasing the oil recovery factor (CIN) due to selection of optimum modes of operation of injection wells included in the system of flooding throughout the oil reservoir or a separate area, and the redistribution selection of products from production wells with preservation of the compensation ratio injected into the formation fluid volume to be extracted from it products.
Technical problems are solved by method of regulating the development of oil deposits, including the allotment of land deposits with partially bound by wells, selection of products from production wells, injection of the displacing agent in injection wells with the definition of the contours of the wells interference and adjustment modes of injection of the displacing agent in injection wells without a significant increase in the volume of injection with the redistribution selection of iPod�tion between the producing wells.
What is new is that the analysis of the rates of producing wells and the injection of the displacing agent in injection wells is carried out based on the identified relationships of injection wells with the relevant mining wells total flow rate during actual operation on the selected sites using historical databases from one year to 20 years with step 1-3 months and current data during the optimization works, and adjustment of flow rates from production wells produced by varying the volume and the redistribution of injection in injection wells taking into account the mutual influence of the relevant production and injection wells, wherein the total injected volume change of not more than 10%, then produce the regulation of the cycles of the modes of selection and recovery of pressure in producing wells, including the selection of production from wells with persistent or slightly increasing water cut and pressure recovery in wells, depending on the speed of recovery of the pressure in the reservoir, changes in chemical and physical properties of formations and fluids, with remaining reserves produced using existing wells with increasing total flow rate and reduce the total water production and the flows of fluid motion to reallocate production OST�full-time oil reserves.
Fig. 1 (a, b) shows that producing 1, 2, 3 and outlet 4, 5, 6, 7 wells with schematic drawing of streamlines between them, on the bar chart presents the coefficients of mutual influence of these wells. Fig. 1 shows two time phases: a) before optimization; b) after optimization.
Fig. 2 shows a chart on the total production rate of oil production wells 1, 2, 3 (Fig. 1) as a result of various optimization measures in the injection wells 4, 5, 6, 7 (Fig. 1), which was able to increase the rate of recovery and reduce water cut (graph of changes of which are shown in Fig. 3) without increasing the volume of pumped fluid.
Method of oil pool development carried out with selection of optimal modes of operating Fund injection wells 4, 5, 6, 7 (Fig. 1) by analyzing waterflood as historical data on the development of the field and current during the optimization of the work and evaluate the effectiveness of the obtained modes of these injection wells. As a result automatically choose the optimum oil production rate of the possible modes of injection of the injection wells 4, 5, 6, 7 and the volumes of injection of the working agent that allows for the flow distribution of the fluid in the reservoir to reduce or maintain at the current level of Obvodnogo� (Fig. 3) the produced output and increase the rate of recovery (Fig. 2) in General, deposits or individual plot. The total injected volume remains almost unchanged (increased or decreased not more than 10%). For the selection of optimal methods of injection modes initially collect all necessary information from the available databases: the modes of wells 1-7, the volume of production and injection wells 1-7. On the basis of the collected information to produce the calculations of dependence of the volume of output of the wells from 1-3 modes of injection wells 4-7, determine the coefficients of the interaction. For a detailed analysis on the last time period is necessary to minimize step changes of the studied parameters. To do this, depending on the amount of information and accuracy is required analyze the recent history of development (from one year to 20 years) with the maximum allowable step 1-3 months. The calculation results of the dependency reveal the dynamic coupling between the discharge 4-7 and reactive extractive 1-3 wells. Changing modes of discharge, automatically selected the optimal injection volumes for injection wells, in which the specified conditions are met. As specified conditions in this case may be a decrease or maintain at the current level amounts�world water content of produced fluids and/or increase oil production. After the selection of modes of operation of injection wells is carried out optimization of the modes of operation in producing wells. Due to the redistribution of volumes of selected products is determined by the optimal mode for each producing well. Optimization is performed using automated software systems, which was conducted sensitivity analysis of water production on the magnitude of depression in the selection of fluids in producing wells. This was asked various limit regimes of the wells. Identified wells where a forced mode of operation led to decrease water production.
After evaluation of the geological structure of the areas of these wells were determined to have similar settings: high porosity and permeability, low reserves depletion, low watercut. To increase oil extraction has been proposed the following scheme of development of individual sections:
- according to the results of the sensitivity analysis are defined well, which can be applied forced mode selection;
- determined cycle of operation in the forced mode in 2-3 months, and then restoring the energy of the reservoir due to the increase of volume of injection in the injection wells during the same time interval;
- while working in �forsirovanno mode is determined from the response time of the wells and the rise time of the pressure in the reservoir;
- the recovery time, in which all production wells operate in the normal mode is determined by the speed of recovery of the pressure in the reservoir, changes in chemical and physical properties of reservoirs and of fluids caused by various activities of increasing oil recovery during the development of the field.
During cyclic accelerated selection and optimal waterflood produced analysis and correction time modes of production wells.
A positive result of the proposed activities is achieved through the flow distribution of fluid motion in the reservoir and production of residual oil reserves.
An example of a specific implementation of this method of oil pool development on the site of Berezovskaya area of the Romashkinskoye field
Fig. 1 (a, b) shows a diagram of the flooding of the selected section of the field where applied optimal method in the analysis of historical data in the system of production and discharge of correlation between wells 1-7. The scheme in Fig. 1 (a, b) is true for each cycle of flooding and selection. For optimal modes of injection in the injection wells is necessary to make a number of technical and computer activities. Selected an area of the reservoir on which to optimize on having produced�existing wells 1, 2, 3 had the effect of discharge 5, 6, 7 with pumping volume 5000 m3a month. In order to increase the total oil production rate for wells 1, 2 and 3 (65 tons per day) and not to increase the water content above 63% on this site, was analyzed interaction of wells for 12 years with a step of one month (from 01.01.2000 to 01.01.2012). Resulting coefficients of mutual influence between each wells 1-3 and 4-7 (modes of operation of wells 1-7, the volume of production and injection wells 1-7) and selected the best possible ways of modes of injection in the injection wells 4-7. The coefficients of mutual influence of wells 1-3 and 4-7 were determined by known methods (A. S. Lisin Calculation of the coefficients of mutual influence of wells by the method of nets) from the originally collected together the necessary information from the available databases: the modes of wells 1-7, the volume of production and injection wells 1-7, based on existing adapted on the history of development and the pressures of geological and hydrodynamic models of oil deposits (response time, bottom hole and reservoir pressure, replacement of production by injection). Based on the above, for a given phase is defined by the response time of both technical and calculated hydrodynamic methods, and it is from 30 to 90 days. On the basis of the collected information was calculated every� volumes of output of the wells on the operation modes of injection wells to the coefficients of interaction for the selection of optimal methods modes of injection in wells 4-7.
Before the change of modes of injection in wells 4, 5, 6, 7 optimized versions of injection wells were tested in projections of geological and hydrodynamic models. As a result of hydrodynamic calculations control the quality of the proposed activities, estimated economic efficiency. Also updated information on the results of hydrodynamic modeling can be used as input for further optimization calculations.
In the graphs displayed the total production rate (Fig. 2) mined production and total water content (Fig. 3) for the 1st cycle of flooding and selection, which shows the curves I, II, III, the corresponding changes of the total production rates (Fig. 2) and water production (Fig. 3) for different modes of production from wells 1-3 and discharge in wells 4-7 of the displacing agent (water). I is a curve of output change (Fig. 2) and water production (Fig. 3) during the development of this site without changing modes of injection in wells 4-7 (Fig. 1); II is the calculated curve of output change (Fig. 2) and water production (Fig. 3) during the development of the chosen site with the changing modes of injection in wells 4-7 (Fig. 1) the closest analogue; III is a graph of flow rate (Fig. 2) and water production (Fig. 3) changing modes of injection and re�the distribution in wells 4-7 (Fig. 1) no practical change in total volume (not more than 10%) and selection for wells 1-3 (Fig. 1) with the coefficients of the interaction; IV - schedule of changes in the actual flow-rate (Fig. 2) and water production (Fig. 3) in the development of the site with all optimization recommendations.
Fig. 2 shows the total oil production rate at the site under different optimization methods of injection for four months with forecasts for the next two months. If you do not apply these optimal methods, the oil production rate will decrease (curve I) and for three consecutive months will be reduced from 64 to 56 tonnes, with focus on the first method, the flow rate of oil (curve II) will be maintained at the level of 71 tonnes. When using the optimization method described in the closest analogue, the flow rate will first increase, and then will decline from 71 to 65 tonnes. The changes in the total production of oil on the plot shows the curve III: after the optimization works on injection wells production rate increased from 64,4 to 71.4 tonnes per day at a lower cost injection
Fig. 3 shows that the choice of optimum modes of discharge, on the contrary, the water content decreases (curve II) from 61 to 59%, and is not growing (curve I) from 61 to 63%, if not use the best ways. Curve III shows the reduction of water content from 63 to 60.5% at choice�e optimization mode on the injection in the injection wells 4, 5, 6, 7 and intensify selection for producing 1, 2, 3 (Fig. 1). Curve IV (Fig. 3) demonstrates the result of reduction of water content at the expense of practical application of optimization actions.
In optimal mode (see curve III in Fig. 2 and 3) on the section (Fig. 16) to increase the oil production rate has been changed, the volume of the injection in wells 5, 6, 7. Well 5 injected volume reduced from 1400 to 1000 m3/month. The volume of injection at the well 6 remained unchanged - at the level of 2000 m3per month, and the well 7 enhanced download from 1600 to 2000 m3per month and includes the previously derived in cycle mode the bore 4 with the pumping volume 600 m3/month. The total cumulative volume of injected and produced fluid remains within the predetermined limits of 5000-5500 m3per month.
After the selection of modes of operation of injection wells 4, 5, 6, 7 (Fig. 1B) produce optimized modes of operation in producing wells. Due to the redistribution of volumes of selected products to determine the optimal operation mode for each producing well 1, 2, 3 (Fig. 1B). Optimization is performed using automated software systems. They determine the ineffective production wells. These include high water-cut or quick watering hole. In these wells reduces the product selection down to a complete stop. Not�tabnanny volume of production is compensated for by increasing the auditions for the other wells so the compensation ratio of production of injection remained at the current level.
Preliminary estimates showed that on the basis of identified in the previous phase of operation modes of injection wells more rapid flooding of the well 1 (Fig. 1A) compared to the borehole 2. For a more uniform development of reserves were reallocated volumes of mining production between wells. For this purpose, the well 1 (Fig. 1B) the liquid has reduced by 30% (from 26 to 18 m3/day), and in borehole 2 (Fig. 1B) offset the decline in production from the well 1 (Fig. 1A) increased from 8 to 16 m3/day. Under these conditions, depletion of reserves was carried out more evenly with a gradual increase of water content on selected wells. When redistribution of volumes of produced fluids between wells 10 and 50%, the uniformity of development of reserves was not achieved due to the rapid flooding of the wells.
For well 3 (Fig. 1B) it was decided to leave the previous regimes.
As a result, after the real event, the total flow rate of oil phase increased from 64,4 72 t/day (see curve IV in Fig. 2), the total water content decreased from 63 to 60.3% (see curve IV in Fig. 3), which practically corresponds to the calculated data.
Then, given the response time of producing wells 1, 2, 3 (Fig. ), comprising from 56 to 94 days and the recovery time pressure at the end of the intensive selection process, it was decided to create such a regime of discharge and optimization of selection, which would create a cycle of 93 days of intense selection and 87 days later restoration of the pressure in the reservoir (Fig. 4A). This mode of operation wells gives the greatest effect to increase oil production and reduce water cut.
The number of injection and production wells may be different. It is determined by their interaction. Analysis of changes in the interactions of land with a large number of wells is carried out in automatic mode with the help of computational tools.
The proposed method is essentially a physical method of increasing the oil recovery and reduce water cut in production wells by 12-17% (Fig. 4A), and the flow rate of oil wells to increase by 10-15% (Fig. 4B) without additional costs for the refurbishment of wells and increased pumping. The use control method of oil pool development and effectively at sites with different conditions.
Method of regulating the development of oil deposits, including the selection of field site with hydrodynamically linked wells, selection of products from production wells with analysis by flow rate, sakac�the displacing agent in injection wells with the definition of the contours of the interaction of the wells and the adjustment of rates of producing wells, characterized in that the analysis of the rates of producing wells and the injection of the displacing agent in injection wells is carried out based on the identified relationships of injection wells with the relevant mining wells total flow rate during actual operation on the selected sites using historical databases from one year to 20 years with a step of 1 to 3 months and current data during the optimization works, and adjustment of flow rates from production wells produced by varying the volume and the redistribution of injection in injection wells taking into account the mutual influence of the relevant production and injection wells, wherein the total injected volume change of not more than 10%, then produce the regulation of the cycles of the modes of selection and recovery of pressure in producing wells, including the cyclic time of the forced selection of products within 2-3 months from the production wells with persistent or slightly rising water cuts followed by reduction of the pressure in these wells, with remaining reserves produced using existing wells with increasing total flow rate and the decrease of the total water production and the flows of fluid motion to reallocate residual oil reserves.
FIELD: oil and gas industry.
SUBSTANCE: in the method for development of dome oil formation at last operational stage extraction of the product is made through producers and working fluid is injected through injectors. Local area of the deposit is selected according to difference of hypsometric depths between the producer and injector per 3 m and more. In the producer standard downhole pumping equipment is replaced by downhole pumping equipment operable on round-the-clock basis. When change in water cut per 10-15% is detected volume of extracted product is limited due to change in operation time of round-the-clock downhole pumping equipment. At that at the injector area injection is limited or the well is shut in completely. Periodic measurements are made for water cut changes in operation mode of the producer. When water cut is reduced operation is continued in elastic drive without start-up of the influencing injector. Periodic measurements of water cut and bottomhole pressure are repeated for the producer. When bottomhole pressure is reduced per 5% and more in regard to the initial measured value the injector operation is started and change in the main parameters of water cut and bottomhole pressure is controlled in the producers.
EFFECT: higher oil recovery of the deposit.
FIELD: oil and gas industry.
SUBSTANCE: during development of multilayer oil deposit working fluid is injected through injectors with common well screen. Extraction of the reservoir product through producers is also performed with common well screen. The upper layer is developed in the mode of injection to withdrawal ratio by injection of working fluid at discharge pressure according to injectivity of the stratum. A pit is arranged close to the injector and working fluid is pumped through this pit to the injector with increased injection pressure sufficient for entry of working fluid both to the upper and lower strata. Producers are operated in the mode of permanent bottomhole pressure. Upon reaction of the producers to increased pressure of working fluid injection the development is continued in the mode of injection to withdrawal ratio by injection of working fluid. Injection to withdrawal ration is redistributed for two strata simultaneously from producers with high water cut and high bottomhole pressure to producers with low water cut and low bottomhole pressure. For this purpose at producers with increasing water cut operation time of pumping equipment is reduced at permanent bottomhole pressure. At producers with low water cut operation time of pumping equipment is increased at permanent bottomhole pressure.
EFFECT: improving oil recovery of the deposit.
FIELD: oil and gas industry.
SUBSTANCE: according to the method geophysical survey of exploratory wells is performed by crossed dipole shear sonic imager. Oriented core is selected with further determination of directions of natural fracturing. Regional directions in maximum stress of oil-saturated rock are defined. According to findings injectors are placed along the regional directions in maximum stress. Producers are placed in between injectors thus forming developing method. Part of injectors occurred in fault zones and closer than 200m is introduced into operation as producers with their further transfer to injectors. When watering is higher than break even point and when it is required to maintain reservoir pressure at the deposit producers are transferred to injectors. Transfer of wells is made so that they form rows of injectors step by step along regional directions in maximum stress of oil-saturated rock and provide even oil displacement.
EFFECT: increased reservoir recovery due to more efficient and sound placement of well pattern within the area of oil deposit considering tectonic and geomechanic conditions of pay rocks occurring.
3 cl, 3 tbl, 8 dwg
FIELD: oil and gas industry.
SUBSTANCE: group of inventions relates to the field of oil industry and can be used for enhanced oil recovery of the reservoir in the development of water-flooded reservoirs with viscous oil and bitumen at a late stage of development. The method comprises opening the reservoir with the ability to transfer the production well into the injection one, the reservoir processing, keeping the hole without any influence, intake of oil from the reservoir. At that a system of microwave electromagnetic generators with radiation frequency of 2.5 GHz is lowered into the injection well, connected to the slot antenna using the feeder. The length of the slot antenna is selected equal to the thickness of the aquifer of the reservoir. In the mode of injection, the water injection into the reservoir is carried out with simultaneous influence on the reservoir with microwave electromagnetic field, the radiation power is determined by the time of heating of the water injected in the downhole to the desired temperature. When filling 5-10% of the volume of the pore space of the formation, the well is maintained, the well is transferred into the production well, and the liquid intake from the production well is carried out.
EFFECT: increase of the effectiveness and economical efficiency of development of water-flooded reservoirs of high-viscosity oil, intensification of oil production in water-flooded reservoirs of high-viscosity oil by increasing the coverage with influence to the reservoir with heating in the bottomhole area of the reservoir of the production wells.
2 cl, 3 dwg
FIELD: oil and gas industry.
SUBSTANCE: under this method the field is drilled according to row system with triangle grid of wells. Work agent is injected in the injection wells. Oil production is performed from production wells. At initial stage of the field development the production reservoir is presented by two horizons, if divided by central separating row of injecting wells with spacing between wells at least 300 m. Central separating row is arranged along line of maximum pay structure, the injection wells in it are made with opening by common filter of the both horizons. The closest first row of the production wells is drilled at distanced from the central row at least 500 m. Other areas of the reservoir are drilled with spacing between wells 300-400 m. After injection of the central row of the injection wells to 0.4-0.7 unit fractions of the pore volume to nearest rows of the production wells at least 90% wells of the central row are shutdown. After oil withdrawal at the entire field to 90% of initial oil productive capacity between the central separating row of the injection wells and nearest row of the production wells the sealing row of the production wells is drilled. Wells of the central row are switched to production at top horizon. During watering of the production wells of the first row to 98% they are switched to water injection.
EFFECT: increased oil recovery factor of the field.
2 ex, 2 dwg
FIELD: oil and gas industry.
SUBSTANCE: under method the first device is installed in the horizontal well. Firth fluid is injected in the first horizontal well via the first device. HCs production is ensured from the second horizontal well under the first well. Second fluid is injected to the third well shifted to side from the first and second wells to displace fluids in the reservoir to the second well. At that HC production from the second well is continued. Hydraulic connection is ensured between the first, the second and the third wells. Pressure in the first well is increased using the second fluid injected to the third well. First well is closed when its pressure is increased by the second fluid to pressure sufficient to displace HCs from the second well during HCs production.
EFFECT: increased method efficiency.
29 cl, 10 dwg
FIELD: oil and gas industry.
SUBSTANCE: method involves construction of horizontal producers covering the field, and horizontal injectors. Displacement agent is injected through injectors, and products are swept by producers. Horizontal production wells are arranged parallel to each other. Horizontal injector is positioned between horizontal sections parallel to them. Injection starts from bottomhole. When intake capacity of reservoirs is decreased at the bottomhole of horizontal injector to minimum profitable level, non-operating section of horizontal shaft is isolated in series in direction from the bottomhole to the beginning of horizontal injector wellbore. Horizontal producers are drilled in permeable interlayer at 3-6 m distance below the reservoir bottom and at least at 10 m distance above oil-water interface. Horizontal injector is equally spaced from horizontal sections of producers by a design pattern distance. Displacement agent is injected with reservoir pressure rise by 10-20% compared to recovery zone. After time period sufficient to recover and stabilise frontal zone of liquid injected to the reservoir, operation may return to previous intervals. Horizontal sections of producers are broached in two intervals at a distance preventing hydrodynamic connection of the wells. Products are recovered in turns. Production intervals are switched when products reach minimum profitable water cut level.
EFFECT: increased oil recovery due to stabilisation of frontal zone of liquid injected to reservoir, extended application scope of horizontal wells in various field development conditions.
6 dwg, 1 ex
FIELD: oil-and-gas industry.
SUBSTANCE: invention relates to the oil-producing industry, in particular to oil field development with flooding. According to the method the displacement agent is injected and oil is withdrawn through the system of injection and production wells. The flooding mode is changed during the development. The displacement agent is injected into the injection well in intensive mode. Using the surface measuring instruments that are a part of an automated process control system the change of extracted oil volume growth depending on the displacement agent injection volume growth until the moment of fast drop of the extracted oil volume is monitored in real time. Then the displacement agent injection volume after which the named drop occurred is recorded. Further injection into the injection well is performed in the volume below this pre-set value.
EFFECT: decrease of labour input of control of oil field flooding process during injection of the displacement agent into injection wells.
1 ex, 6 dwg
FIELD: oil and gas industry.
SUBSTANCE: method provides for use of the production wells. One or several wells are equipped with pump unit with possibility of discharge change. For each production well the deposit or deposits used for production are known. At wellhead of each production well the produced crude oil and oil gas are measured, as well as crude oil watercut is determined. The product wells product is delivered to the gathering header of the wells cluster. The cluster contains one or more injection wells. For each injection well the deposit or deposits used for injection are known. Injectability of the injected water and required injection pressure are determined. Compatibility of the injected water and produced water is studied. Injection is performed upon compatibility of the injected and produced waters. Coordinates of all production and injection wells of the cluster using the same deposits are determined. For each production well time of the produced product lifting is determined from suction of the pump unit to wellhead at maximum discharge. Volume of produced crude oil and oil gas is measured with interval not exceeding half of measured time of fluid lifting for the given well. At wellhead of each well the injected water pressure and its volume are measured. Injected water volume and wellhead pressure are measured with interval not exceeding half of measured time of water supply to the wellhead of each injection well before parker. For each injection well the curve of injected water pressure and volume vs. time is plotted. For each production well using the plotted volume of produced crude oil and oil gas vs. time the relationship with the injected water volume and wellhead pressure is determined, as well as distances to each injection well ensuring injection to the same deposit. For the production wells equipped with pump units with possibility of discharge change such relationships are determined at different discharge. The wells cluster is controlled based on the obtained relationships for all production wells. At that the treated water supply system for injection is made with possibility to change water volume and wellhead pressure for one or more injection wells.
EFFECT: increased efficiency of clusters well control.
2 cl, 1 dwg
FIELD: oil-and-gas industry.
SUBSTANCE: this process comprises measurement of injection well capacity, feed of products of one or several production wells for preliminary water disposal. Measured are density of green oil and gas, green oil water content are measured in the well. Here said products are divided into partially dewatered oil, gas and water. Partially dewatered oil and gas are fed in gathering main. Disposed water is fed into injection well. Compatibility of disposed water with water of seam wherefrom pumping from injection well is made is defined. If threes are compatible, injection well is equipped with the device to create water pressure sufficient for water injection into seam, for example, with electrically-driven rotary pump. Said device allows varying of feed capacity by frequency-controlled drive for said pump. It is set to minimum feed to define the compliance of disposed water quality with the seam geological properties. At poor water quality, it is directed to gathering main or, at sufficient quality, it is forced into injection well. Disposed water amount is defined. Then, device feed capacity is increased either continuously or in stepwise manner to create water pressure. It is increased unless disposed water quality satisfied the seam geological properties.
EFFECT: higher process efficiency.
3 cl, 1 dwg, 1 ex
FIELD: oil and gas production.
SUBSTANCE: groups of high intake- and low intake-capacity injecting wells are chosen in a single hydrodynamic system and, for each well, oil reservoir properties and permissible degree of pollution of fluid received by high intake-capacity wells are determined. When fluid from low-permeable oil reservoir flows off through high intake-capacity wells, this fluid is cleaned to permissible degree of pollution.
EFFECT: reduced losses in intake capacity of formations and increased time between treatments of wells.
FIELD: oil and gas extractive industry.
SUBSTANCE: method includes construction of wells and oil and gas collection system, forcing water from water-bearing level into oil deposits, flow of oil from oil deposits into secondary deposit and following extraction of oil from secondary deposit for useful implementation. Resources of deposit are separated on basis of natural energy characteristic on screened and having rigid water-forcing mode. Deposit is operated by three well types. Of the latter flow wells connect oil deposits to secondary deposit for flowing and collection of oil in upper bed under effect from gravitation. Balancing wells connect screened deposits and secondary deposit to water-forcing level for balancing of bed pressures and preventing loss of rocks stability. Extraction wells connect secondary deposit to oil and gas collection system. Selection of bed for secondary deposit is performed from number of highly penetrable beds, having maximally allowed excess over oil deposits.
EFFECT: higher oil yield, higher effectiveness.
5 cl, 3 dwg
FIELD: oil extractive industry.
SUBSTANCE: method includes drilling of deposit according to row-wise non-even grid of wells with distance from force to extractive rows, greater than distance between extractive rows, pumping of displacing gent into force wells, extraction of product from product wells and transferring of displacing agent pumping front to extraction area. According to invention, transferring of displacing agent pumping front to extraction area is performed by drilling side horizontal shafts in all wells of force row and directed towards extractive row by beds ad zones with most remainder oil saturation level. Then among these wells are singled out, horizontal shafts of which pass along beds and areas with lesser oil saturation level. Pumping of displacing agent is restarted, and other wells are transferred to product category. These wells are operated with face pressures lower than saturation pressure until reaching 98% water saturation level. After that pumping of displacing agent is restarted along all other wells of force row. During that, rows of extractive wells are operated in normal mode.
EFFECT: higher efficiency.
FIELD: oil industry.
SUBSTANCE: according to first variant of method, force and product wells are drilled, working agent is fed through force wells, oil is extracted through product wells, dome-like raised portions are marked out, which surpass absolute marks of bed, additional wells are positioned in these portions. Wells placement is planned at tops of dome-like raised portions even with breach of evenness of planned well mesh. After full drilling of wells mesh and in case of more accurate definition according to data of drilled wells of deposit of dome-like portions side shafts are drilled from adjacent wells towards more precisely defined tops of dome-like portions, controlling the deposit. In adjacent wells and side shafts, positioned on tops of dome-like raised portions , range of productive bed is opened between absolute mark of ceiling in this well and absolute mark, appropriate for ceiling in closest well. According to second variant of method practically analogical operations are realized as in first variant, except when absolute mark of ceiling of productive bed according to adjacent wells is lower than mark of sole of productive bed, whole bed is opened in side shafts.
EFFECT: higher efficiency.
2 cl, 2 dwg
FIELD: oil reservoir development, particularly for developing water-flooded ones.
SUBSTANCE: method involves withdrawing oil through production wells and ejecting working substance through ejection wells. To prevent water ingress from well bore into oil-saturated formation area formation is perforated in water-oil interface zone so that lower part of oil-saturation formation interval and upper part of water-flooded formation interval are penetrated. This provides oil relative permeability retention in oil-saturated formation area. To prevent formation mudding during initial perforation thereof drilling is performed in depression, balance and repression modes with pressure of not more than 3 MPa. As far as oil is depleted perforation interval is extended towards oil-saturated formation area.
EFFECT: possibility to retain oil relative permeability of oil-saturated formation area.
2 cl, 2 dwg
FIELD: oil field development, particularly for ones with nonuniform reservoirs.
SUBSTANCE: method involves drilling injection and production wells; flooding oil reservoir and extracting oil out of well; defining more exactly geologic aspects on the base of drilling results; designing and drilling additional wells with horizontal bores or drilling horizontal bores from existent wells; determining location of reservoir drive zone boundaries; calculating volume of dead oil located near drive zones; drilling horizontal bores from existent wells located near drive zones and/or new wells with horizontal bores located in above zone, wherein horizontal bores are drilled in direction perpendicular to drive zone boundaries.
EFFECT: improved oil recovery.
2 dwg, 1 ex
FIELD: oil industry.
SUBSTANCE: method includes drilling vertical product and force wells, extracting oil from product wells, forcing working agent through force wells, making side horizontal shafts in force wells, forcing working agent through side horizontal shafts of force wells. Additionally, side horizontal shafts are made in extraction wells. Oil is taken through side horizontal shafts of extractive wells. With pressure in the well, decreased for 5-10% from hydrostatic pressure, all side horizontal shafts are made by washing away rock under pressure of fluid of around 15-20 mPa. Direction of all side horizontal shafts is set to be parallel to rows of wells.
EFFECT: higher oil yield.
1 ex, 1 dwg
FIELD: oil production industry, particularly enhanced recovery methods for obtaining hydrocarbons.
SUBSTANCE: method involves drilling production and injection wells and maintaining formation pressure; performing seismic works to determine volumetric routing of natural macrocrack system with lateral and depth routing; forming production and injection macrocracks of above system; drilling wells to corresponding macrocracks and forming producing well-macrocrack systems for oil production and injection well-macrocrack for formation flooding or production well-macrocrack for oil production and system including vertical and/or horizontal multibranch wells for formation flooding or injection well-macrocrack system for formation flooding and system including vertical and/or horizontal multibranch production wells for oil production or production well-macrocrack system, injection well-macrocrack system and system including vertical and/or horizontal multibranch production and injection wells.
EFFECT: increased efficiency, oil recovery and production well injectivity, as well as increased sweep efficiency and oil recovery ratio.
FIELD: oil production industry, particularly oil deposit development.
SUBSTANCE: method involves pumping working agent, namely water, in two stages. The first stage is performed with the use of power pumps. The second one is carried out by means of hydraulic measuring pumps, which are used to convert injection pressure created by power pumps. If it is necessary to increase pressure in water lines used to deliver water to separate injection wells pressure is regulated in accordance with necessary water volume to be injected in wells on the base of collecting properties of oil formations in bottomhole formation zones. This is performed by providing change in pump piston diameter and stroke ratios in the first and the second sections of hydraulic measuring pumps, which are selected on the base of hydraulic resistance variation depending on water flow velocity. Parameters characterizing injection system operation are simultaneously measured and efficiency of the method and equipment operation is detected from above characteristics.
EFFECT: increased efficiency of oil bed development due to energy-saving equipment and technique usage for formation pressure maintaining.
2 cl, 2 dwg
FIELD: enhanced recovery methods for obtaining hydrocarbons.
SUBSTANCE: method involves flooding production bed through injection wells with the use of pump units. In the case of terrigenous porous productive bed flooding acoustical sound resonators with resonance frequency setting are installed in injection line. This eliminates amplitude of alternating low-frequency liquid pulsation sound generated by pump units. Method also involves providing constant compression mode in productive beds and frontal oil drive from productive bed.
EFFECT: increased operational reliability.
1 ex, 3 dwg