CN114753813A - Method for improving recovery ratio in high water-containing stage of active edge-bottom water heavy oil reservoir - Google Patents
Method for improving recovery ratio in high water-containing stage of active edge-bottom water heavy oil reservoir Download PDFInfo
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- CN114753813A CN114753813A CN202110029156.2A CN202110029156A CN114753813A CN 114753813 A CN114753813 A CN 114753813A CN 202110029156 A CN202110029156 A CN 202110029156A CN 114753813 A CN114753813 A CN 114753813A
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- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 66
- 238000000034 method Methods 0.000 title claims abstract description 41
- 239000000295 fuel oil Substances 0.000 title claims abstract description 27
- 238000011084 recovery Methods 0.000 title claims abstract description 18
- 239000003921 oil Substances 0.000 claims abstract description 59
- 238000006073 displacement reaction Methods 0.000 claims abstract description 57
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims abstract description 56
- 238000005187 foaming Methods 0.000 claims abstract description 42
- 238000002347 injection Methods 0.000 claims abstract description 40
- 239000007924 injection Substances 0.000 claims abstract description 40
- 238000004519 manufacturing process Methods 0.000 claims abstract description 39
- 239000003638 chemical reducing agent Substances 0.000 claims abstract description 37
- 229910052757 nitrogen Inorganic materials 0.000 claims abstract description 28
- 238000011161 development Methods 0.000 claims abstract description 18
- 230000008569 process Effects 0.000 claims abstract description 9
- 238000005457 optimization Methods 0.000 claims abstract description 7
- 230000001603 reducing effect Effects 0.000 claims abstract description 7
- 238000011234 economic evaluation Methods 0.000 claims abstract description 4
- 239000006260 foam Substances 0.000 claims description 14
- 230000005465 channeling Effects 0.000 claims description 8
- 230000009467 reduction Effects 0.000 claims description 8
- 230000001186 cumulative effect Effects 0.000 claims description 6
- 230000000903 blocking effect Effects 0.000 claims description 4
- 230000037361 pathway Effects 0.000 claims 1
- 238000004088 simulation Methods 0.000 abstract description 3
- 238000012512 characterization method Methods 0.000 abstract 1
- 238000012360 testing method Methods 0.000 description 3
- 238000010795 Steam Flooding Methods 0.000 description 2
- 230000008901 benefit Effects 0.000 description 2
- 238000009826 distribution Methods 0.000 description 2
- 230000000694 effects Effects 0.000 description 2
- 230000002708 enhancing effect Effects 0.000 description 2
- 239000012530 fluid Substances 0.000 description 2
- 239000008398 formation water Substances 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 239000003129 oil well Substances 0.000 description 2
- 238000012887 quadratic function Methods 0.000 description 2
- 239000000243 solution Substances 0.000 description 2
- 230000009471 action Effects 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 238000002474 experimental method Methods 0.000 description 1
- 239000003673 groundwater Substances 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 230000000630 rising effect Effects 0.000 description 1
- 238000006467 substitution reaction Methods 0.000 description 1
- 238000012546 transfer Methods 0.000 description 1
Images
Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/166—Injecting a gaseous medium; Injecting a gaseous medium and a liquid medium
- E21B43/168—Injecting a gaseous medium
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/30—Specific pattern of wells, e.g. optimizing the spacing of wells
Abstract
The invention relates to the technical field of oilfield development, in particular to a method for improving recovery efficiency in a high water-containing stage of an active edge bottom water heavy oil reservoir. The method comprises the following steps: selecting a foaming viscosity reducer with foaming and viscosity reducing effects, and characterizing performance parameters of the foaming viscosity reducer; determining the relative position between an injection well and a production well, and deploying a well pattern; injecting a foaming viscosity reducer for displacement development; calculating the nitrogen consumption in the displacement process, and injecting nitrogen into the oil reservoir through an injection well; calculating accumulated net current values under different displacement pressure differences among injection wells and production wells; and determining the injection pressure of the injection well and the bottom hole flowing pressure of the production well in the displacement process. The method disclosed by the invention is based on the numerical reservoir simulation characterization of the foaming viscosity reducer performance, combines dynamic economic evaluation, and applies an optimization theory to realize balanced displacement and effective utilization of residual oil among wells of the active bottom-edge water heavy oil reservoir, thereby providing a way for effective utilization of residual oil among wells in a high water-cut stage of the active bottom-edge water heavy oil reservoir.
Description
Technical Field
The invention relates to the technical field of oilfield development, in particular to a method for improving the recovery ratio of an active edge bottom water heavy oil reservoir in a high water-containing stage.
Background
The victory oil field active edge bottom water heavy oil reservoir resources are rich and are mainly distributed in 86 unit blocks such as a long dike, a temporary disc and a big lujia, and the geological reserve is 2.96 hundred million tons.
Influenced by active edge bottom water, the waterless oil recovery period of the heavy oil reservoir is short and the water content rises fast, the reservoir can rise to the ultrahigh water content period in a short time after being put into development, and after the active edge bottom water heavy oil reservoir bottom water coning, the edge bottom water can enter an oil well along a water channeling channel in a large amount under the influence of the oil-water fluidity ratio, residual oil between wells is difficult to use, so that the production of the oil well faces the problems of high liquid content and low oil content, and the ground water treatment cost is high. For the victory oil field active edge bottom water heavy oil reservoir, the calibrated recovery rate is only 22.1%, and the overall utilization degree is low. Under the current oil price condition, the deep research is needed, the development cost of the active edge-bottom water heavy oil reservoir is reduced, the utilization degree is further improved, and the benefit development of the active edge-bottom water heavy oil reservoir is realized.
Chinese patent application CN106285584A discloses a diversified utilization and development method for active edge bottom water heavy oil reservoir transfer flooding, which comprises the following steps: carrying out oil reservoir depressurization on the selected active edge-bottom water heavy oil reservoir block; determining a development mode and optimizing parameters for the target well group of the oil reservoir plot; and treating and comprehensively utilizing the formation water of the oil reservoir plots. And the oil deposit depressurization refers to drilling a water taking well at the bottom of the bottom water, taking water to the ground through the water taking well, and performing water quality treatment on the water taking well until the pressure of a water layer is reduced to below 4.5MPa so as to achieve the oil deposit condition suitable for steam flooding. The invention integrates oil reservoir depressurization, development mode and parameter optimization, formation water treatment and comprehensive utilization, effectively utilizes active edge bottom water heavy oil reservoir and realizes smooth steam drive, and finally improves the recovery ratio and the reserve utilization ratio of the heavy oil reservoir.
However, under the conditions of low oil price and continuous rising development cost, a new method capable of improving the recovery ratio of the active bottom-edge water heavy oil reservoir needs to be formed to improve the development benefit and the oil reservoir utilization degree while reducing the development cost.
Disclosure of Invention
The invention mainly aims to provide a method for improving recovery efficiency in a high water content stage of an active edge bottom water heavy oil reservoir.
In order to realize the purpose, the invention adopts the following technical scheme:
the invention provides a method for improving the recovery ratio of an active edge bottom water heavy oil reservoir in a high water-containing stage, which comprises the following steps:
selecting a foaming viscosity reducer with foaming and viscosity reducing effects, and characterizing performance parameters of the foaming viscosity reducer;
determining the relative position between an injection well and a production well, and deploying a well pattern;
injecting a foaming viscosity reducer for displacement development;
Calculating the nitrogen consumption in the displacement process, and injecting nitrogen into the oil reservoir through an injection well;
calculating accumulated net current values under different displacement pressure differences among injection wells and production wells;
and determining the injection pressure of the injection well and the bottom hole flowing pressure of the production well in the displacement process.
Further, performance parameters characterizing foaming viscosity reducers include: the relationship between the interfacial tension performance and the concentration of the foaming viscosity reducer is reduced, the relationship between the viscosity reduction performance and the concentration of the foaming viscosity reducer is reduced, the relationship between the foam resistance factor and the concentration of the foaming viscosity reducer is reduced, and the relationship between the foam half-life period and the concentration of the foaming viscosity reducer is reduced.
Further, the relative position between the injection well and the production well in the plane and in the longitudinal direction is determined.
Furthermore, the relative position of the injection wells in the longitudinal direction can simultaneously meet the requirements of longitudinally balanced displacement of residual oil between wells, such as blocking of a water channeling channel by the foaming type viscosity reducer on the lower part of an oil layer when encountering water, displacement propulsion after viscosity reduction of the foaming type viscosity reducer in the middle of the oil layer when encountering residual oil between wells, nitrogen-gas-flooding oil displacement at the top of the oil layer and the like.
Furthermore, the relative position on the plane of the production well can meet the requirement that the nitrogen foam viscosity reduction driving mode is adopted, and the production wells in the lower injection and production well group can achieve uniform effect.
Further, the foaming viscosity reducer is injected into the oil reservoir from the injection well to perform residual oil displacement between wells.
Further, the nitrogen consumption is equal to the sum of the nitrogen amount for forming nitrogen foam plugging in the water channeling passage at the bottom of the oil reservoir and the nitrogen amount for nitrogen overburden oil displacement at the top of the oil reservoir.
And further, predicting oil production under different displacement differential pressures through a digital-analog model, and calculating accumulated net present values under different displacement differential pressures by using a dynamic economic evaluation method.
And further, by utilizing a mathematical optimization method, taking the displacement differential pressure corresponding to the maximum accumulated net current value as a reasonable displacement differential pressure, and determining the injection pressure of the injection well and the bottom hole flow pressure of the production well in the displacement process.
Further, the cumulative net present value NPV is functionally related to the displacement pressure difference Pd as follows:
NPV＝aPd 2+bPd+c
in the formula, NPV is an accumulated net present value, Pd is displacement pressure difference, and a, b and c are coefficients of a quadratic equation obtained by regression.
Compared with the prior art, the invention has the following beneficial effects:
according to the method, the performance parameters of the foaming viscosity reducer are represented by a numerical model, and on the basis, the relative positions of an injection well and a production well are optimized, and a well pattern is deployed; and calculating the nitrogen consumption for foaming and oil displacement, optimizing by taking the maximization of the net present value of financial affairs as a mathematical target, and determining the reasonable displacement pressure difference between an injection well and a production well in the production process, thereby providing technical guidance and theoretical support for improving the recovery ratio in the high water-bearing stage of the active edge-bottom water reservoir. The invention relates to a method for improving the recovery ratio of an active edge bottom water heavy oil reservoir in a high water-containing stage by comprehensively considering technical and economic factors.
Drawings
The accompanying drawings, which are incorporated in and constitute a part of this specification, are included to provide a further understanding of the invention, and are included to illustrate an exemplary embodiment of the invention and not to limit the invention.
FIG. 1 is a flow chart of a method for enhancing oil recovery during high water content phase of an active edge-bottom water heavy oil reservoir according to an embodiment of the present invention;
FIG. 2 is a schematic diagram of the distribution of fluids in a reservoir during the implementation of the method for enhancing the recovery efficiency during the high water phase of an active bottom-edge water heavy oil reservoir according to an embodiment of the present invention;
FIG. 3 is a graph of the relationship between displacement pressure differential and accumulated net present value when a reasonable displacement pressure differential is determined in accordance with an embodiment of the present invention.
Detailed Description
It should be noted that the following detailed description is exemplary and is intended to provide further explanation of the invention. Unless defined otherwise, all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this invention belongs.
It is noted that the terminology used herein is for the purpose of describing particular embodiments only and is not intended to be limiting of exemplary embodiments according to the invention. As used herein, the singular forms "a", "an" and "the" are intended to include the plural forms as well, and it should be understood that when the terms "comprises" and/or "comprising" are used in this specification, they specify the presence of the stated features, steps, operations, and/or combinations thereof, unless the context clearly indicates otherwise.
In order to make the technical solutions of the present invention more clearly understood by those skilled in the art, the technical solutions of the present invention will be described in detail below with reference to specific embodiments.
Example 1
As shown in figure 1, the method for improving the recovery efficiency of the active bottom-edge water heavy oil reservoir in the high water content stage comprises the following steps:
in step 101, a foaming viscosity reducer with foaming and viscosity reducing functions is selected, oil reservoir numerical simulation software is used for fitting performance experiment data of the foaming viscosity reducer, and the relationship between the interface tension reducing performance, viscosity reducing performance, foam resistance factor and half-life period of the foaming viscosity reducer and the concentration of the foaming viscosity reducer is represented in the numerical simulation software, so that a necessary data basis is provided for subsequent optimization. Flow proceeds to step 102.
At step 102, a reservoir numerical simulation is used to calculate the displacement state of residual oil between the injection well and the production well when the injection well and the production well are at different positions. And taking the positions of the injection well and the production well corresponding to the balanced displacement of the residual oil between the wells in the longitudinal direction and the plane as the optimal injection and production well position for deployment. The relative position of the injection well in the longitudinal direction can simultaneously meet the requirements of plugging a water channeling channel by the foaming type viscosity reducer at the lower part of an oil layer when the foaming type viscosity reducer foams when meeting water, displacing and propelling the foaming type viscosity reducer in the middle part of the oil layer after viscosity reduction of residual oil between wells, and longitudinally and uniformly displacing residual oil between wells such as nitrogen-overburden oil displacement at the top of the oil layer. The relative position on the plane of the production well can meet the requirement that the nitrogen foam viscosity reduction drives the production well in the lower injection and production well group in the development mode to achieve uniform effect. Fig. 2 is a schematic view of the fluid distribution within the reservoir during the implementation of step 102. The flow proceeds to step 103.
At step 103, a foaming viscosity reducer is injected into the reservoir from the injection well for interwell residual oil displacement. The flow proceeds to step 104.
At step 104, nitrogen usage is calculated using digital to analog software. The nitrogen consumption can meet the requirements that a stable foam blocking water channeling channel is formed under the action of the bottom of an oil layer and a foam viscosity reducer, nitrogen overlap oil displacement is realized at the top of the oil layer, and the displacement front edge can be pushed in a balanced manner. The nitrogen consumption is equal to the sum of the nitrogen amount for forming nitrogen foam plugging in the water channeling passage at the bottom of the oil reservoir and the nitrogen amount for nitrogen overburden oil displacement at the top of the oil reservoir. The flow proceeds to step 105.
In step 105, the displacement differential pressure is changed, the daily oil yield under different displacement differential pressures is predicted through a digital-analog model, after the daily net present value is calculated, the daily net present value is accumulated, the accumulated net present value in the whole production period is obtained, and the accumulated net present value corresponding to different displacement differential pressures is obtained. The flow proceeds to step 106.
In step 106, a mathematical optimization method is used to determine the injection pressure of the injection well and the bottom hole flow pressure of the production well in the displacement process by using the displacement pressure difference corresponding to the maximum accumulated net present value as a reasonable displacement pressure difference.
Drawing the accumulated net present value scattered point data under different displacement differential pressures into a data table, carrying out unary quadratic regression on the scattered point data, and solving the maximum value of an unary quadratic equation obtained by regression, wherein the displacement differential pressure corresponding to the maximum value is the reasonable displacement differential pressure in the displacement process.
The cumulative net present value NPV and the displacement pressure difference Pd have the following functional relationship:
NPV＝aPd 2+bPd+c
in the formula, NPV is an accumulated net present value, Pd is displacement pressure difference, and a, b and c are coefficients of a quadratic equation obtained by regression.
FIG. 3 is a graph of differential displacement pressure versus cumulative net present value. The quadratic function of the regression is:
y＝-1113.4x2+22531x+672533
by using a quadratic function extreme formula, the maximum net present value can be calculated as: 786518.5 yuan, the corresponding displacement differential pressure oil is 10.1MPa, the value is reasonable production differential pressure, when the difference between the injection pressure of an injection well and the bottom hole flowing pressure of a production well is kept at 10.1MPa, the high water content later-stage development of the active bottom water heavy oil reservoir can reach the optimal input-output ratio, and the economic and efficient development of the reservoir is realized.
The invention carries out the mine field test in a certain block of the victory oil field, and the test result shows that the technology can reduce the water content of the production well by 14 percent and improve the recovery ratio of the test block by about 6 percent.
The method for improving the recovery efficiency in the high water content stage of the active edge bottom water heavy oil reservoir optimizes the relative position of injection and production wells, defines the nitrogen consumption and reasonably replaces the pressure difference by combining methods such as economic evaluation, mathematical optimization and the like on the basis of numerical simulation, thereby realizing the economic and efficient development in the high water content stage of the active edge bottom water heavy oil reservoir and providing technical support and theoretical support for oil field production.
The above embodiments are preferred embodiments of the present invention, but the present invention is not limited to the above embodiments, and any other changes, modifications, substitutions, combinations, and simplifications which do not depart from the spirit and principle of the present invention should be construed as equivalents thereof, and all such modifications are intended to be included in the scope of the present invention.
Claims (10)
1. The method for improving the recovery ratio of the active edge-bottom water heavy oil reservoir in the high water-containing stage is characterized by comprising the following steps of:
selecting a foaming viscosity reducer with foaming and viscosity reducing effects, and characterizing performance parameters of the foaming viscosity reducer;
determining the relative position between an injection well and a production well, and deploying a well pattern;
injecting a foaming viscosity reducer for displacement development;
calculating the nitrogen consumption in the displacement process, and injecting nitrogen into the oil reservoir through an injection well;
calculating accumulated net current values under different displacement pressure differences among injection wells and production wells;
and determining the injection pressure of the injection well and the bottom hole flowing pressure of the production well in the displacement process.
2. The method of claim 1, wherein the performance parameters characterizing the foaming viscosity reducer comprise: the relationship between the interfacial tension performance and the concentration of the foaming viscosity reducer is reduced, the relationship between the viscosity reduction performance and the concentration of the foaming viscosity reducer is reduced, the relationship between the foam resistance factor and the concentration of the foaming viscosity reducer is reduced, and the relationship between the foam half-life period and the concentration of the foaming viscosity reducer is reduced.
3. The method of claim 1 wherein the relative position between the injection well and the production well in the plane and the longitudinal direction is determined.
4. The method according to claim 3, wherein the relative positions of the injection wells in the longitudinal direction can simultaneously meet the requirements of blocking a water channeling channel by a foaming type viscosity reducer at the lower part of an oil layer in case of foaming when meeting water, driving and propelling the foaming type viscosity reducer at the middle part of the oil layer after viscosity reduction of residual oil between wells in case of the foaming type viscosity reducer, and longitudinally and evenly driving the residual oil between wells.
5. The method of claim 3, wherein the relative positions on the production well plane are such that nitrogen foam viscosity reduction drive-out of production wells in the injection-production well group can be uniformly effected.
6. The method of claim 1, wherein injecting the foaming viscosity reducer from the injection well into the reservoir displaces residual oil from the well.
7. The method of claim 1, wherein the amount of nitrogen is equal to the sum of the amount of nitrogen for blocking the water channeling pathway forming nitrogen foam at the bottom of the reservoir and the amount of nitrogen for flooding the top of the reservoir.
8. The method of claim 1, wherein oil production at different displacement differential pressures is predicted by a digital-to-analog model, and the cumulative net present value at different displacement differential pressures is calculated using a dynamic economic evaluation method.
9. The method of claim 1, wherein the injection pressure of the injection well and the bottom-hole flow pressure of the production well during the displacement are determined using a mathematical optimization method using the displacement pressure differential corresponding to the maximum cumulative net present value as the rational displacement pressure differential.
10. The method of claim 9, wherein the cumulative net present value NPV is a function of the displacement pressure difference Pd as follows:
NPV＝aPd 2+bPd+c
in the formula, NPV is an accumulated net present value, Pd is displacement pressure difference, and a, b and c are coefficients of a quadratic equation obtained by regression.
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Cited By (1)
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