CN108846540B - Recovery ratio calibration method and device for tight sandstone gas field - Google Patents
Recovery ratio calibration method and device for tight sandstone gas field Download PDFInfo
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Abstract
The application provides a method and a device for calibrating recovery ratio of a tight sandstone gas field, wherein the method comprises the following steps: dividing a target tight sandstone gas field into a plurality of work areas, and dividing production wells in the target tight sandstone gas field into a plurality of well types; determining the control area of each work area, the control area ratio of various wells in each work area, the cumulative production of wells and the control area of wells; determining the limit well number of various wells in each work area according to the control area of each work area, the control area ratio of various wells in each work area and the well average control area; multiplying the accumulated well output of various wells in each work area by the limit well number to obtain the limit accumulated well output of various wells in each work area; determining the utilization reserves of various wells in each work area, and dividing the ultimate accumulated yield of various wells in each work area by the utilization reserves to obtain the ultimate recovery ratio of various wells in each work area; and determining the ultimate recovery ratio according to the ultimate recovery ratios of various wells in each work area. The method and the device can improve the accuracy of the recovery ratio calibration of the tight sandstone gas field.
Description
Technical Field
The application relates to the technical field of petroleum and natural gas development, in particular to a method and a device for calibrating the recovery ratio of a tight sandstone gas field.
Background
The determination of the gas field recovery ratio and the final gas production amount has important significance for guiding the long-term stable production of the gas field, making a development technical strategy and measuring the development effect of the gas field. The recovery ratio is the ratio of the final accumulated gas production amount to the ascertained reserve amount when the gas field is scrapped. The ascertained reserves refer to geological reserves calculated after the evaluation and drilling stage of the gas field in China, and are the basis for development scheme compilation and capacity construction. The large-scale compact sandstone gas field has wide distribution range, strong reservoir heterogeneity, complex geological conditions and great development difficulty, and no special recovery ratio calibration method aiming at the gas field is formed at present.
The conventional gas field is generally calibrated for recovery efficiency by a gas-flooding experimental simulation or a comparable method, and the two methods have poor application effect in the tight sandstone gas field. The simulation of the gas displacement experiment is to perform basic experiments such as stress sensitivity, single-phase and gas-water two-phase, gas slippage effect and the like under the conditions of simulating the original formation temperature and the formation stress, and analyze the ratio of the accumulated gas production to the total amount (reserve) of natural gas accumulated in a rock sample to obtain the ultimate recovery ratio. The method is popularized to a large compact sandstone gas field type, and has certain problems: the physical property of a compact gas reservoir is poor, the pore structure is complex, and the complex pore and throat combination relationship of the reservoir is difficult to simulate in a laboratory; secondly, the permeability of the compact gas reservoir is low, the seepage mechanism is complex, and the classical Darcy seepage theory is not applicable; and thirdly, the large compact sandstone reservoir has strong heterogeneity, different development blocks and even the difference inside the same development block is large, the indoor simulation analysis test sample points are few, and the recovery result obtained according to a plurality of rock samples is difficult to represent the whole gas field. The analogy method needs to meet stricter conditions when in use, and the similarity between the analogy gas reservoir and the geological conditions and the development mode of the target gas reservoir is extremely high. As most of Chinese oil and gas reservoirs are deposited on land, the difference with foreign geological conditions is large, the development and the start of domestic compact gas reservoirs are late, fresh compact gas reservoirs enter the later development stage or are close to abandon, namely, the recovery ratio calibration by adopting an analogy method lacks a proper analogy gas reservoir, and the accuracy is not high.
Disclosure of Invention
The embodiment of the application aims to provide a method and a device for calibrating the recovery ratio of a tight sandstone gas field so as to improve the accuracy of the recovery ratio calibration of the tight sandstone gas field.
In order to achieve the above object, in one aspect, the present application provides a method for calibrating a recovery ratio of a tight sandstone gas field, including:
dividing a target tight sandstone gas field into a plurality of work areas according to reservoir geological conditions and development characteristics;
determining the reservoir scale and the reservoir structure of each work area;
dividing the production wells in the target tight sandstone gas field into a plurality of well classes based on preset evaluation indexes;
determining the control area of each work area, the control area ratio of various wells in each work area and the cumulative production of the wells, and correspondingly determining the well control area of various wells in each work area according to the reservoir scale and the reservoir structure of each work area;
correspondingly determining the limit well number of various wells in each work area according to the control area of each work area, the control area ratio of various wells in each work area and the well average control area;
multiplying the accumulated well output of various wells in each work area by the corresponding limit well number to obtain the limit accumulated well output of various wells in each work area;
determining the utilization reserves of various wells in each work area, and dividing the ultimate accumulated yield of various wells in each work area by the corresponding utilization reserves to correspondingly obtain the ultimate recovery ratio of various wells in each work area;
and determining the ultimate recovery ratio of the target tight sandstone gas field according to the ultimate recovery ratio of various wells in each work area.
In the recovery efficiency calibration method for the tight sandstone gas field, the reservoir geological conditions comprise effective thickness, reserve abundance, porosity and gas saturation; the development characteristics include the three year well-average daily gas production.
In the recovery efficiency calibration method for the tight sandstone gas field in the embodiment of the application, the evaluation indexes comprise single-layer effective thickness, accumulated effective thickness, unimpeded flow and initial yield.
In the method for calibrating the recovery ratio of a tight sandstone gas field according to the embodiment of the application, dividing a target tight sandstone gas field into a plurality of work areas according to reservoir geological conditions and development characteristics includes:
standardizing the effective thickness, the reserve abundance, the porosity, the gas saturation and the average daily gas production of the three-year-period well to obtain standardized parameters so as to eliminate the influence of different dimensions;
determining the weight of each standardized parameter according to the influence of each standardized parameter on the work area;
according to the formula
Determining parameter values of comprehensive evaluation parameters, and dividing the target tight sandstone gas field into a plurality of work areas according to the parameter values of the comprehensive evaluation parameters;
wherein V is a comprehensive evaluation parameter;
Sgi、hi、Ri、Pirespectively normalized porosity, gas saturation, andeffective thickness, reserve abundance and three-year-period average daily gas production of the well; a. b, c, d, e are respectively
Sgi、hi、Ri、PiThe weights of (a), (b), (c), (d) and (e) are positive numbers, and a + b + c + d + e is 1.
In the method for calibrating the recovery ratio of a tight sandstone gas field according to the embodiment of the application, the determining the control area of each work area and the control area ratio of various wells in each work area includes:
determining a main control sedimentary facies belt of each work area;
and correspondingly determining the control area of each work area and the control area ratio of various wells in each work area by taking the master control sedimentary facies belt of each work area as constraint.
In the method for calibrating the recovery ratio of a tight sandstone gas field according to the embodiment of the application, the determining the cumulative production of the wells of each type of well in each work area includes:
and determining the well average dynamic reserves of various wells in each work area by utilizing a capacity instability analysis and production curve integration method, and predicting the well average accumulated yield of various wells in each work area by combining preset single well development abandon conditions.
In the method for calibrating the recovery ratio of a tight sandstone gas field according to the embodiment of the application, the corresponding determination of the well control area of each type of well in each work area according to the reservoir scale and the reservoir structure of each work area comprises the following steps:
correspondingly determining the value range of the effective sand body plane superposition area of various wells in each work area according to the reservoir scale and the reservoir structure of each work area;
determining the average value of the single-well gas leakage area of various wells in each work area;
and when the average value of the single-well gas leakage areas of the various wells in each work area is correspondingly located in the value range of the plane superposition area of the effective sand bodies of the various wells in each work area, correspondingly determining the average value of the single-well gas leakage areas of the various wells in each work area as the well average control area of the various wells in each work area.
In the method for calibrating the recovery ratio of a tight sandstone gas field according to the embodiment of the application, the method for correspondingly determining the limit well number of various wells in each work area according to the control area of each work area, the control area ratio of various wells in each work area and the well average control area includes:
multiplying the control area of each work area by the control area ratio of various wells in each work area respectively to correspondingly obtain the control area of various wells in each work area;
and correspondingly dividing the control area of each well in each work area by the well average control area of each well in each work area to correspondingly obtain the limit well number of each well in each work area.
In the recovery factor calibration method for the tight sandstone gas field in the embodiment of the application, determining the ultimate recovery factor of the target tight sandstone gas field according to the ultimate recovery factors of various wells in each work area includes:
and carrying out weighted average on the ultimate recovery ratio of various wells in each work area to obtain the ultimate recovery ratio of the target compact sandstone gas field.
On the other hand, the embodiment of the application also provides a recovery ratio calibration device for tight sandstone gas field, which comprises:
the target gas field partitioning module is used for dividing the target compact sandstone gas field into a plurality of work areas according to reservoir geological conditions and development characteristics;
the reservoir characteristic determining module is used for determining the reservoir scale and the reservoir structure of each work area;
the production well classification module is used for classifying the production wells in the target tight sandstone gas field into a plurality of well classes based on preset evaluation indexes;
the control parameter determining module is used for determining the control area of each work area, the control area ratio of various wells in each work area and the cumulative output of the wells, and correspondingly determining the well control area of various wells in each work area according to the reservoir scale and the reservoir structure of each work area;
the limit well number determining module is used for correspondingly determining the limit well number of various wells in each work area according to the control area of each work area, the control area ratio of various wells in each work area and the well average control area;
the accumulated yield determining module is used for multiplying the accumulated well yields of various wells in each work area by the corresponding limit well number to obtain the limit accumulated yields of various wells in each work area;
the classified recovery rate determining module is used for determining the utilization reserves of various wells in each work area, dividing the ultimate accumulated yield of various wells in each work area by the corresponding utilization reserves and correspondingly obtaining the ultimate recovery rate of various wells in each work area;
and the total recovery rate determining module is used for determining the ultimate recovery rate of the target tight sandstone gas field according to the ultimate recovery rates of various wells in each work area.
In another aspect, the present application provides another tight sandstone gas field recovery factor calibration device, including a memory, a processor, and a computer program stored on the memory, where the computer program is executed by the processor to perform the following steps:
dividing a target tight sandstone gas field into a plurality of work areas according to reservoir geological conditions and development characteristics;
determining the reservoir scale and the reservoir structure of each work area;
dividing the production wells in the target tight sandstone gas field into a plurality of well classes based on preset evaluation indexes;
determining the control area of each work area, the control area ratio of various wells in each work area and the cumulative production of the wells, and correspondingly determining the well control area of various wells in each work area according to the reservoir scale and the reservoir structure of each work area;
correspondingly determining the limit well number of various wells in each work area according to the control area of each work area, the control area ratio of various wells in each work area and the well average control area;
multiplying the accumulated well output of various wells in each work area by the corresponding limit well number to obtain the limit accumulated well output of various wells in each work area;
determining the utilization reserves of various wells in each work area, and dividing the ultimate accumulated yield of various wells in each work area by the corresponding utilization reserves to correspondingly obtain the ultimate recovery ratio of various wells in each work area;
and determining the ultimate recovery ratio of the target tight sandstone gas field according to the ultimate recovery ratio of various wells in each work area.
According to the technical scheme provided by the embodiment of the application, massive real and reliable geological and dynamic data in the development of the large-scale compact sandstone gas field are utilized, the production wells are used as entry points, the strategies of production well classification discussion and typical block dissection are adopted, a plurality of work areas are reasonably divided, a plurality of production well types are divided, the ultimate cumulative yield of various wells in each work area is predicted according to the typical blocks, then the ultimate cumulative yield of various wells in each work area is divided by the corresponding utilization reserves, the ultimate recovery ratio of various wells in each work area is correspondingly obtained, and finally the ultimate recovery ratio of the target compact sandstone gas field is determined according to the ultimate recovery ratio of various wells in each work area. Therefore, more accurate recovery ratio of the tight sandstone gas field can be calibrated based on the technical scheme provided by the embodiment of the application, so that the method can play a positive role in the preparation and development of technical countermeasures and the maintenance of long-term stable production of the gas field.
Drawings
In order to more clearly illustrate the embodiments of the present application or the technical solutions in the prior art, the drawings needed to be used in the description of the embodiments or the prior art will be briefly introduced below, it is obvious that the drawings in the following description are only some embodiments described in the present application, and for those skilled in the art, other drawings can be obtained according to the drawings without any creative effort. In the drawings:
FIG. 1 is a flow chart of a method for calibrating recovery efficiency of tight sandstone gas fields in one embodiment of the present application;
FIG. 2a is a plot of sand to ground ratio for a work area according to an embodiment of the present disclosure;
FIG. 2b is a plan view of wells within a work area according to an embodiment of the present invention;
FIG. 3 is a block diagram of a recovery factor calibration apparatus for tight sandstone gas fields in an embodiment of the present application;
fig. 4 is a block diagram of a recovery factor calibration device for tight sand gas fields according to another embodiment of the present application.
Detailed Description
In order to make those skilled in the art better understand the technical solutions in the present application, the technical solutions in the embodiments of the present application will be clearly and completely described below with reference to the drawings in the embodiments of the present application, and it is obvious that the described embodiments are only a part of the embodiments of the present application, and not all of the embodiments. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present application. For example, in the following description, forming the second component over the first component may include embodiments in which the first and second components are formed in direct contact, embodiments in which the first and second components are formed in non-direct contact (i.e., additional components may be included between the first and second components), and so on.
Also, for ease of description, some embodiments of the present application may use spatially relative terms such as "above …," "below …," "top," "below," etc., to describe the relationship of one element or component to another (or other) element or component as illustrated in the various figures of the embodiments. It will be understood that the spatially relative terms are intended to encompass different orientations of the device in use or operation in addition to the orientation depicted in the figures. For example, if the device in the figures is turned over, elements or components described as "below" or "beneath" other elements or components would then be oriented "above" or "over" the other elements or components.
For a large compact sandstone gas field, two main problems exist in the current calculation formula by taking the ascertained reserves as the recovery ratio: firstly, the well spacing is large, the data are few, the precision is low in the exploration phase, the obtained reservoir parameters are not accurate enough, and the reliability of the geological reserves obtained according to the volumetric method is not strong. Although more accurate gas field reserves parameters can be obtained along with the deepening of the development process, under the current reserves management mode of China, the reserves are proved to be rarely changed or underwritten once submitted; secondly, production dynamics is not combined, and the calculated recovery ratio cannot reflect the development rule of the gas reservoir, so that the transverse comparison of different types of gas reservoirs is not facilitated. The seepage capability of the dense gas reservoir is weak, and reserves in an uncontrolled area of the well pattern are difficult to draw. Therefore, it is contemplated to use a reserve of oil instead of the ascertained reserve in the recovery calculation equation. The reserve for use is that part of the reserve which is used for production utilization in the area covered by the technical well pattern and the capacity construction according to the development scheme. A more regular well pattern is difficult to be completely matched with irregular reservoir distribution, so that a certain degree of area loss is caused, and part of ascertained reserves are difficult to use; in the development process, the knowledge of reservoir heterogeneity is deepened continuously, and the accuracy of the obtained reservoir parameters is improved continuously, so that the amount of used reserves calculated by using the production well pattern is always smaller than the amount of found reserves. Considering that the single well yield of the compact gas reservoir is low, the gas field scale effective development depends on a large number of well arrangements, rich geological and development dynamic data can be obtained according to the production wells, and the gas reservoir can be accurately described and the recovery rate can be calibrated by adopting a proper method according to the real data.
Therefore, massive geological and dynamic data in the development of the large-scale compact sandstone gas field are utilized, the production well is used as an entry point, a classification discussion and key dissection strategy is adopted, the development blocks are reasonably split, the production well types are divided, the final accumulated gas production rate of various well zones under the condition that the well pattern is dense enough and interference is not generated is predicted aiming at typical blocks, and the ultimate recovery ratio of the gas field is accurately calibrated by integrating all the blocks, so that the method can play an active role in the establishment of technical measures for development and the long-term stable production of the gas field.
Referring to fig. 1, based on the above theory, the method for calibrating the recovery ratio of tight sandstone gas field according to the embodiment of the present application may include the following steps:
and S101, dividing the target tight sandstone gas field into a plurality of work areas according to reservoir geological conditions and development characteristics.
The large compact sandstone gas field has wide distribution range, strong reservoir heterogeneity and obvious difference among development blocks. Thus, in an embodiment of the present application, a target tight sandstone gas field may be divided into multiple zones based on reservoir geological conditions and development characteristics. Reservoir geological conditions may include, for example, effective thickness, reserve abundance, porosity, gas saturation, and the like; development characteristics may include, for example, three year well-average daily gas production, etc. In an embodiment of the present application, the dividing the target tight sandstone gas field into a plurality of work areas according to the reservoir geological conditions and the development characteristics may include the following steps:
1) standardizing the effective thickness, the reserve abundance, the porosity, the gas saturation and the average daily gas production of the three-year-period well to obtain standardized parameters so as to eliminate the influence of different dimensions;
2) determining the weight of each standardized parameter according to the influence of each standardized parameter on the work area;
3) according to the formula
Determining parameter values of comprehensive evaluation parameters, and dividing the target tight sandstone gas field into a plurality of work areas according to the parameter values of the comprehensive evaluation parameters;
wherein V is a comprehensive evaluation parameter;
Sgi、hi、Ri、Pirespectively standardized porosity, gas saturation, effective thickness, reserve abundance and three-year-period well average daily gas production; a. b, c, d, e are respectively
Sgi、hi、Ri、PiThe weights of (a), (b), (c), (d) and (e) are positive numbers, and a + b + c + d + e is 1.
In an exemplary embodiment, a large compact sandstone gas field of surrigo is taken as an example:
(1) firstly, the 5 parameters are standardized to eliminate the influence of different dimensions
Storage of large compact sandstone gas field of SuligeThe porosity of the layer is mainly distributed in 5-15%, the gas saturation is mainly distributed in 40-80%, the effective thickness is mainly distributed in 6-20 m, and the reserve abundance is mainly distributed in (0.9-2.5) x 108m3/km2The daily gas production in the three-year period is mainly distributed in (0.5-3.0) x 104m3And d. Then there are:
wherein,
Sgh, R and P are respectively original porosity, gas saturation, effective thickness, reserve abundance and three-year-period well average daily gas production.
(2) According to the influence of each parameter on the partition, respectively defining the weight of each parameter
According to experience, a relevant formula is fitted, and the weights of porosity, gas saturation, effective thickness, reserve abundance and daily gas production in three years are respectively 0.1, 0.2, 0.15 and 0.45. The sum of the weights of these 5 parameters is 1.
(3) Partitioning the gas field according to the comprehensive evaluation parameter V
According to V values of 0.3, 0.2-0.3, 0.12-0.2 and <0.12, the gas field is divided into four large areas which respectively correspond to Suzhong, Sudong, Suxi and Sunan, as shown in the following table 1, so that bases are provided for the subsequent research in subareas.
TABLE 1 Su Li Ge gas field each area division table
S102, determining the reservoir scale and the reservoir structure of each work area.
In the embodiment of the present application, generally, the number of production wells per work area may still be large, and the data is complicated and difficult to be applied completely. Therefore, it can be considered to perform reservoir fine dissection from a typical block in each work area, which preferably can represent the work area, to determine the reservoir scale and reservoir structure thereof, so as to clarify the geological conditions of the work area.
In an exemplary embodiment, for example, Suzhou is an important component of the development of the Sulige gas field, area 6300km2Average reserve abundance of 1.5 billion/km2And the production wells are 4207, the capacity is 100 hundred million parts per year, and the number of the production wells and the capacity both account for more than 40 percent of the total number of the production wells and the total capacity of the gas field. The section of surrigo includes 10 development blocks, of which suvier 14 blocks are preferred as research areas: the area of a research area is large (850 km)2) The reservoir conditions are good, and the reservoir scale, the reservoir physical properties and the reserve abundance are representative for the middle area of the gas field; the production is carried out in 2006, which is one of the earliest blocks in the Sulige gas field, the gas well development time is long, and the dynamic data is reliable; and the dynamic and static data in the area are complete, the number of the production wells is 646, and the well area of the encryption test 6 is developed, so that the comprehensive research is suitable for being developed.
And S103, dividing the production wells in the target tight sandstone gas field into a plurality of well types based on preset evaluation indexes.
In an embodiment of the application, parameters such as single-layer effective thickness, accumulated effective thickness, unobstructed flow, initial yield and the like can be used as evaluation indexes, and a production well classification standard is established according to the advantages and disadvantages of development effects.
In an exemplary embodiment, based on the above classification method, the production wells of the fringed gas field may be classified into three types of wells, as shown in table 2 below:
TABLE 2 three-class well division evaluation criteria for Su-Li Ge gas field
In table 2, type I wells: the single-layer thickness is greater than 5, the accumulated thickness is greater than 10, the unimpeded flow is greater than 10, the initial yield is greater than 1.5, and the development effect is best; class II wells: the thickness of the single layer is 3-5, a certain reservoir scale is formed after the multiple layers are stacked, the accumulated thickness is 6-10, the unimpeded flow is 4-10, the initial yield is 0.8-1.5, and the development effect is good; a class III well: the single-layer thickness is less than 3, the number of effective sand bodies is small, the accumulated thickness is less than 6, the unimpeded flow is less than 4, the initial yield is less than 0.8, and the development effect is poor. The classification standard considers more parameters, so that the discrimination accuracy is improved, and the classification standard can be used for rapidly judging the well type of a production well in the early development stage.
S104, determining the control area of each work area, the control area ratio of various wells in each work area and the cumulative production of the wells, and correspondingly determining the well control area of various wells in each work area according to the reservoir scale and the reservoir structure of each work area.
In an embodiment of the present application, the determining the control area of each work area and the control area ratio of each type of well in each work area may be, for example, first determining a master sedimentary facies belt of each work area; and then, correspondingly determining the control area of each work area and the control area ratio of various wells in each work area by taking the master control sedimentary facies belt of each work area as constraint.
Conventional phasing generally refers to depositing microphases. The sedimentary microfacies have a certain control function relative to the distribution of the effective sands, the effective sands have a better corresponding relationship with coarse sand lithofacies such as the bottom of a cardiac beach, the bottom of a riverway filling and the like, however, the sedimentary microfacies have strong heterogeneity in space, the sedimentary microfacies of different layers and different well regions have large differences in development types, development frequencies and development scales, the distribution characteristics are difficult to predict, and the main control factors (namely the main control sedimentary facies) of the effective sands distribution need to be searched from a macroscopic scale. Under the extremely wide and slow structure background of the structure, the river channels are overlapped in multiple periods in the geological history period to form a large-scale braided river system. The braided river system is kilometer-level on the plane, and can contain 2-3 development small layers for a sand group level stratum in the vertical direction. According to the evolution characteristics of a source, water power, a compatible space and an ancient landform, the braided river system can be divided into three zones, namely a superposition zone, a transition zone and an inter-system zone. Between the superposed zones, the transition zones and the systems, the power of the sedimentary water is changed from strong to weak, and the geological conditions of the reservoir are changed from good to bad.
Researches show that for continental facies braided river sediment, the braided river system belt has a strong control effect on the growth type, frequency and scale of sediment microfacies and is a main control geological factor for determining effective sand body distribution and gas well productivity. For example, in an exemplary embodiment, the stacking belt is hydrodynamically strong, sand to land ratio >0.5, cardiac beach development rate is high (average 58%), gas field is enriched by more than 70% of the available sand, and the available sand size is relatively large; the transition zone is arranged at the edge of the superposed zone, the water body energy is weakened, the sand-land ratio is 0.3-0.5, the filling microphase of the main developing riverway (the ratio is up to 72%), the cardiac beach development ratio is only 28%, about 25% of effective sand bodies are contained, the scale of the effective sand bodies is reduced to some extent, and the continuity is poor. The water power between systems is weak, the sand-ground ratio is less than 0.3, the deposition of fine grains such as silty and muddy grains is taken as the main, and effective sand bodies basically do not develop. Therefore, the braided river body frenulum can be used as facies zone restraint, and the control area of each work area and the control area ratio of various wells in each work area are determined. In an exemplary embodiment, based on the above method, a sand-to-ground ratio histogram (as shown in FIG. 2 a) and a well-zone histogram (as shown in FIG. 2 b) of a certain work area of the Suliger field may be obtained, and based thereon, the control area of each work area and the control area ratio of various types of wells in each work area may be determined.
In an embodiment of the present application, the determining the cumulative well yields of the wells in each work area may be, for example, determining the dynamic well reserves of the wells in each work area by using a capacity instability analysis and production curve integration method, and predicting the cumulative well yields of the wells in each work area by combining preset single well development abandonment conditions.
In an exemplary embodiment, for example, a large number of wells with long production time (>500d) and reaching or substantially reaching a quasi-steady state may be selected as analysis samples, the well-average dynamic reserves of each type of well may be evaluated by methods such as capacity instability analysis and production curve integration, and then the well-average cumulative production of each type of well may be predicted by combining single well development abandonment conditions. In general, fluid flow from a reservoir to a wellbore may go through two phases, namely an unstable flow section at the beginning of the well opening and a boundary flow section at the later stage. The skin coefficient, the reservoir permeability, the fracture length and the like of the gas well can be calculated through fitting of the unstable flow section, and the dynamic reserve of the gas well can be calculated through fitting of the boundary flow section. In order to ensure the accuracy and reliability of the calculation result, data quality control is carried out on each gas well participating in calculation, abnormal points can be checked, meanwhile, effective reservoir thickness of perforation layer communication is extracted for each gas well in parameter selection, and physical property data such as porosity, permeability after reservoir fracturing modification and the like are obtained in a weighted average mode on the basis of the effective reservoir thickness. And (3) predicting the accumulated production of various wells in each work area by combining the single-well development abandonment conditions (such as well head pressure less than 3Mpa, daily gas production rate less than 1000 square/day and the like).
In an embodiment of the present application, the correspondingly determining the well control areas of the various wells in each work area according to the reservoir scale and the reservoir structure of each work area may include the following steps:
1) correspondingly determining the value range of the effective sand body plane superposition area of various wells in each work area according to the reservoir scale and the reservoir structure of each work area;
2) determining the average value of the single-well gas leakage area of various wells in each work area;
3) and correspondingly determining the average value of the gas leakage area of the single wells of various wells in each work area as the well average control area of various wells in each work area when the average value of the gas leakage area of the single wells of various wells in each work area is correspondingly located in the value range of the plane superposition area of the effective sand bodies of various wells in each work area.
In an exemplary embodiment, taking a certain type of production well in a certain work area of a Suliger gas field as an example, the effective single sand body width is mainly distributed in the range of 100-500 m and is 310m on average according to close well pattern dissection, interference well testing analysis and combination of data such as effective single sand body thickness, width-to-thickness ratio, length-to-width ratio and the like; the effective single sand body length is mainly distributed in 300-700 m, and is 520m on average. While the average area of the single sand body is 0.16km2The area of a plurality of effective sand bodies encountered by single well drilling after plane superposition is 0.18-0.23 km2Within the range. Considering parameters such as artificial crack half-length, reservoir physical properties and the like, according to a large amount of production well dynamic data, the gas well gas leakage range is limited, and 63% of well leakage area<0.24km224% of wells are at 0.24-0.48km2Only 13% of wells>0.48km2Average of 0.20km2. Due to 0.20km2Is located at 0.18-0.23 km2In range, therefore, 0.20km can be expected2The wells of the same type as the work area are all area controlled.
And S105, correspondingly determining the limit well number of various wells in each work area according to the control area of each work area, the control area ratio of various wells in each work area and the well average control area.
In an embodiment of the present application, correspondingly determining the limit well number of each type of well in each work area according to the control area of each work area, the control area ratio of each type of well in each work area, and the average well control area may include:
1) multiplying the control area of each work area by the control area ratio of various wells in each work area respectively to correspondingly obtain the control area of various wells in each work area;
2) and correspondingly dividing the control area of each well in each work area by the well average control area of each well in each work area to correspondingly obtain the limit well number of each well in each work area.
And S106, multiplying the accumulated well yields of the various wells in each work area by the corresponding limit well number to obtain the limit accumulated well yields of the various wells in each work area.
S1017, determining the utilization reserves of various wells in each work area, and dividing the limit accumulated yield of various wells in each work area by the corresponding utilization reserves to correspondingly obtain the limit recovery rate of various wells in each work area.
In an exemplary embodiment, taking the surrog gas field 14 work area as an example, from the aspects of reservoir geological scale and dynamic air leakage range, three types of well control areas of 0.29 km, 0.22 km and 0.14km can be obtained respectively2I.e., three types of wells corresponding to 3.4, 4.5, and 7.1 openings in maximum pattern density when no disturbance occurs. When the well patterns of the three types of well zones are encrypted to be sufficiently dense, the predicted reserves for production are 286.1, 653.6 and 286.7 million parts respectively, and the total is 1226.4 million parts, which accounts for 95.2 percent of the detected reserves. The average cumulative yield of the three well types is 249.4, 514.4 and 198.9 billion respectively, and the cumulative yield is 962.7 billion. Thus, the ultimate recovery rates for the I, II, and III well zones were 87.2%, 78.7%, and 69.4%, respectively, and the ultimate recovery rate for the entire work zone was 78.5%, as shown in Table 3 below.
TABLE 3 Su 14 Block recovery ratio calculation Table
And S108, determining the ultimate recovery ratio of the target tight sandstone gas field according to the ultimate recovery ratio of various wells in each work area.
In an exemplary embodiment, taking the case of the fringe field, the rates, development profile evaluations, and control ranges of the three types of wells in each work area differ, resulting in different ultimate recovery rates. The medium reservoir has the best condition, the reliability of the ascertained reserves is the strongest, the mobility degree is high, the development effect is good, the proportion of the I + II type wells is more than 70 percent, and the ultimate recovery ratio is 78.5 percent. The large area of water in the west area causes difficult utilization of large-scale reserves, but the physical properties of reservoirs are not poor, so the recovery ratio of the reserves is proved to be low and is 26.8 percent, and the recovery ratio of the reserves is second to the middle area and is 76.6 percent. The east region is relatively compact and has poor physical properties, the proportion of the I + II type well is 62.1 percent, and the ultimate recovery ratio of the movable reserves is 73.8 percent. South areas were the most dense and had poor development, with a class I + II well fraction of less than 40% and a mobile reserve of 71.2% ultimate recovery, as shown in table 4 below.
TABLE 4 recovery ratio of each block of Suliger
And carrying out weighted average on the ultimate recovery ratio of various wells in each work area, and finally obtaining the utilization reserve ultimate recovery ratio of the Suliger gas field of 75.3%.
Referring to fig. 3, a recovery rate calibration apparatus for tight sandstone gas field according to the embodiment of the present application may include:
the target gas field partitioning module 31 may be configured to divide the target tight sandstone gas field into a plurality of work areas according to reservoir geological conditions and development characteristics;
the reservoir characteristic determining module 32 may be configured to determine the reservoir scale and the reservoir structure of each work area;
the production well classification module 33 may be configured to classify the production wells in the target tight sandstone gas field into a plurality of well classes based on preset evaluation indexes;
the control parameter determining module 34 may be configured to determine a control area of each work area, a control area ratio of each well in each work area, and an accumulated well yield, and determine a well control area of each well in each work area according to a reservoir scale and a reservoir structure of each work area;
the limit well number determining module 35 may be configured to correspondingly determine the limit well number of each type of well in each work area according to the control area of each work area, the control area ratio of each type of well in each work area, and the well average control area;
the cumulative yield determination module 36 may be configured to multiply the cumulative well yields of the wells in each work area by the corresponding number of the limit wells, to obtain the limit cumulative well yields of the wells in each work area;
the classified recovery rate determining module 37 can be used for determining the utilization reserves of various wells in each work area, dividing the ultimate accumulated yield of various wells in each work area by the corresponding utilization reserves, and correspondingly obtaining the ultimate recovery rate of various wells in each work area;
and the total recovery rate determining module 38 can be used for determining the ultimate recovery rate of the target tight sandstone gas field according to the ultimate recovery rates of various wells in each work area.
Referring to fig. 4, another tight sand gas field recovery factor calibration device of the embodiments of the present application may include a memory, a processor, and a computer program stored on the memory, the computer program when executed by the processor performing the steps of:
dividing a target tight sandstone gas field into a plurality of work areas according to reservoir geological conditions and development characteristics;
determining the reservoir scale and the reservoir structure of each work area;
dividing the production wells in the target tight sandstone gas field into a plurality of well classes based on preset evaluation indexes;
determining the control area of each work area, the control area ratio of various wells in each work area and the cumulative production of the wells, and correspondingly determining the well control area of various wells in each work area according to the reservoir scale and the reservoir structure of each work area;
correspondingly determining the limit well number of various wells in each work area according to the control area of each work area, the control area ratio of various wells in each work area and the well average control area;
multiplying the accumulated well output of various wells in each work area by the corresponding limit well number to obtain the limit accumulated well output of various wells in each work area;
determining the utilization reserves of various wells in each work area, and dividing the ultimate accumulated yield of various wells in each work area by the corresponding utilization reserves to correspondingly obtain the ultimate recovery ratio of various wells in each work area;
and determining the ultimate recovery ratio of the target tight sandstone gas field according to the ultimate recovery ratio of various wells in each work area. While the process flows described above include operations that occur in a particular order, it should be appreciated that the processes may include more or less operations that are performed sequentially or in parallel (e.g., using parallel processors or a multi-threaded environment).
For convenience of description, the above devices are described as being divided into various units by function, and are described separately. Of course, the functionality of the units may be implemented in one or more software and/or hardware when implementing the present application.
The present invention is described with reference to flowchart illustrations and/or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of the invention. It will be understood that each flow and/or block of the flow diagrams and/or block diagrams, and combinations of flows and/or blocks in the flow diagrams and/or block diagrams, can be implemented by computer program instructions. These computer program instructions may be provided to a processor of a general purpose computer, special purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, create means for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be stored in a computer-readable memory that can direct a computer or other programmable data processing apparatus to function in a particular manner, such that the instructions stored in the computer-readable memory produce an article of manufacture including instruction means which implement the function specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be loaded onto a computer or other programmable data processing apparatus to cause a series of operational steps to be performed on the computer or other programmable apparatus to produce a computer implemented process such that the instructions which execute on the computer or other programmable apparatus provide steps for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
In a typical configuration, a computing device includes one or more processors (CPUs), input/output interfaces, network interfaces, and memory.
The memory may include forms of volatile memory in a computer readable medium, Random Access Memory (RAM) and/or non-volatile memory, such as Read Only Memory (ROM) or flash memory (flash RAM). Memory is an example of a computer-readable medium.
Computer-readable media, including both non-transitory and non-transitory, removable and non-removable media, may implement information storage by any method or technology. The information may be computer readable instructions, data structures, modules of a program, or other data. Examples of computer storage media include, but are not limited to, phase change memory (PRAM), Static Random Access Memory (SRAM), Dynamic Random Access Memory (DRAM), other types of Random Access Memory (RAM), Read Only Memory (ROM), Electrically Erasable Programmable Read Only Memory (EEPROM), flash memory or other memory technology, compact disc read only memory (CD-ROM), Digital Versatile Discs (DVD) or other optical storage, magnetic cassettes, magnetic tape magnetic disk storage or other magnetic storage devices, or any other non-transmission medium that can be used to store information that can be accessed by a computing device. As defined herein, a computer readable medium does not include a transitory computer readable medium such as a modulated data signal and a carrier wave.
It should also be noted that the terms "comprises," "comprising," or any other variation thereof, are intended to cover a non-exclusive inclusion, such that a process, method, or apparatus that comprises a list of elements does not include only those elements but may include other elements not expressly listed or inherent to such process, method, or apparatus. Without further limitation, an element defined by the phrase "comprising an … …" does not exclude the presence of other like elements in a process, method or apparatus that comprises the element.
As will be appreciated by one skilled in the art, embodiments of the present application may be provided as a method, system, or computer program product. Accordingly, the present application may take the form of an entirely hardware embodiment, an entirely software embodiment or an embodiment combining software and hardware aspects. Furthermore, the present application may take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, and the like) having computer-usable program code embodied therein.
The application may be described in the general context of computer-executable instructions, such as program modules, being executed by a computer. Generally, program modules include routines, programs, objects, components, data structures, etc. that perform particular tasks or implement particular abstract data types. The application may also be practiced in distributed computing environments where tasks are performed by remote processing devices that are linked through a communications network. In a distributed computing environment, program modules may be located in both local and remote computer storage media including memory storage devices.
The embodiments in the present specification are described in a progressive manner, and the same and similar parts among the embodiments are referred to each other, and each embodiment focuses on the differences from the other embodiments. In particular, for the system embodiment, since it is substantially similar to the method embodiment, the description is simple, and for the relevant points, reference may be made to the partial description of the method embodiment.
The above description is only an example of the present application and is not intended to limit the present application. Various modifications and changes may occur to those skilled in the art. Any modification, equivalent replacement, improvement, etc. made within the spirit and principle of the present application should be included in the scope of the claims of the present application.
Claims (11)
1. A method for calibrating the recovery ratio of a tight sandstone gas field is characterized by comprising the following steps:
dividing a target tight sandstone gas field into a plurality of work areas according to reservoir geological conditions and development characteristics;
determining the reservoir scale and the reservoir structure of each work area;
dividing the production wells in the target tight sandstone gas field into a plurality of well classes based on preset evaluation indexes;
determining the control area of each work area, the control area ratio of various wells in each work area and the cumulative production of the wells, and correspondingly determining the well control area of various wells in each work area according to the reservoir scale and the reservoir structure of each work area;
correspondingly determining the limit well number of various wells in each work area according to the control area of each work area, the control area ratio of various wells in each work area and the well average control area;
multiplying the accumulated well output of various wells in each work area by the corresponding limit well number to obtain the limit accumulated well output of various wells in each work area;
determining the utilization reserves of various wells in each work area, and dividing the ultimate accumulated yield of various wells in each work area by the corresponding utilization reserves to correspondingly obtain the ultimate recovery ratio of various wells in each work area;
and determining the ultimate recovery ratio of the target tight sandstone gas field according to the ultimate recovery ratio of various wells in each work area.
2. The tight sandstone gas field recovery calibration method of claim 1, wherein the reservoir geological conditions comprise effective thickness, reserve abundance, porosity, and gas saturation; the development characteristics include the three year well-average daily gas production.
3. The tight sandstone gas field recovery calibration method of claim 1, wherein the evaluation criteria comprise monolayer effective thickness, cumulative effective thickness, unobstructed flow rate, and initial production.
4. The tight sandstone gas field recovery calibration method of claim 2, wherein the dividing of the target tight sandstone gas field into a plurality of zones according to reservoir geological conditions and development characteristics comprises:
standardizing the effective thickness, the reserve abundance, the porosity, the gas saturation and the average daily gas production of the three-year-period well to obtain standardized parameters so as to eliminate the influence of different dimensions;
determining the weight of each standardized parameter according to the influence of each standardized parameter on the work area;
according to the formula
Determining parameter values of comprehensive evaluation parameters, and dividing the target tight sandstone gas field into a plurality of work areas according to the parameter values of the comprehensive evaluation parameters;
wherein V is a comprehensive evaluation parameter;
Sgi、hi、Ri、Pirespectively standardized porosity, gas saturation, effective thickness, reserve abundance and three-year-period well average daily gas production; a. b, c, d, e are respectively
Sgi、hi、Ri、PiThe weights of (a), (b), (c), (d) and (e) are positive numbers, and a + b + c + d + e is 1.
5. The tight sandstone gas field recovery calibration method of claim 1, wherein determining the controlled area of each zone and the controlled area ratio of wells in each zone comprises:
determining a main control sedimentary facies belt of each work area;
and correspondingly determining the control area of each work area and the control area ratio of various wells in each work area by taking the master control sedimentary facies belt of each work area as constraint.
6. The tight sandstone gas field recovery calibration method of claim 1, wherein determining the cumulative production of wells from each type of well in each work zone comprises:
and determining the well average dynamic reserves of various wells in each work area by utilizing a capacity instability analysis and production curve integration method, and predicting the well average accumulated yield of various wells in each work area by combining preset single well development abandon conditions.
7. The method for calibrating recovery efficiency of tight sandstone gas field of claim 1, wherein the determining the well control area of each type of well in each work area according to the reservoir scale and the reservoir structure of each work area comprises:
correspondingly determining the value range of the effective sand body plane superposition area of various wells in each work area according to the reservoir scale and the reservoir structure of each work area;
determining the average value of the single-well gas leakage area of various wells in each work area;
and when the average value of the single-well gas leakage areas of the various wells in each work area is correspondingly located in the value range of the plane superposition area of the effective sand bodies of the various wells in each work area, correspondingly determining the average value of the single-well gas leakage areas of the various wells in each work area as the well average control area of the various wells in each work area.
8. The method for calibrating recovery efficiency of tight sandstone gas field of claim 1, wherein said determining the limit number of wells of each type in each zone according to the control area of each zone, the control area ratio of the wells of each type in each zone, and the well-to-well control area comprises:
multiplying the control area of each work area by the control area ratio of various wells in each work area respectively to correspondingly obtain the control area of various wells in each work area;
and correspondingly dividing the control area of each well in each work area by the well average control area of each well in each work area to correspondingly obtain the limit well number of each well in each work area.
9. The method for calibrating recovery ratio of tight sandstone gas field according to claim 1, wherein the determining the ultimate recovery ratio of the target tight sandstone gas field according to the ultimate recovery ratio of each type of well in each work area comprises:
and carrying out weighted average on the ultimate recovery ratio of various wells in each work area to obtain the ultimate recovery ratio of the target compact sandstone gas field.
10. The utility model provides a recovery ratio calibration device in tight sandstone gas field which characterized in that includes:
the target gas field partitioning module is used for dividing the target compact sandstone gas field into a plurality of work areas according to reservoir geological conditions and development characteristics;
the reservoir characteristic determining module is used for determining the reservoir scale and the reservoir structure of each work area;
the production well classification module is used for classifying the production wells in the target tight sandstone gas field into a plurality of well classes based on preset evaluation indexes;
the control parameter determining module is used for determining the control area of each work area, the control area ratio of various wells in each work area and the cumulative output of the wells, and correspondingly determining the well control area of various wells in each work area according to the reservoir scale and the reservoir structure of each work area;
the limit well number determining module is used for correspondingly determining the limit well number of various wells in each work area according to the control area of each work area, the control area ratio of various wells in each work area and the well average control area;
the accumulated yield determining module is used for multiplying the accumulated well yields of various wells in each work area by the corresponding limit well number to obtain the limit accumulated yields of various wells in each work area;
the classified recovery rate determining module is used for determining the utilization reserves of various wells in each work area, dividing the ultimate accumulated yield of various wells in each work area by the corresponding utilization reserves and correspondingly obtaining the ultimate recovery rate of various wells in each work area;
and the total recovery rate determining module is used for determining the ultimate recovery rate of the target tight sandstone gas field according to the ultimate recovery rates of various wells in each work area.
11. A tight sandstone gas field recovery factor calibration device comprising a memory, a processor, and a computer program stored on the memory, wherein the computer program, when executed by the processor, performs the steps of:
dividing a target tight sandstone gas field into a plurality of work areas according to reservoir geological conditions and development characteristics;
determining the reservoir scale and the reservoir structure of each work area;
dividing the production wells in the target tight sandstone gas field into a plurality of well classes based on preset evaluation indexes;
determining the control area of each work area, the control area ratio of various wells in each work area and the cumulative production of the wells, and correspondingly determining the well control area of various wells in each work area according to the reservoir scale and the reservoir structure of each work area;
correspondingly determining the limit well number of various wells in each work area according to the control area of each work area, the control area ratio of various wells in each work area and the well average control area;
multiplying the accumulated well output of various wells in each work area by the corresponding limit well number to obtain the limit accumulated well output of various wells in each work area;
determining the utilization reserves of various wells in each work area, and dividing the ultimate accumulated yield of various wells in each work area by the corresponding utilization reserves to correspondingly obtain the ultimate recovery ratio of various wells in each work area;
and determining the ultimate recovery ratio of the target tight sandstone gas field according to the ultimate recovery ratio of various wells in each work area.
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| CN105160414A (en) * | 2015-07-16 | 2015-12-16 | 中国石油天然气股份有限公司 | Method and device for predicting type of full oil reservoir production area |
| CN105545265A (en) * | 2016-01-05 | 2016-05-04 | 郭建林 | Large-area tight gas reservoir exploitation method |
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