CN110067555B - Method and device for determining minimum dynamic reserve of carbonate oil well - Google Patents
Method and device for determining minimum dynamic reserve of carbonate oil well Download PDFInfo
- Publication number
- CN110067555B CN110067555B CN201810066897.6A CN201810066897A CN110067555B CN 110067555 B CN110067555 B CN 110067555B CN 201810066897 A CN201810066897 A CN 201810066897A CN 110067555 B CN110067555 B CN 110067555B
- Authority
- CN
- China
- Prior art keywords
- oil
- crude oil
- gas
- carbonate
- production
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Active
Links
Images
Classifications
-
- 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
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
- E21B49/08—Obtaining fluid samples or testing fluids, in boreholes or wells
- E21B49/087—Well testing, e.g. testing for reservoir productivity or formation parameters
Abstract
The invention provides a method and a device for determining the minimum dynamic reserve of a carbonate oil well, wherein the method comprises the following steps: obtaining economic limit oil production, crude oil density, pump hanging depth, gas-liquid interface, original stratum crude oil volume coefficient, current stratum crude oil volume coefficient and average comprehensive compression coefficient of the carbonate rock oil well; determining the unit pressure drop oil production according to the economic limit oil production, the crude oil density, the pump hanging depth and the gas-liquid interface of the carbonate rock oil well; and determining the minimum dynamic reserve of the carbonate oil well according to the unit pressure drop oil production, the crude oil density, the original formation crude oil volume coefficient, the current formation crude oil volume coefficient and the average comprehensive compression coefficient. The minimum dynamic reserve of the carbonate well at the economic limit of oil production can thus be calculated.
Description
Technical Field
The invention relates to the field of oil extraction in oil fields, in particular to a method and a device for determining the minimum dynamic reserve of a carbonate oil well.
Background
The main oil production layer section of the carbonate oil well is usually the geological condition of a large seam and a large hole, and the reservoir has the obvious heterogeneity characteristic and is accompanied by larger bottom water body in the oil well.
In the process of exploiting the carbonate rock oil well, once bottom water breaks through and enters a water layer, the water content of the oil layer rapidly rises due to the density difference of crude oil and the bottom water, so that the oil deposit of the oil well production layer is suppressed, and the yield is greatly reduced. And after the oil well is exposed to water, the recovery speed of the oil well is reduced along with the acceleration of the rising speed of bottom water. As described above, the carbonate oil well is difficult to recover, and therefore, economic cost needs to be considered. Under the condition of a certain price, the workover operation of the crude oil has a certain economic limit oil production, if the workover is finished, the produced crude oil has a small oil production, the loss of a production enterprise is caused, and the economic limit oil production can be determined according to economic benefit parameters under general conditions.
However, the minimum dynamic reserve of the carbonate oil well corresponding to the economic limit oil production is difficult to calculate at present, and the practical field production cannot be met only by an empirical method.
Disclosure of Invention
The invention provides a method and a device for determining the minimum dynamic reserve of a carbonate oil well, which can calculate the minimum dynamic reserve of the carbonate oil well at the economic limit oil production.
The invention provides a method for determining the minimum dynamic reserve of a carbonate oil well, which comprises the following steps:
obtaining economic limit oil production, crude oil density, pump hanging depth, gas-liquid interface, original stratum crude oil volume coefficient, current stratum crude oil volume coefficient and average comprehensive compression coefficient of the carbonate rock oil well;
determining the unit pressure drop oil production according to the economic limit oil production, the crude oil density, the pump hanging depth and the gas-liquid interface of the carbonate rock oil well;
and determining the minimum dynamic reserve of the carbonate oil well according to the unit pressure drop oil production, the crude oil density, the original formation crude oil volume coefficient, the current formation crude oil volume coefficient and the average comprehensive compression coefficient.
Optionally, determining the unit pressure drop oil production according to the economic limit oil production, the crude oil density, the pump hanging depth and the gas-liquid interface of the carbonate oil well comprises:
calculating the oil production per pressure drop according to the following formula one:
ΔQ”＝ρ×g×(h2-h1) xDeltaQ (equation one);
wherein Δ Q "represents the economic limit oil production, and ρ representsDensity of said crude oil, h2Indicating the pump hanging depth, h1Represents the gas-liquid interface, Δ Q represents the unit pressure drop oil production, and g represents the gravitational acceleration.
Optionally, the determining the minimum dynamic reserve of the carbonate well according to the unit pressure drop oil production, the crude oil density, the original formation crude oil volume coefficient, the current formation crude oil volume coefficient and the average comprehensive compressibility includes:
calculating the minimum dynamic reserve of the carbonate well according to the following formula two:
ΔQ＝N×Boi×Cot×ρ/Bo(formula two)
Wherein Δ Q represents the oil production per pressure drop, BoiRepresenting the original formation crude oil volume coefficient, CotRepresenting said average integrated compression factor, BoRepresenting the current formation crude oil volume factor, and N representing the minimum dynamic reserve of the carbonate well.
Optionally, obtaining the economic limit oil production of the carbonate oil well comprises:
and determining the economic limit oil production according to the current crude oil price and the total production cost.
Optionally, the obtaining a gas-liquid interface of the carbonate oil well comprises:
obtaining a relation graph of the gas-oil ratio and the gas-liquid interface when the carbonate rock oil well stops spraying;
and determining the gas-liquid interface according to the relation graph of the production gas-oil ratio and the gas-liquid interface and the predicted production gas-oil ratio.
A second aspect of the invention provides a device for determining the minimum dynamic reserve of a carbonate well, comprising:
the acquisition module is used for acquiring the economic limit oil production, the crude oil density, the pumping depth, the gas-liquid interface, the volume coefficient of the crude oil in the original stratum, the volume coefficient of the crude oil in the current stratum and the average comprehensive compression coefficient of the carbonate oil well;
the first determining module is used for determining the unit pressure drop oil production according to the economic limit oil production, the crude oil density, the pump hanging depth and the gas-liquid interface of the carbonate oil well;
and the second determination module is used for determining the minimum dynamic reserve of the carbonate oil well according to the unit pressure drop oil production, the crude oil density, the original formation crude oil volume coefficient, the current formation crude oil volume coefficient and the average comprehensive compression coefficient.
Optionally, the first determining module is specifically configured to:
calculating the oil production per pressure drop according to the following formula one:
ΔQ”＝ρ×g×(h2-h1) xDeltaQ (equation one);
wherein Δ Q "represents the economic limit oil production, ρ represents the crude oil density, h2Indicating the pump hanging depth, h1Represents the gas-liquid interface, Δ Q represents the unit pressure drop oil production, and g represents the gravitational acceleration.
Optionally, the second determining module is specifically configured to:
calculating the minimum dynamic reserve of the carbonate well according to the following formula two:
ΔQ＝N×Boi×Cot×ρ/Bo(formula two)
Wherein Δ Q represents the oil production per pressure drop, BoiRepresenting the original formation crude oil volume coefficient, CotRepresenting said average integrated compression factor, BoRepresenting the current formation crude oil volume factor, and N representing the minimum dynamic reserve of the carbonate well.
The acquisition module includes:
and the first obtaining submodule is used for determining the economic limit oil production according to the current crude oil price and the total production cost.
Optionally, the obtaining module includes:
the second acquisition submodule is used for acquiring a relationship diagram of the produced gas-oil ratio and the gas-liquid interface when the carbonatite oil well stops jetting;
and the determining submodule is used for determining the gas-liquid interface according to the produced gas-oil ratio and gas-liquid interface relation diagram and the predicted produced gas-oil ratio.
A third aspect of the invention provides an apparatus for determining a minimum dynamic reserve for a carbonate well, the apparatus comprising: a processor, a memory for storing instructions, and a transceiver for communicating with other devices, the processor for executing the instructions stored in the memory to cause the apparatus to perform a method as follows:
obtaining economic limit oil production, crude oil density, pump hanging depth, gas-liquid interface, original stratum crude oil volume coefficient, current stratum crude oil volume coefficient and average comprehensive compression coefficient of the carbonate rock oil well;
determining the unit pressure drop oil production according to the economic limit oil production, the crude oil density, the pump hanging depth and the gas-liquid interface of the carbonate rock oil well;
and determining the minimum dynamic reserve of the carbonate oil well according to the unit pressure drop oil production, the crude oil density, the original formation crude oil volume coefficient, the current formation crude oil volume coefficient and the average comprehensive compression coefficient.
Optionally, determining the unit pressure drop oil production according to the economic limit oil production, the crude oil density, the pump hanging depth and the gas-liquid interface of the carbonate oil well comprises:
calculating the oil production per pressure drop according to the following formula one:
ΔQ”＝ρ×g×(h2-h1) xDeltaQ (equation one);
wherein Δ Q "represents the economic limit oil production, ρ represents the crude oil density, h2Indicating the pump hanging depth, h1Represents the gas-liquid interface, deltaQ represents the oil production per unit pressure drop, and g represents.
Optionally, determining the minimum dynamic reserve of the carbonate well according to the unit pressure drop oil production, the crude oil density, the original formation crude oil volume coefficient, the current formation crude oil volume coefficient and the average comprehensive compressibility, and including:
calculating the minimum dynamic reserve of the carbonate well according to the following formula two:
ΔQ＝N×Boi×Cot×ρ/Bo(formula two)
Wherein Δ Q represents the oil production per pressure drop, BoiRepresenting the original formation crude oil volume coefficient, CotRepresenting said average integrated compression factor, BoRepresenting the current formation crude oil volume factor, and N representing the minimum dynamic reserve of the carbonate well.
Optionally, obtaining the economic limit oil production of the carbonate oil well comprises:
and determining the economic limit oil production according to the current crude oil price and the total production cost.
Optionally, the obtaining a gas-liquid interface of the carbonate oil well comprises:
obtaining a relation graph of the gas-oil ratio and the gas-liquid interface when the carbonate rock oil well stops spraying;
and determining the gas-liquid interface according to the relation graph of the production gas-oil ratio and the gas-liquid interface and the predicted production gas-oil ratio.
The invention provides a method and a device for determining the minimum dynamic reserve of a carbonate oil well, which comprise the following steps: obtaining economic limit oil production, crude oil density, pump hanging depth, gas-liquid interface, original stratum crude oil volume coefficient, current stratum crude oil volume coefficient and average comprehensive compression coefficient of the carbonate rock oil well; determining the unit pressure drop oil production according to the economic limit oil production, the crude oil density, the pump hanging depth and the gas-liquid interface of the carbonate rock oil well; and determining the minimum dynamic reserve of the carbonate oil well according to the unit pressure drop oil production, the crude oil density, the original formation crude oil volume coefficient, the current formation crude oil volume coefficient and the average comprehensive compression coefficient. The minimum dynamic reserve of the carbonate well at the economic limit of oil production can thus be calculated.
Drawings
The accompanying drawings, which are incorporated in and constitute a part of this specification, illustrate embodiments consistent with the invention and together with the description, serve to explain the principles of the invention.
FIG. 1 is a flow chart of a method for determining a minimum dynamic reserve for a carbonate well according to an embodiment of the present invention;
FIG. 2 is a graph of gas-to-oil ratio versus gas-to-liquid interface;
FIG. 3 is a schematic structural diagram of a device for determining the minimum dynamic reserve of a carbonate well according to a second embodiment of the present invention;
FIG. 4 is a schematic structural diagram of a minimum dynamic reserve determination device for a carbonate well according to a third embodiment of the present invention;
FIG. 5 is a schematic structural diagram of a device for determining the minimum dynamic reserve of a carbonate well according to a fourth embodiment of the present invention;
fig. 6 is a schematic structural diagram of a device for determining the minimum dynamic reserve of a carbonate well according to a fifth embodiment of the present invention.
With the above figures, certain embodiments of the invention have been illustrated and described in more detail below. The drawings and the description are not intended to limit the scope of the inventive concept in any way, but rather to illustrate it by those skilled in the art with reference to specific embodiments.
Detailed Description
Reference will now be made in detail to the exemplary embodiments, examples of which are illustrated in the accompanying drawings. When the following description refers to the accompanying drawings, like numbers in different drawings represent the same or similar elements unless otherwise indicated. The implementations described in the exemplary embodiments below are not intended to represent all implementations consistent with the present disclosure. Rather, they are merely examples of apparatus and methods consistent with certain aspects of the present disclosure, as detailed in the appended claims.
The carbonate rock is an important reservoir type, and is complex, such as the characteristics of large basin formation time span, large buried depth span, strong heterogeneity, more factors influencing crack solubility development, change of multiple tectonic movements of old stratum and the like, so that the distribution rule of the carbonate rock oil and gas field is not easy to master. China has a large area of carbonate rock distribution areas and huge potential in the exploration field, so that the research significance on carbonate rock oil wells is profound.
The ultimate economic oil production of the carbonate oil well has important practical significance for oil well design and development, the economic ultimate oil production means that the oil field enters the middle and later production periods, the oil production begins to decrease gradually, the economic benefit decreases along with the decrease, when the oil production decreases to a certain value, the production benefit of the oil well can only meet the requirement of the production cost, the oil production at the moment is called the economic ultimate oil production, and after the oil production decreases to the economic ultimate output, if the oil production continues to be exploited, the economic ultimate oil production means that the oil production is lost, so that the economic ultimate oil production of the oil well is researched and has important economic significance.
Fig. 1 is a flowchart of a method for determining a minimum dynamic reserve of a carbonate rock oil well according to an embodiment of the present invention, where the method of the present embodiment is executed by a device for determining a minimum dynamic reserve of a carbonate rock oil well, where the device may be a dedicated computer, a general-purpose computer, a personal computer, a mobile phone, a tablet computer, or the like, and as shown in fig. 1, the method of the present embodiment includes the following steps:
s101, obtaining economic limit oil production, crude oil density, pumping depth, gas-liquid interface, original stratum crude oil volume coefficient, current stratum crude oil volume coefficient and average comprehensive compression coefficient of the carbonate oil well.
The economic limit oil yield is calculated by a plurality of methods, and common calculation models comprise: a weibull (Wcibull) prediction model, an IICZ model, a generalized quinque model, a Logistic (Logistic) prediction model, and an Arps hyperbolic decreasing model. Each oil well should combine the conditions and characteristics of itself, select one or more models for predictive analysis according to the strategy and target of the company, and then combine the predictive analysis results of each model to perform combined predictive analysis to obtain the final predictive result, so as to guide the production operation of the enterprise. For a single well, the yield when its returns equal the cost is the economic limit oil production for that well. The economic limit oil production is related to cost, oil price, daily management, tax rate, etc.
Alternatively, the economic limit oil production is determined based on the current crude oil price and the total cost of production. The total production cost may include total drilling costs, completion costs, bottom layer treatment costs, lift costs, equipment maintenance costs, operating costs, labor costs, surface equipment and gathering costs, and the like. The total cost of production may also be related to the production process, and the equipment and processes used for different production processes may be different, and thus, the completion costs, bottom layer treatment costs, lifting costs, equipment maintenance costs, operation costs, labor costs, surface equipment and transportation costs may be different for different production processes. In general, the labor cost, ground equipment and gathering and transportation cost corresponding to different mining processes are basically the same.
The oil well has a long exploitation period, and one exploitation process can be adopted in the whole exploitation period, and different exploitation processes can be adopted in different exploitation stages.
When one mining process is adopted in the mining period of the oil well, the total production cost corresponding to different mining processes can be respectively calculated, the economic limit oil production quantity corresponding to different mining processes is further obtained according to the current crude oil price, and one economic limit oil production quantity is selected from the plurality of economic limit oil production quantities obtained through calculation according to the budget cost of an enterprise and is used as the economic limit oil production quantity of the carbonate oil well. The economic limit oil production corresponding to the total production cost closest to the estimated cost may be selected as the economic limit oil production for the carbonate well. Due to the characteristics of the carbonate oil well, only a certain specific exploitation process can be adopted, and the economic limit oil production corresponding to the specific exploitation is calculated and used as the economic limit oil production of the carbonate oil well.
When the oil well adopts different exploitation processes in different exploitation stages, the production cost of each exploitation stage is respectively calculated, then the production cost of each exploitation stage is accumulated to obtain the total production cost, and the economic limit oil yield of the carbonate oil well is calculated according to the current crude oil price and the total production cost.
Wherein, the unit of the total production cost can be ten thousand yuan, and the price of the crude oil can be yuan/t.
Crude oil, which is a thick oily liquid with a dark brown color, green fluorescence and a particular odor, is commonly referred to as raw oil. The liquid hydrocarbon mixture is a mixture of a plurality of liquid hydrocarbons such as alkane, cyclane, aromatic hydrocarbon, alkene and the like.
The crude oil density refers to the unit of crude oil density in g/cm per cubic meter of crude oil mass under standard conditions (20 degrees, 0.1MPa), and the value of the crude oil density is 30.75-0.85(g/cm 3). The crude oil density in this example refers to the average crude oil density, which is related to the gas-oil ratio (GOR), and the average crude oil density is different for different GOR. The crude oil density can be obtained by inquiring according to oil deposit information, can also be obtained by measurement, and can also be obtained by measuring for multiple times to obtain the average crude oil density.
The pumping depth refers to the depth from the well head to the oil well pump, and is specifically calculated as follows: the pump hanging depth is equal to oil compensation distance, the length of the oil pipe hanger, the short section length of the oil pipe hanger, the accumulated length of the oil pipe and the length of the tool above a suction inlet of the pump cylinder. The pump hang depth may be predefined.
The ratio of the gas production to the oil production of a well is commonly referred to as the gas-oil ratio, which represents how many cubic meters of natural gas are produced with each ton of crude oil produced. Under the condition of an underground oil layer, a certain amount of natural gas is dissolved in crude oil, the natural gas can cause the expansion of the volume of oil when dissolved in the oil, the specific gravity and the viscosity are reduced, the fluid liquid column pressure is reduced, the oil well is easier to self-blow, and the oil exploitation is facilitated. When the reservoir pressure (the saturation pressure of the crude oil) drops to a certain limit, the dissolved natural gas starts to escape from the crude oil. Reservoir pressure and gas-oil ratio are the main indicators of the self-blowout capability of an oil well. If the oil layer driving mode is hydraulic driving, all gas is dissolved in the petroleum in the process of exploitation, and the gas-oil ratio is equivalent to the gas amount dissolved in the petroleum.
Optionally, the obtaining of the gas-liquid interface of the carbonate oil well specifically comprises: obtaining a relation graph of the gas-oil ratio and the gas-liquid interface when the carbonate rock oil well stops spraying; determining the produced gas-oil ratio according to the produced gas-oil ratio and gas-liquid interface relation graph and the predicted produced gas-oil ratioThe gas-liquid interface. FIG. 2 is a graph of gas-oil ratio versus gas-liquid interface, in FIG. 2, the horizontal axis represents the gas-oil ratio, the vertical axis represents the gas-liquid interface, and the unit of the gas-oil ratio is cm3And/t, the unit of the gas-liquid interface is m (meter). As can be seen from fig. 2, the gas-oil ratio gradually increases as the gas-liquid interface increases.
The volume coefficient of crude oil, also called underground volume coefficient of crude oil, is the ratio of the volume of crude oil in the ground (i.e. the volume of formation oil) to the volume of crude oil degassed at the surface, i.e. the volume of crude oil in the ground
Wherein, VfRepresenting the volume of crude oil in the ground, VsThe volume of the crude oil after being degassed on the ground is represented, and the volume coefficient of the crude oil is dimensionless. The original formation crude oil volume coefficient refers to an oil layer volume coefficient before an oil well in an oil reservoir is exploited, the current formation crude oil volume coefficient refers to an oil layer volume coefficient before the oil well is exploited to the current oil layer volume coefficient, and the original formation crude oil volume coefficient and the current formation crude oil volume coefficient can be obtained through measurement.
The integrated compression factor means: the volume that can be displaced from a unit volume of rock by elastic energy for every 1MPa drop in pressure. The average integrated compression factor means: average value of average volume that can be discharged from unit volume of rock by means of elastic energy every 1MPa of pressure drop of all wells in the block. Can be obtained by simulating core experiments or calculation, such as: calculated by the following formula:
wherein, C0Denotes the compression factor of oil, CwDenotes the compressibility factor of water, CpRepresenting the compressibility of the rock pore, V0Denotes the volume of oil in the pores, VwDenotes the volume of water in the pores, VpRepresenting the volume of the rock pore space, dp representing the reduced pressure, VfRepresenting the volume of the rock;
will be provided with
By bringing into the above formula to obtain C3＝φ(SoiC0+SwiCw+Cp)；
Where φ represents the porosity of the rock, SoiRepresenting the original oil saturation, SwiIndicating irreducible water saturation, C3Representing the volume of fluid displaced by elastic energy per unit volume of rock per 1MPa of pressure drop.
And S102, determining the unit pressure drop oil production according to the economic limit oil production, the crude oil density, the pump hanging depth and the gas-liquid interface of the carbonate oil well.
The unit of the unit pressure drop oil production is t/MPa (ton per MPa), and the unit pressure drop oil production refers to the amount of oil which can be produced when the pressure drop is reduced by 1 MPa. Alternatively, the oil production per pressure drop may be calculated according to the following formula one:
ΔQ”＝ρ×g×(h2-h1) xDeltaQ (equation one);
wherein Δ Q "represents the economic limit oil production, ρ represents the crude oil density, h2Indicating the pump hanging depth, h1Representing the gas-liquid interface and deltaq the oil production per pressure drop.
As can be seen from the formula I, the economic limit oil production is equal to the unit pressure drop oil production (t/MPa) multiplied by the mechanical recovery reduced back pressure (MPa), and the mechanical recovery reduced back pressure is equal to rho multiplied by g multiplied by h2-h1). Transforming the formula one to obtain:
so that the unit pressure drop oil production can be calculated.
And S103, determining the minimum dynamic reserve of the carbonate oil well according to the unit pressure drop oil production, the crude oil density, the original formation crude oil volume coefficient, the current formation crude oil volume coefficient and the average comprehensive compression coefficient.
Alternatively, the minimum dynamic reserve of the carbonate well may be calculated according to the following equation two:
ΔQ＝N×Boi×Cot×ρ/Bo(formula two)
Wherein, DeltaQ represents the unit pressure drop oil production, BoiRepresenting the original formation crude oil volume coefficient, CotRepresents the average integrated compression factor, BoRepresenting the current formation crude oil volume coefficient, and N represents the minimum dynamic reserve of the carbonate well.
Table one is a schematic representation of one measurement of a carbonate well:
watch 1
In the embodiment, the economic limit oil production, the crude oil density, the pumping depth, the gas-liquid interface, the volume coefficient of the crude oil in the original stratum, the volume coefficient of the crude oil in the current stratum and the average comprehensive compression coefficient of the carbonate oil well are obtained; determining the unit pressure drop oil production according to the economic limit oil production, the crude oil density, the pump hanging depth and the gas-liquid interface of the carbonate rock oil well; and determining the minimum dynamic reserve of the carbonate oil well according to the unit pressure drop oil production, the crude oil density, the original formation crude oil volume coefficient, the current formation crude oil volume coefficient and the average comprehensive compression coefficient. The minimum dynamic reserve of the carbonate well at the economic limit of oil production can thus be calculated.
Fig. 3 is a schematic structural diagram of a device for determining a minimum dynamic reserve of a carbonate well according to a second embodiment of the present invention, and as shown in fig. 3, the device according to the second embodiment includes:
the acquisition module 11 is used for acquiring the economic limit oil production, the crude oil density, the pumping depth, the gas-liquid interface, the volume coefficient of the original formation crude oil, the volume coefficient of the current formation crude oil and the average comprehensive compression coefficient of the carbonate oil well;
the first determining module 12 is used for determining the unit pressure drop oil production according to the economic limit oil production, the crude oil density, the pump hanging depth and the gas-liquid interface of the carbonate oil well;
and a second determining module 13, configured to determine a minimum dynamic reserve of the carbonate well according to the unit pressure drop oil production, the crude oil density, the original formation crude oil volume coefficient, the current formation crude oil volume coefficient, and the average comprehensive compression coefficient.
Optionally, the first determining module 12 is specifically configured to:
calculating the oil production per pressure drop according to the following formula one:
ΔQ”＝ρ×g×(h2-h1) xDeltaQ (equation one);
wherein Δ Q "represents the economic limit oil production, ρ represents the crude oil density, h2Indicating the pump hanging depth, h1Represents the gas-liquid interface, and Δ Q represents the oil production per pressure drop.
Optionally, the second determining module 13 is specifically configured to:
calculating the minimum dynamic reserve of the carbonate well according to the following formula two:
ΔQ＝N×Boi×Cot×ρ/Bo(formula two)
Wherein Δ Q represents the oil production per pressure drop, BoiRepresenting the original formation crude oil volume coefficient, CotRepresenting said average integrated compression factor, BoRepresenting the current formation crude oil volume factor, and N representing the minimum dynamic reserve of the carbonate well.
Fig. 4 is a schematic structural diagram of a device for determining a minimum dynamic reserve of a carbonate well according to a third embodiment of the present invention, as shown in fig. 4, the device provided in this embodiment is based on the device shown in fig. 3, and the obtaining module 11 includes:
a first obtaining submodule 111 for determining said economic limit oil production according to the current crude oil price and the total production cost.
Fig. 5 is a schematic structural diagram of a device for determining a minimum dynamic reserve of a carbonate well according to a fourth embodiment of the present invention, and as shown in fig. 5, the device according to the fourth embodiment is based on the device shown in fig. 4, and the obtaining module 11 further includes:
a second obtaining submodule 112, configured to obtain a relationship diagram between a produced gas-oil ratio and a gas-liquid interface when the carbonatite oil well stops jetting;
and the determining submodule 113 is used for determining the gas-liquid interface according to the produced gas-oil ratio and gas-liquid interface relation diagram and the predicted produced gas-oil ratio.
The apparatuses provided in the second to fourth embodiments may be configured to execute the method of the first embodiment, and the specific implementation manner and the technical effect are similar, which are not described herein again.
Fig. 6 is a schematic structural diagram of a device for determining a minimum dynamic reserve of a carbonate well according to a fifth embodiment of the present invention, as shown in fig. 6, the device according to the present embodiment includes: a processor 21, a memory 22 and a transceiver 23, the memory 22 being configured to store instructions and the transceiver 23 being configured to communicate with other devices, the processor 21 being configured to execute the instructions stored in the memory to cause the apparatus to perform the method as follows:
obtaining economic limit oil production, crude oil density, pump hanging depth, gas-liquid interface, original stratum crude oil volume coefficient, current stratum crude oil volume coefficient and average comprehensive compression coefficient of the carbonate rock oil well;
determining the unit pressure drop oil production according to the economic limit oil production, the crude oil density, the pump hanging depth and the gas-liquid interface of the carbonate rock oil well;
and determining the minimum dynamic reserve of the carbonate oil well according to the unit pressure drop oil production, the crude oil density, the original formation crude oil volume coefficient, the current formation crude oil volume coefficient and the average comprehensive compression coefficient.
Optionally, determining the unit pressure drop oil production according to the economic limit oil production, the crude oil density, the pump hanging depth and the gas-liquid interface of the carbonate oil well comprises:
calculating the oil production per pressure drop according to the following formula one:
ΔQ”＝ρ×g×(h2-h1) xDeltaQ (equation one);
wherein Δ Q "represents the economic limit oil production, ρ represents the crude oil density, h2Indicating the pump hanging depth, h1Represents the gas-liquid interface, deltaQ represents the oil production per unit pressure drop, and g represents.
Optionally, determining the minimum dynamic reserve of the carbonate well according to the unit pressure drop oil production, the crude oil density, the original formation crude oil volume coefficient, the current formation crude oil volume coefficient and the average comprehensive compressibility, and including:
calculating the minimum dynamic reserve of the carbonate well according to the following formula two:
ΔQ＝N×Boi×Cot×ρ/Bo(formula two)
Wherein Δ Q represents the oil production per pressure drop, BoiRepresenting the original formation crude oil volume coefficient, CotRepresenting said average integrated compression factor, BoRepresenting the current formation crude oil volume factor, and N representing the minimum dynamic reserve of the carbonate well.
Optionally, obtaining the economic limit oil production of the carbonate oil well comprises:
and determining the economic limit oil production according to the current crude oil price and the total production cost.
Optionally, the obtaining a gas-liquid interface of the carbonate oil well comprises:
obtaining a relation graph of the gas-oil ratio and the gas-liquid interface when the carbonate rock oil well stops spraying;
and determining the gas-liquid interface according to the relation graph of the production gas-oil ratio and the gas-liquid interface and the predicted production gas-oil ratio.
It is to be understood that the processor referred to in this disclosure may be a Central Processing Unit (CPU), general purpose processor, Digital Signal Processor (DSP), Application Specific Integrated Circuit (ASIC), Field Programmable Gate Array (FPGA) or other programmable logic device, transistor logic device, hardware component, or any combination thereof. Which may implement or perform the various illustrative logical blocks, modules, and circuits described in connection with the disclosure. The processor may also be a combination of computing functions, e.g., comprising one or more microprocessors, DSPs, and microprocessors, among others.
Other embodiments of the disclosure will be apparent to those skilled in the art from consideration of the specification and practice of the disclosure disclosed herein. This application is intended to cover any variations, uses, or adaptations of the disclosure following, in general, the principles of the disclosure and including such departures from the present disclosure as come within known or customary practice within the art to which the disclosure pertains. It is intended that the specification and examples be considered as exemplary only, with a true scope and spirit of the disclosure being indicated by the following claims.
It will be understood that the present disclosure is not limited to the precise arrangements described above and shown in the drawings and that various modifications and changes may be made without departing from the scope thereof. The scope of the present disclosure is limited only by the appended claims.
Claims (6)
1. A method for determining a minimum dynamic reserve for a carbonate well, comprising:
obtaining economic limit oil production, crude oil density, pump hanging depth, gas-liquid interface, original stratum crude oil volume coefficient, current stratum crude oil volume coefficient and average comprehensive compression coefficient of the carbonate rock oil well;
determining the unit pressure drop oil production according to the economic limit oil production, the crude oil density, the pump hanging depth and the gas-liquid interface of the carbonate rock oil well;
determining the minimum dynamic reserve of the carbonate oil well according to the unit pressure drop oil production, the crude oil density, the original formation crude oil volume coefficient, the current formation crude oil volume coefficient and the average comprehensive compression coefficient;
wherein, according to the economic limit oil production, crude oil density, pump hanging degree of depth and gas-liquid interface of carbonate oil well, confirm unit pressure drop oil production, include:
calculating the oil production per pressure drop according to the following formula one:
ΔQ”＝ρ×g×(h2-h1) xDeltaQ (equation one);
wherein Δ Q "represents the economic limit oil production, ρ represents the crude oil density, h2Indicating the pump hanging depth, h1Representing the gas-liquid interface, delta Q representing the unit pressure drop oil production, and g representing the gravity acceleration;
determining the minimum dynamic reserve of the carbonate oil well according to the unit pressure drop oil production, the crude oil density, the original formation crude oil volume coefficient, the current formation crude oil volume coefficient and the average comprehensive compression coefficient, wherein the determination comprises the following steps:
calculating the minimum dynamic reserve of the carbonate well according to the following formula two:
ΔQ＝N×Boi×Cot×ρ/Bo(formula two)
Wherein Δ Q represents the oil production per pressure drop, BoiRepresenting the original formation crude oil volume coefficient, CotRepresenting said average integrated compression factor, BoRepresenting the current formation crude oil volume factor, and N representing the minimum dynamic reserve of the carbonate well.
2. The method of claim 1, wherein said obtaining an economic limit oil production of a carbonate well comprises:
and determining the economic limit oil production according to the current crude oil price and the total production cost.
3. The method of claim 1, wherein the obtaining a gas-liquid interface of a carbonate well comprises:
obtaining a relation graph of the gas-oil ratio and the gas-liquid interface when the carbonate rock oil well stops spraying;
and determining the gas-liquid interface according to the relation graph of the production gas-oil ratio and the gas-liquid interface and the predicted production gas-oil ratio.
4. A device for determining the minimum dynamic reserve of a carbonate well, comprising:
the acquisition module is used for acquiring the economic limit oil production, the crude oil density, the pumping depth, the gas-liquid interface, the volume coefficient of the crude oil in the original stratum, the volume coefficient of the crude oil in the current stratum and the average comprehensive compression coefficient of the carbonate oil well;
the first determining module is used for determining the unit pressure drop oil production according to the economic limit oil production, the crude oil density, the pump hanging depth and the gas-liquid interface of the carbonate oil well;
the second determination module is used for determining the minimum dynamic reserve of the carbonate oil well according to the unit pressure drop oil production, the crude oil density, the original formation crude oil volume coefficient, the current formation crude oil volume coefficient and the average comprehensive compression coefficient;
the first determining module is specifically configured to:
calculating the oil production per pressure drop according to the following formula one:
ΔQ”＝ρ×g×(h2-h1) xDeltaQ (equation one);
wherein Δ Q "represents the economic limit oil production, ρ represents the crude oil density, h2Indicating the pump hanging depth, h1Representing the gas-liquid interface, delta Q representing the unit pressure drop oil production, and g representing the gravity acceleration;
the second determining module is specifically configured to:
calculating the minimum dynamic reserve of the carbonate well according to the following formula two:
ΔQ＝N×Boi×Cot×ρ/Bo(formula two)
Wherein Δ Q represents the oil production per pressure drop, BoiRepresenting the original formation crude oil volume coefficient, CotRepresenting said average integrated compression factor, BoRepresenting the current formation crude oil volume factor, and N representing the minimum dynamic reserve of the carbonate well.
5. The apparatus of claim 4, wherein the obtaining module comprises:
and the first obtaining submodule is used for determining the economic limit oil production according to the current crude oil price and the total production cost.
6. The apparatus of claim 4, wherein the obtaining module comprises:
the second acquisition submodule is used for acquiring a relationship diagram of the produced gas-oil ratio and the gas-liquid interface when the carbonatite oil well stops jetting;
and the determining submodule is used for determining the gas-liquid interface according to the produced gas-oil ratio and gas-liquid interface relation diagram and the predicted produced gas-oil ratio.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201810066897.6A CN110067555B (en) | 2018-01-24 | 2018-01-24 | Method and device for determining minimum dynamic reserve of carbonate oil well |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201810066897.6A CN110067555B (en) | 2018-01-24 | 2018-01-24 | Method and device for determining minimum dynamic reserve of carbonate oil well |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN110067555A CN110067555A (en) | 2019-07-30 |
| CN110067555B true CN110067555B (en) | 2022-03-29 |
Family
ID=67365406
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201810066897.6A Active CN110067555B (en) | 2018-01-24 | 2018-01-24 | Method and device for determining minimum dynamic reserve of carbonate oil well |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN110067555B (en) |
Families Citing this family (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN112746839B (en) * | 2019-10-31 | 2023-07-25 | 中国石油天然气股份有限公司 | Method and device for determining volume coefficient of crude oil |
Citations (9)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN102767356A (en) * | 2012-08-08 | 2012-11-07 | 张方礼 | Method for using combustion and vapor combination flooding to exploit thick oil |
| CN104314539A (en) * | 2014-10-20 | 2015-01-28 | 中国石油天然气股份有限公司 | Artificial foaming-oil huff and puff oil production method for heavy oil reservoir |
| CN105243182A (en) * | 2015-09-08 | 2016-01-13 | 中国石油天然气股份有限公司 | Method for calculating dynamic reserve of dense oil fractured horizontal well |
| CN105464652A (en) * | 2015-12-03 | 2016-04-06 | 恒泰艾普石油天然气技术服务股份有限公司 | Dynamic reserve calculation method and system for fracture and cave type carbonatite oil reservoir fracture and cave unit |
| CN105673001A (en) * | 2014-11-20 | 2016-06-15 | 中国石油天然气股份有限公司 | Processing method for reduction in formation pressure of carbonatite single well |
| CN105956938A (en) * | 2016-05-18 | 2016-09-21 | 恒泰艾普（北京）能源科技研究院有限公司 | Fracture-vug type oil reservoir dynamic reserve calculation method |
| WO2017078671A1 (en) * | 2015-11-02 | 2017-05-11 | Halliburton Energy Services Inc. | Method and apparatus for fast economic analysis of production of fracture-stimulated wells |
| CN106846157A (en) * | 2016-12-28 | 2017-06-13 | 中国石油天然气股份有限公司 | A kind of Reserves Assessment method in steam soak later stage under SEC criterions |
| WO2017188858A1 (en) * | 2016-04-28 | 2017-11-02 | Schlumberger Canada Limited | Reservoir performance system |
Family Cites Families (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN106150477B (en) * | 2015-04-23 | 2019-11-08 | 中国石油化工股份有限公司 | A kind of method of the single well controlled reserves of determining fracture-pore reservoir |
| CN106127604B (en) * | 2016-06-17 | 2019-05-07 | 中国石油天然气股份有限公司 | A kind of dynamic holdup calculation method and device |
-
2018
- 2018-01-24 CN CN201810066897.6A patent/CN110067555B/en active Active
Patent Citations (9)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN102767356A (en) * | 2012-08-08 | 2012-11-07 | 张方礼 | Method for using combustion and vapor combination flooding to exploit thick oil |
| CN104314539A (en) * | 2014-10-20 | 2015-01-28 | 中国石油天然气股份有限公司 | Artificial foaming-oil huff and puff oil production method for heavy oil reservoir |
| CN105673001A (en) * | 2014-11-20 | 2016-06-15 | 中国石油天然气股份有限公司 | Processing method for reduction in formation pressure of carbonatite single well |
| CN105243182A (en) * | 2015-09-08 | 2016-01-13 | 中国石油天然气股份有限公司 | Method for calculating dynamic reserve of dense oil fractured horizontal well |
| WO2017078671A1 (en) * | 2015-11-02 | 2017-05-11 | Halliburton Energy Services Inc. | Method and apparatus for fast economic analysis of production of fracture-stimulated wells |
| CN105464652A (en) * | 2015-12-03 | 2016-04-06 | 恒泰艾普石油天然气技术服务股份有限公司 | Dynamic reserve calculation method and system for fracture and cave type carbonatite oil reservoir fracture and cave unit |
| WO2017188858A1 (en) * | 2016-04-28 | 2017-11-02 | Schlumberger Canada Limited | Reservoir performance system |
| CN105956938A (en) * | 2016-05-18 | 2016-09-21 | 恒泰艾普（北京）能源科技研究院有限公司 | Fracture-vug type oil reservoir dynamic reserve calculation method |
| CN106846157A (en) * | 2016-12-28 | 2017-06-13 | 中国石油天然气股份有限公司 | A kind of Reserves Assessment method in steam soak later stage under SEC criterions |
Non-Patent Citations (10)
| Title |
|---|
| A New Calculation Method for Single Well Controlled Dynamic Reserves of Tight Gas;Cai Zhenhua et al.;《Society of Petroleum Engineers》;20130331;第1-5页 * |
| A New Method for Forecasting Dynamic Reserve of Fractured Gas Well in Low-permeability and Tight Gas Reservoir;Luo Ruilan et al.;《Society of Petroleum Engineers》;20100608;第1-8页 * |
| Screening and Evaluation of Preponderant Reserves in Oil Or Gas Fields;Kai Zhang et al.;《ICCIS 2010》;20101231;第274-277页 * |
| 不同类型油藏动态测试指标表征方法应用研究;张平等;《中国优秀硕士学位论文全文数据库基础科学辑》;20120515(第5期);第A011-96页 * |
| 乌5井区百口泉组低渗油藏开发方式优化研究;罗元等;《中国优秀硕士学位论文全文数据库工程科技Ⅰ辑》;20170315(第3期);第B019-323页 * |
| 关于单井控制储量经济极限的研究;谢绪权等;《石油勘探与开发》;19860630(第3期);第69-72页 * |
| 利用压力动态资料估算单井控制储量;刘振宇等;《钻采工艺》;20040131(第1期);第24-27页 * |
| 油井产量经济极限和控制储量极限的预测决策支持系统;贾冀五等;《石油学报》;19881231(第4期);第122-130页 * |
| 用单井经济极限储量评价复杂断块气藏可开发储量;靳秀菊等;《天然气工业》;20030228(第2期);第131-132页 * |
| 缝洞型油藏动态储量计算的一种新方法——以塔里木盆地哈拉哈塘油田为例;陈利新等;《新疆石油地质》;20160630;第37卷(第3期);第356-359页 * |
Also Published As
| Publication number | Publication date |
|---|---|
| CN110067555A (en) | 2019-07-30 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN107563899B (en) | Oil-gas well productivity prediction method and device | |
| CN101253402B (en) | Method for evaluating unsaturation coalbed gas storage layer | |
| CN110334868A (en) | A kind of method that coupled fluid flowing predicts the optimal stewing well time with geological stress | |
| CN103089224A (en) | Fracturing method for comprehensively controlling fracture height | |
| CN106522928B (en) | Well testing method for unstable pressure drop of well logging head by stopping pump after acidizing and fracturing | |
| CN103498663B (en) | A kind of sucker rod pump hoisting system pumping technological parameter defining method and device | |
| CN104314547A (en) | HAFD segmented optimization method and system | |
| CN109424362B (en) | Method and system for calculating single-well control crude oil reserve of bottom water reservoir | |
| CN104975827A (en) | Substance balance method for predicting carbon dioxide flooding oil reservoir indexes | |
| RU2433250C1 (en) | Method of oil development by using periodic operation of producer wells with operation portions varying with oil well fluid density variation | |
| CN107130955B (en) | Method for determining bottom hole flowing pressure and method for determining natural energy of reservoir | |
| Yi et al. | Determination of dynamic reserves of fractured horizontal wells in tight oil reservoirs by multi-region material balance method | |
| CN110067555B (en) | Method and device for determining minimum dynamic reserve of carbonate oil well | |
| CN103498661B (en) | A kind of method determining oil reservoir physical data under high pressure | |
| CN111963161B (en) | Method and device for determining hidden abnormal oil well | |
| CN110273672B (en) | Fracture-cavity type oil reservoir space structure well pattern design method based on variation coefficient | |
| CN111582532A (en) | Stress-sensitive oil reservoir horizontal well fluid production capacity prediction method and device | |
| CN109424355B (en) | Method and device for acquiring collapse state of oil well | |
| CN110094200A (en) | The method and apparatus for predicting coal bed gas well maximum water yield per day | |
| CN111680814B (en) | Elastic-driving reasonable production allocation optimization method for fractured-vuggy carbonate reservoir | |
| CN117648886B (en) | High-pressure pulse jet reservoir reconstruction pressure prediction method and device | |
| US20210270124A1 (en) | Method for distinguishing authenticity of high-pressure physical property parameters of oil reservoirs | |
| US10400592B2 (en) | Methodology for presenting dumpflood data | |
| Yao et al. | Case study on diagnosis and identify the degree of bottom hole liquid accumulation in double-branch horizontal wells in PCOC | |
| CN113537668B (en) | Method and system for evaluating crude oil geological reserves in unfilled karst cave |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| GR01 | Patent grant | ||
| GR01 | Patent grant |