CN111927444B - Method for evaluating gas injection capacity of depleted oil-gas reservoir gas storage - Google Patents
Method for evaluating gas injection capacity of depleted oil-gas reservoir gas storage Download PDFInfo
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- 239000007924 injection Substances 0.000 title claims abstract description 90
- 238000002347 injection Methods 0.000 title claims abstract description 90
- 238000000034 method Methods 0.000 title claims abstract description 14
- 239000007789 gas Substances 0.000 claims abstract description 112
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims abstract description 88
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims abstract description 58
- 239000003345 natural gas Substances 0.000 claims abstract description 54
- 229910052757 nitrogen Inorganic materials 0.000 claims abstract description 21
- 229910001873 dinitrogen Inorganic materials 0.000 claims abstract description 19
- 238000012360 testing method Methods 0.000 claims abstract description 9
- 230000015572 biosynthetic process Effects 0.000 claims description 10
- QJGQUHMNIGDVPM-UHFFFAOYSA-N nitrogen(.) Chemical compound [N] QJGQUHMNIGDVPM-UHFFFAOYSA-N 0.000 claims description 7
- 230000000087 stabilizing effect Effects 0.000 claims description 5
- 238000004458 analytical method Methods 0.000 claims description 4
- 239000002343 natural gas well Substances 0.000 claims description 4
- 230000001143 conditioned effect Effects 0.000 claims description 3
- 238000004519 manufacturing process Methods 0.000 claims description 3
- 238000011160 research Methods 0.000 abstract description 3
- 238000010276 construction Methods 0.000 abstract description 2
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- 239000002912 waste gas Substances 0.000 abstract 1
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- 239000004215 Carbon black (E152) Substances 0.000 description 1
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- 238000011156 evaluation Methods 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
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Abstract
The invention discloses a method for evaluating the gas injection capacity of a depleted oil-gas reservoir, wherein the depleted oil-gas reservoir is a gas reservoir built by utilizing a depleted waste gas reservoir or a retired gas reservoir which is exploited to a certain degree. Due to the fact that natural gas of part of oil and gas fields is under-produced, enough gas sources are not available for test injection tests in the early-stage pre-feasibility research stage of gas storage construction, and the gas injection capability of the gas storage cannot be clearly achieved. The invention adopts nitrogen gas to replace natural gas as an injection medium, and evaluates the gas injection capability of the gas storage, thereby determining the gas injection working system and designing a gas injection pipe column. The invention provides a method for evaluating the natural gas injection capacity of a gas storage by using pilot injection of nitrogen aiming at a depleted oil-gas reservoir, which determines a gas injection working system and designs a gas injection pipe column, provides a basis for designing the gas storage and further saves investment.
Description
Technical Field
The invention relates to the field of oil and gas resource development, in particular to a method for evaluating gas injection capacity of a depleted oil and gas reservoir.
Background
Depleted hydrocarbon reservoirs are gas reservoirs constructed using depleted spent reservoirs that have been mined or retired to some extent. Oil and gas exploration and development workers accurately master the geological conditions of the gas storage, such as oil (gas) reservoir area, reservoir thickness, cover gas seal, original formation pressure and temperature, gas storage layer porosity, permeability, homogeneity, gas well operation system and the like, and do not need to perform geological exploration. Part of gas wells and ground facilities for developing oil and gas fields can be repeatedly used for underground gas storage, the quantity of cushion gas to be supplemented and injected is small, the storage building period is short, and the investment and operation cost is low. Due to the fact that natural gas of part of oil and gas fields is under-produced, enough gas sources are not available for test injection tests in the early-stage pre-feasibility research stage of gas storage construction, and the gas injection capability of the gas storage cannot be clearly achieved. Therefore, nitrogen can be used as an injection medium instead of natural gas to evaluate the gas injection capacity of the gas storage, so that the gas injection working system is determined and the gas injection pipe column is designed. However, natural gas and nitrogen have obvious physical and chemical property differences, and how to evaluate the natural gas injection capacity of the gas storage by using the injected nitrogen is a difficult problem to be solved urgently.
Disclosure of Invention
The invention aims to solve the technical problem of providing an evaluation method of the gas injection capability of a depleted oil-gas reservoir, aiming at the depleted oil-gas reservoir, determining a gas injection working system and designing a gas injection pipe column, providing a basis for designing the gas reservoir and further saving investment.
In order to solve the technical problems, the invention adopts the technical scheme that: a method for evaluating the gas injection capacity of a depleted oil-gas reservoir gas storage comprises the following steps:
(1) designing 3-4 stable nitrogen gas injection quantities by adopting a natural gas well productivity well testing method, injecting nitrogen gas according to the sequence that the gas injection quantities gradually increase from small to small, lowering a cable direct-reading pressure gauge into the middle depth H of a reservoir stratum of a depleted oil and gas reservoir, recording the flowing pressure and temperature of each stable nitrogen gas injection quantity until the flowing pressure is stable, and measuring the stable nitrogen gas injection quantity qNCorresponding steady flow pressure pwfStable flow temperature TwfStabilizing the wellhead pressure pwhAnd stabilizing the wellhead temperature TwhFinally closing the well to measure the formation pressure pR；
(2) According to the standard-Katz chart, calculating a deviation factor Z of the nitrogen at the ground pressure of 0.101MPa and the ground temperature of 25 DEG C1Nitrogen gas at steady flow pressure pwfAnd a stable flow temperature TwfDeviation factor Z of2Deviation factor Z of natural gas at ground pressure of 0.101MPa and ground temperature of 25 DEG C3Natural gas at steady flow pressure pwfAnd stabilizing the flowTemperature TwfDeviation factor Z of4；
(3) Calculating the stable gas injection quantity q of nitrogenNCorresponding natural gas injection quantity qg：
Z1-a deviation factor of nitrogen at a ground pressure of 0.101MPa and a ground temperature of 25 ℃; z2Nitrogen at steady flow pressure pwfAnd a stable flow temperature TwfA deviation factor of (d); z3-deviation factor of natural gas at ground pressure of 0.101MPa and ground temperature of 25 ℃; z4At steady flow pressure p of natural gaswfAnd a stable flow temperature TwfA deviation factor of (d);
(4) drawing the natural gas injection capacity curve in a rectangular coordinate system, namely
And q isgThe relationship curve of (1);
(5) and (3) regressing a binomial capacity equation according to the capacity curve:
(6) obtaining different stratum pressure p according to gas well node analysis methodRMaximum gas injection amount of the conditioned bet gas well:
in the formula:
pwh≤pprocess limitation
Lambda is the oil pipe resistance coefficient, and the value is 0.015; p is a radical ofwh-stabilizing wellhead pressure, MPa; t isav-the average temperature in the wellbore,
K；Zav-average pressure p in the wellboreavAnd the average temperature T in the wellboreavA natural gas deviation factor of; p is a radical ofav-the average pressure in the wellbore,
MPa；γgnatural gas relative density, 0.6; h-depth of the middle of the reservoir, m; p is a radical ofProcess limitation-wellhead equipment pressure, the nameplate having a label; d-the inner diameter of the oil pipe, obtained from the basic parameters of the injection and production well, m.
(7) Drawing OPR and IPR curves in a rectangular coordinate system, and selecting the natural gas injection amount corresponding to the intersection point of the two curves as the maximum natural gas injection amount q under different formation pressures and different pipe column conditionsGAnd the maximum natural gas injection amount is used for evaluating the gas injection capacity of the depleted oil-gas reservoir gas storage.
The invention has the beneficial effects that: the invention provides scientific test data for determining a gas injection working system and designing a gas injection pipe column in the design of the gas storage library when the gas injection capacity of the gas storage library is evaluated by adopting pilot injection nitrogen under the condition that a target gas reservoir lacks a pilot injection natural gas source in the pre-feasibility research stage of a depleted oil-gas reservoir, thereby saving investment.
Drawings
FIG. 1 is a graph showing the change of the gas injection amount and the flow pressure with time in the case of injecting nitrogen gas in the embodiment of the present invention.
FIG. 2 is a graph of the capacity of natural gas injection according to an embodiment of the present invention.
FIG. 3 is a graph of OPR and IPR curves for an embodiment of the present invention.
Detailed Description
The technical solutions in the embodiments of the present invention will be described clearly and completely with reference to the accompanying drawings in the embodiments of the present invention, and it is obvious that the described embodiments are only a part of the embodiments of the present invention, and not all of the embodiments. All other embodiments obtained by a person skilled in the art without making any inventive step are within the scope of the present invention.
The invention discloses a method for evaluating the gas injection capacity of a depleted oil-gas reservoir gas storage, which comprises the following steps of:
(1) designing 3-4 stable nitrogen gas injection quantities by adopting a natural gas well productivity well testing method, injecting nitrogen gas according to the sequence that the gas injection quantities gradually increase from small to small, lowering a cable direct-reading pressure gauge into the middle depth H of a reservoir stratum of a depleted oil and gas reservoir, recording the flowing pressure and temperature of each stable nitrogen gas injection quantity until the flowing pressure is stable, and measuring the stable nitrogen gas injection quantity qNCorresponding steady flow pressure pwfStable flow temperature TwfStabilizing the wellhead pressure pwhAnd stabilizing the wellhead temperature TwhFinally closing the well to measure the formation pressure pR；
(2) According to the standard-Katz chart, calculating a deviation factor Z of the nitrogen at the ground pressure of 0.101MPa and the ground temperature of 25 DEG C1Nitrogen gas at steady flow pressure pwfAnd a stable flow temperature TwfDeviation factor Z of2Deviation factor Z of natural gas at ground pressure of 0.101MPa and ground temperature of 25 DEG C3Natural gas at steady flow pressure pwfAnd a stable flow temperature TwfDeviation factor Z of4；
(3) Calculating the stable gas injection quantity q of nitrogenNCorresponding natural gas injection quantity qg：
Z1The pressure of the nitrogen at the surface isA deviation factor of 0.101MPa and a ground temperature of 25 ℃; z2Nitrogen at steady flow pressure pwfAnd a stable flow temperature TwfA deviation factor of (d); z3-deviation factor of natural gas at ground pressure of 0.101MPa and ground temperature of 25 ℃; z4At steady flow pressure p of natural gaswfAnd a stable flow temperature TwfA deviation factor of (d);
(4) drawing the natural gas injection capacity curve in a rectangular coordinate system, namely
And q isgThe relationship curve of (1);
(5) and (3) regressing a binomial capacity equation according to the capacity curve:
(6) obtaining different stratum pressure p according to gas well node analysis methodRMaximum gas injection amount of the conditioned bet gas well:
in the formula:
pwh≤pprocess limitation
Lambda is the oil pipe resistance coefficient, and the value is 0.015; p is a radical ofwh-stabilizing wellhead pressure, MPa; t isav-in-wellbore averagingThe temperature of the mixture is controlled by the temperature,
K；Zav-average pressure p in the wellboreavAnd the average temperature T in the wellboreavA natural gas deviation factor of; p is a radical ofav-the average pressure in the wellbore,
MPa；γgnatural gas relative density, 0.6; h-depth of the middle of the reservoir, m; p is a radical ofProcess limitation-wellhead equipment pressure, the nameplate having a label; d-the inner diameter of the oil pipe, obtained from the basic parameters of the injection and production well, m.
(7) Drawing OPR and IPR curves in a rectangular coordinate system, and selecting the natural gas injection amount corresponding to the intersection point of the two curves as the maximum natural gas injection amount q under different formation pressures and different pipe column conditionsGAnd the maximum natural gas injection amount is used for evaluating the gas injection capacity of the depleted oil-gas reservoir gas storage.
Example (b):
and taking a certain exhausted gas reservoir as a target gas reservoir of the gas storage, wherein the pressure of the gas reservoir is 7.94MPa, and the temperature of the gas reservoir is 83.29 ℃. The nitrogen purity was 99.2%, the relative density was 0.966, the natural gas relative density was 0.6, and the depth of the middle was 2831.05 m.
(1) The conventional natural gas well productivity well testing method is adopted, and 4 stable nitrogen gas injection quantities are respectively designed to be 18 multiplied by 104m3/d、24×104m3/d、30×104m3D and 36X 104m3D; lowering a cable direct-reading pressure gauge into the middle depth 2831.05m of the reservoir of the depleted oil-gas reservoir, recording the flow pressure and the temperature of each nitrogen stable gas injection amount until the flow pressure is stable, and measuring the stable gas injection amount q of the nitrogen until the flow pressure is stableNCorresponding steady flow pressure pwfStable flow temperature TwfStabilizing the wellhead pressure pwhAnd stabilizing the wellhead temperature TwhFinally closing the well to measure the formation pressure pRSo as to obtain the actual nitrogen injection amount and the corresponding stable flowing pressure, see table 1 and fig. 1.
TABLE 1 data table of nitrogen steady injection, natural gas injection and steady flow pressure
(2) According to the standard-Katz chart, the deviation factor Z of the nitrogen at the ground pressure (0.101MPa) and the ground temperature (25 ℃) is obtained1Nitrogen gas at steady flow pressure pwfAnd a stable flow temperature TwfDeviation factor Z of2And the deviation factor Z of the natural gas at the ground pressure (0.101MPa) and the ground temperature (25℃)3Natural gas stabilized at a flow pressure pwfAnd a stable flow temperature TwfDeviation factor Z of4To obtain Z1＝0.9952，Z3＝0.9979，Z2And Z4See table 1.
(3) Calculating the stable gas injection quantity q of nitrogenNCorresponding natural gas injection quantity qg：
Thus, a corresponding natural gas injection amount data table is obtained under different nitrogen stable gas injection amounts, and the table is shown in table 1.
(4) In a rectangular coordinate system, the corresponding stable flow pressure data under different natural gas injection quantities in the attached table 1 are utilized to draw a natural gas injection capacity curve, namely
And q isgSee fig. 2.
(5) And (3) regressing a binomial capacity equation according to the capacity curve:
(6) and calculating the maximum injection amount of the natural gas injected into the gas well under different formation pressure conditions according to a gas well node analysis method.
(7) Drawing OPR and IPR curves in a rectangular coordinate system, and selecting the natural gas injection amount corresponding to the intersection point of the two curves as the maximum natural gas injection amount q under different formation pressure and different pipe column conditionsGAnd the maximum natural gas injection amount is used for evaluating the gas injection capacity of the depleted oil-gas reservoir gas storage. See figure 3 for the amount of gas injected corresponding to the gray point.
In summary, the disclosure of the present invention is not limited to the above-mentioned embodiments, and persons skilled in the art can easily set forth other embodiments within the technical teaching of the present invention, but such embodiments are included in the scope of the present invention.
Claims (1)
1. The method for evaluating the gas injection capacity of the depleted oil-gas reservoir gas storage is characterized by comprising the following steps of:
(1) designing 3-4 stable nitrogen gas injection quantities by adopting a natural gas well productivity well testing method, injecting nitrogen gas according to the sequence that the gas injection quantities gradually increase from small to small, lowering a cable direct-reading pressure gauge into the middle depth H of a reservoir stratum of a depleted oil and gas reservoir, recording the flowing pressure and temperature of each stable nitrogen gas injection quantity until the flowing pressure is stable, and measuring the stable nitrogen gas injection quantity qNCorresponding steady flow pressure pwfStable flow temperature TwfStabilizing the wellhead pressure pwhAnd stabilizing the wellhead temperature TwhFinally closing the well to measure the formation pressure pR；
(2) According to the standard-Katz chart, calculating a deviation factor Z of the nitrogen at the ground pressure of 0.101MPa and the ground temperature of 25 DEG C1Nitrogen gas at steady flow pressure pwfAnd a stable flow temperature TwfDeviation factor Z of2Deviation factor Z of natural gas at ground pressure of 0.101MPa and ground temperature of 25 DEG C3Natural gas at steady flow pressure pwfAnd a stable flow temperature TwfDeviation factor Z of4；
(3) Calculating the stable gas injection quantity q of nitrogenNCorresponding natural gas injection quantity qg：
Z1-a deviation factor of nitrogen at a ground pressure of 0.101MPa and a ground temperature of 25 ℃; z2Nitrogen at steady flow pressure pwfAnd a stable flow temperature TwfA deviation factor of (d); z3-deviation factor of natural gas at ground pressure of 0.101MPa and ground temperature of 25 ℃; z4At steady flow pressure p of natural gaswfAnd a stable flow temperature TwfA deviation factor of (d);
(4) drawing the natural gas injection capacity curve in a rectangular coordinate system, namely
And q isgThe relationship curve of (1);
(5) and (3) regressing a binomial capacity equation according to the capacity curve:
(6) obtaining different stratum pressure p according to gas well node analysis methodRMaximum gas injection amount of the conditioned bet gas well:
in the formula:
pwh≤pprocess limitation
Lambda is the oil pipe resistance coefficient, and the value is 0.015; p is a radical ofwh-stabilizing wellhead pressure, MPa; t isav-the average temperature in the wellbore,
K；Zav-average pressure p in the wellboreavAnd the average temperature T in the wellboreavA natural gas deviation factor of; p is a radical ofav-the average pressure in the wellbore,
MPa；γgnatural gas relative density, 0.6; h-depth of the middle of the reservoir, m; p is a radical ofProcess limitation-wellhead equipment pressure, the nameplate having a label; d is the inner diameter of the oil pipe, which is obtained from the basic parameters of the injection and production well, m;
(7) drawing OPR and IPR curves in a rectangular coordinate system, and selecting the natural gas injection amount corresponding to the intersection point of the two curves as the maximum natural gas injection amount q under different formation pressures and different pipe column conditionsGAnd the maximum natural gas injection amount is used for evaluating the gas injection capacity of the depleted oil-gas reservoir gas storage.
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