CN113216950B - Device and method for recognizing reservoir fluid through pressure response - Google Patents
Device and method for recognizing reservoir fluid through pressure response Download PDFInfo
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- CN113216950B CN113216950B CN202110684964.2A CN202110684964A CN113216950B CN 113216950 B CN113216950 B CN 113216950B CN 202110684964 A CN202110684964 A CN 202110684964A CN 113216950 B CN113216950 B CN 113216950B
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- 239000012530 fluid Substances 0.000 title claims abstract description 125
- 238000000034 method Methods 0.000 title claims abstract description 28
- 238000012360 testing method Methods 0.000 claims abstract description 67
- 239000007788 liquid Substances 0.000 claims abstract description 14
- 239000003129 oil well Substances 0.000 claims abstract description 7
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 12
- 238000005259 measurement Methods 0.000 claims description 6
- 239000003921 oil Substances 0.000 description 17
- 235000019198 oils Nutrition 0.000 description 15
- 238000011161 development Methods 0.000 description 6
- 239000000523 sample Substances 0.000 description 6
- 230000015572 biosynthetic process Effects 0.000 description 5
- 238000004458 analytical method Methods 0.000 description 4
- 239000009096 changqing Substances 0.000 description 4
- 230000007547 defect Effects 0.000 description 3
- 238000005516 engineering process Methods 0.000 description 3
- 239000010779 crude oil Substances 0.000 description 2
- 239000003344 environmental pollutant Substances 0.000 description 2
- 239000008398 formation water Substances 0.000 description 2
- 235000019476 oil-water mixture Nutrition 0.000 description 2
- 231100000719 pollutant Toxicity 0.000 description 2
- 238000011160 research Methods 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 1
- 238000012512 characterization method Methods 0.000 description 1
- 238000007796 conventional method Methods 0.000 description 1
- 238000001514 detection method Methods 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 230000007774 longterm Effects 0.000 description 1
- 238000007781 pre-processing Methods 0.000 description 1
- 238000005070 sampling Methods 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK 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
- E21B49/008—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 by injection test; by analysing pressure variations in an injection or production test, e.g. for estimating the skin factor
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
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- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Physics & Mathematics (AREA)
- Fluid Mechanics (AREA)
- Environmental & Geological Engineering (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Chemical & Material Sciences (AREA)
- Analytical Chemistry (AREA)
- Geophysics (AREA)
- Measuring Fluid Pressure (AREA)
Abstract
The invention belongs to the technical field of fluid identification, and particularly relates to a device and a method for reservoir fluid identification through pressure response. The device comprises a liquid inlet, a test pipeline, a digital pressure gauge, a piston and a test chamber. The liquid inlet is positioned at the bottom end of the test pipeline and is communicated with the flow pipeline of the oil well; the digital pressure gauge is arranged on the test tube line and is positioned between the liquid port and the test chamber; the test chamber is positioned at the top end of the test pipeline; the piston is positioned in the test chamber, so that fluid can flow in the test pipeline at a constant speed. The invention uses different response characteristics of the pressure curve to identify the fluid and judge the state of the fluid, and has the characteristics of simple method, economy, high efficiency and high accuracy.
Description
Technical Field
The invention belongs to the technical field of fluid identification, and particularly relates to a device and a method for reservoir fluid identification through pressure response.
Background
Reservoir fluid identification technology is to identify the nature of the fluid in the reservoir under the reservoir condition, and whether the fluid contains water or oil or not, and whether the fluid contains various components with different densities or not. In the oil field exploration and development process, a fluid identification technology is an important means for determining reserves and developing horizons, and fluid property identification is an important link in oil and gas field exploration and development research, and the accuracy of identification is directly related to the discovery and efficient development of oil and gas reservoirs. With the development of oil fields, the development degree of conventional reservoirs is continuously increased, and the development of reservoirs becomes hot spots and difficulties, so that the associated reservoir fluid identification technology also enters a new stage.
The steps of conventional reservoir fluid identification techniques:
1. logging data preprocessing line checking, core homing and logging curve standardization;
2. reservoir electric lower limit establishment (including lower limit of acoustic wave time difference, lower limit of natural gamma, lower limit of resistivity, lower limit of natural potential and the like of the reservoir)
3. Establishing lower limit of oil layer (lower limit of acoustic wave time difference, lower limit of natural gamma, lower limit of resistivity, lower limit of natural potential, etc.) of oil layer
4. The lower limit determined by the above method is used to determine the properties of the fluid in the reservoir.
The identification of reservoir fluid properties can be achieved in the field of conventional reservoir fluid identification by the method described above, but the accuracy of the errors is not particularly desirable.
The technical proposal of the prior art is mainly that the reservoir lower limit standard is established through logging data standardization and based on four-way relation research, the effective thickness standard of the oil layer is established, and the fluid comprehensive identification method is established. These four parts complete reservoir fluid identification, which is also a conventional method of reservoir fluid identification.
Application number 200810137152 discloses a downhole differential pressure flow densitometer for measuring well fluid flow and density. The method can realize the flow rate and density of the underground fluid by using a differential pressure sensor. The formula used by the instrument is Δp=ρgh and Δp=aq 2 +ρgh, the flow rate and density of the target fluid are measured using a differential pressure densitometer. The invention has the defects that the friction coefficient of the fluid flowing in the test pipeline needs to be known in advance, the fluid needs to flow at a constant speed, and meanwhile, the flow and the password of the measured fluid are all integrally judged after the measured fluid is mixed, and the fluid identification function is not provided.
Patent No. EP1254352A1 discloses a densitometer for drilling, in which a vibration source and a detector are provided on the pipe wall by providing a sampling flow pipe to achieve detection of the sample density. The sample flow tube receives a sample fluid flow for characterization. The reference flow tube is filled with a reference fluid having good properties. The measurement module generates vibrations in the two tubes using a vibration source. The measurement module combines signals from vibration detectors on the pipeline to determine characteristics of the sample fluid such as density, viscosity, compressibility, water content. The invention has the defects that pollutants are easy to adhere to the vibration probe, and the inherent vibration frequency of the probe can be changed after the pollutants are adhered, so that the accuracy of measurement is affected; meanwhile, the flow and the password of the measured fluid are integrally judged after the measured fluid is mixed, and the fluid identification function is not provided.
Disclosure of Invention
Aiming at the defects of the prior art, the invention provides a device and a method for identifying reservoir fluid through pressure response, which are characterized in that the fluid is identified by utilizing different response characteristics of a pressure curve, and the state of the fluid is judged.
In order to achieve the above object, the present invention provides, in one aspect, an apparatus for reservoir fluid identification by pressure response, the apparatus comprising a fluid inlet 1, a test line 2, a digital pressure gauge 3, a piston 4, and a test chamber 5. The liquid inlet 1 is positioned at the bottom end of the test pipeline 2 and is communicated with a flow pipeline of the oil well; the digital pressure gauge 3 is arranged on the test pipeline 2 and is positioned between the liquid inlet 1 and the test chamber 5; the test chamber is positioned at the top end of the test pipeline 2; the piston 4 is located inside the test chamber 5 in order to allow a constant flow of fluid in the test line.
Preferably, the length of the test line 2 is greater than 90cm and the internal diameter is less than 5mm.
Preferably, the measurement accuracy of the digital pressure gauge 3 is required to be more than 0.3%, and the data acquisition time is less than each time/150 milliseconds.
Preferably, the volume of the test chamber 5 is greater than 200ml.
Another object of the invention discloses a method for reservoir fluid identification by pressure response, comprising the steps of:
(1) The test pipeline is communicated with the flow pipeline of the oil well, the test pipeline is filled with fluid to be identified, the piston is controlled to move, the piston moves from the bottom dead center to the top dead center, the fluid in the test pipeline flows at a constant speed, one stroke of the piston is ended, the fluid in the test pipeline also stops flowing, and pressure data is recorded in the whole process by using the pressure gauge.
Preferably, the linear velocity of the fluid flowing at a constant velocity is greater than 100mm/s.
(2) And (3) sorting the pressure test result of the digital pressure gauge, drawing a pressure curve according to the obtained pressure data in time sequence, obtaining a relative deviation curve of the pressure data by using a relative deviation concept in statistics, and determining the positive and negative deviation of the pressure curve according to the relative deviation curve.
(3) The positive and negative deviations of the pressure curve are analyzed to determine the ratio of oil to water in the fluid, wherein the positive deviation is the fluid with relatively high density and the negative deviation is the fluid with relatively low density.
(4) A pressure response standard curve for a particular fluid is made and then the duty cycle for a phase fluid can be obtained by the following equation.
The proportion of the fluid in the test line of the certain phase=the number of relative deviations/total number of fluid points according to the density characteristics of the fluid x 100%.
The invention carries out the specific process flow of the fluid identification in the pit: when fluid identification is carried out, a liquid inlet of the test pipeline is communicated with a fluid pipeline to be identified, so that fluid enters the test pipeline under the condition of the same pressure, a piston is driven to flow at a higher speed in the pipeline from one limit position to the other limit position, along with the end of the stroke of the piston, the fluid stops flowing in the test pipeline, the liquid starts to flow from the liquid inlet to the liquid inlet, the pressure value is recorded in detail, and the proportion of different types of fluid in the fluid can be identified through positive and negative deviation analysis of the recorded pressure change.
Compared with the prior art, the invention has the following advantages and beneficial effects:
compared with the similar method, the method is more accurate, fine, reliable, simple and convenient;
faster and more economical than other methods.
Drawings
FIG. 1 is a schematic diagram of a device for identifying reservoir fluids by pressure response according to the present invention.
FIG. 2 is a graph of the relative deviation of 7-24 well fluid identification for Changqing oilfield flags.
FIG. 3 is a graph of the relative deviation of the long-term oilfield plug 364-6 well fluid identification.
FIG. 4 is a graph of relative deviation of the fluid identification of 121-22 wells of Changqing oilfield.
Detailed Description
Referring to fig. 1, an apparatus for reservoir fluid identification by pressure response includes a fluid inlet 1, a test line 2, a digital manometer 3, a piston 4, and a test chamber 5. The liquid inlet 1 is positioned at the bottom end of the test pipeline 2 and is communicated with a flow pipeline of the oil well; the digital pressure gauge 3 is arranged on the test pipeline 2 and is positioned between the liquid inlet 1 and the test chamber 5; the test chamber is positioned at the top end of the test pipeline 2; the piston 4 is located inside the test chamber 5 in order to allow a constant flow of fluid in the test line.
The length of the test pipeline 2 is more than 90cm, and the inner diameter is less than 5mm.
The measurement accuracy of the digital pressure gauge 3 is required to be more than 0.3%, and the data acquisition time is less than each time/150 milliseconds.
The volume of the test chamber 5 is greater than 200ml.
A method for reservoir fluid identification by pressure response, comprising the steps of:
(1) The test pipeline is communicated with the flow pipeline of the oil well, the test pipeline is filled with fluid to be identified, the piston is controlled to move, the piston moves from the bottom dead center to the top dead center, the fluid in the test pipeline flows at a constant speed, one stroke of the piston is ended, the fluid in the test pipeline also stops flowing, and pressure data is recorded in the whole process by using the pressure gauge.
The linear velocity of the fluid flowing at a constant speed is more than 100mm/s. The constant-speed fluid flowing time refers to the time required for the constant-speed flow rate of the fluid flowing through the digital pressure gauge to reach the volume of the test chamber.
(2) And (3) sorting the pressure test result of the digital pressure gauge, drawing a pressure curve according to the obtained pressure data in time sequence, obtaining a relative deviation curve of the pressure data by using a relative deviation concept in statistics, and determining the positive and negative deviation of the pressure curve according to the relative deviation curve.
When multiple fluids flow in the test pipeline, the kinetic energy of the fluids is expressed as follows according to Bernoulli equationWherein ρ is the density of the fluid, v is the velocity of the fluid, and the kinetic energy of the fluid is closely related to the density because the velocity of the fluid flowing in the test pipeline is the same, the kinetic energy of the fluid is different due to the difference of the densities, the pressure values measured by the pressure gauge are also different, the greater the density is,the higher the pressure value, the smaller the density and the lower the pressure value.
(3) The positive and negative deviations of the pressure curve are analyzed to determine the ratio of oil to water in the fluid, wherein the positive deviation is the fluid with relatively high density and the negative deviation is the fluid with relatively low density.
(4) A pressure response standard curve for a particular fluid is made and then the duty cycle for a phase fluid can be obtained by the following equation.
The proportion of the fluid in the test line of the certain phase=the number of relative deviations/total number of fluid points according to the density characteristics of the fluid x 100%.
Example 1: the fluid tested was pure water
In 2019, 9 months, fluid identification was performed at 2024.8 meters downhole of the field flag 7-24 wells in Changqing, and the formation fluid obtained at this location was pure water.
Intercepting a section of pressure data acquired from the position, wherein the data are as follows:
the data were subjected to relative deviation analysis to obtain a relative deviation curve, see fig. 2.
The corresponding data representation of the intercepted pressure data in the relative deviation table is shown in the circle area in fig. 2.
It can be seen that the areas encircled in figure 2 all result in positive deviations. The formation fluid representing the location is all formation water.
The fluid taken at this point was transported to the surface and analyzed to obtain formation water at a density of 1.002.
Example 2: the fluid tested was pure oil
In 2019, 11 months, fluid identification was performed at 2064.6 meters downhole of the Changqing oilfield plug 364-6, where the resulting formation fluid was pure oil.
Intercepting a section of pressure data acquired from the position, wherein the data are as follows:
the data were subjected to relative deviation analysis to obtain a relative deviation curve, see fig. 3.
The corresponding data representation of the intercepted pressure data in the relative deviation table is shown in the circle area in fig. 3.
It can be seen that the areas encircled in figure 3 all result in negative deviations. The formation fluid representing that location is all crude oil.
The fluid taken at this point was transported to the surface and analyzed to obtain crude oil, all of which had a density of 0.8452.
Example 3: the fluid tested was an oil-water mixture
And (3) carrying out fluid identification at the position of 1709.5 meters underground in 121-22 wells of Daqing oilfield in month 6 of 2020, wherein the stratum fluid obtained from the position is oil-water mixture.
Intercepting a section of pressure data acquired from the position, wherein the data are as follows:
the data were subjected to relative deviation analysis to obtain a relative deviation curve, see fig. 4.
The corresponding data representation of the intercepted pressure data in the relative deviation table is shown in the circle area in fig. 4.
It can be seen that both positive and negative deviations are obtained in the circled area in fig. 4. The formation fluid representing this location is all oil and water.
According to the following: the proportion of a certain fluid in the test line = the number of relative deviations from the density characteristics of the fluid/the total number of fluid points, and the oil and water content at that location was calculated.
Moisture content=positive pressure deviation point/total point×100% =53%
Oil content = pressure negative bias points/total points x 100% = 52.78%
The water content at this position was found to be 53% and the oil content 47.22%.
The fluid taken at this location was transferred to the surface, and after oil-water separation, the oil content was actually 41.57%, the water content was 58.43% and the error rate was 15%.
Claims (6)
1. The device comprises a liquid inlet, a test pipeline, a digital pressure gauge, a piston and a test chamber, wherein the liquid inlet is positioned at the bottom end of the test pipeline and is communicated with a flow pipeline of an oil well; the digital pressure gauge is arranged on the test tube line and is positioned between the liquid inlet and the test chamber; the test chamber is positioned at the top end of the test pipeline; the piston is positioned in the test chamber;
the method is characterized by comprising the following steps of:
(1) The testing pipeline is communicated with a flow pipeline of the oil well, the testing pipeline is filled with fluid to be identified, the piston is controlled to move from a bottom dead center to a top dead center, the fluid in the testing pipeline flows at a constant speed, one stroke of the piston is ended, the fluid in the testing pipeline also stops flowing, and pressure data are recorded in the whole process by using a pressure gauge;
(2) The method comprises the steps of finishing pressure test results of a digital pressure gauge, drawing a pressure curve according to the obtained pressure data in time sequence, obtaining a relative deviation curve of the pressure data by using a relative deviation concept in statistics, and determining positive and negative deviations of the pressure curve according to the relative deviation curve;
(3) Analyzing positive and negative deviations of the pressure curve to determine the proportion of oil and water in the fluid, wherein the positive deviation is fluid with relatively high density, and the negative deviation is fluid with relatively low density;
(4) Making a pressure response standard curve of a specific fluid, and then obtaining the duty ratio of a certain phase of fluid by the following formula;
the ratio of a certain phase fluid = the number of relative deviations per total number of fluid x 100% that corresponds to the fluid density characteristics.
2. The method of claim 1, wherein the fluid flows at a uniform linear velocity of greater than 100mm/s.
3. The method of claim 1, wherein the proportion of the fluid in the test line is =the number of relative deviations/total number of fluid points corresponding to the density characteristics of the fluid x 100%.
4. The method of claim 1, wherein the test line has a length of greater than 90cm and an inner diameter of less than 5mm.
5. The method of claim 1, wherein the digital manometer has a measurement accuracy of greater than 0.3% and a data acquisition time of less than 150 ms/each time.
6. The method of claim 1, wherein the test chamber has a volume of greater than 200ml.
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| CN202110684964.2A CN113216950B (en) | 2021-06-21 | 2021-06-21 | Device and method for recognizing reservoir fluid through pressure response |
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Citations (8)
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|---|---|---|---|---|
| CN101189409A (en) * | 2005-04-29 | 2008-05-28 | 石油研究和发展公司 | Methods and apparatus of downhole fluid analysis |
| CN103806901A (en) * | 2012-11-08 | 2014-05-21 | 中国石油大学(北京) | Oil well downhole rapid test system and test method |
| CN204552741U (en) * | 2015-03-02 | 2015-08-12 | 高博学 | Device for testing liquid level of oil well |
| CN204989082U (en) * | 2015-08-11 | 2016-01-20 | 中国石油大学(北京) | Device for measuring water content of crude oil |
| CN105443113A (en) * | 2014-08-29 | 2016-03-30 | 中国石油天然气股份有限公司 | Test string for gas storage |
| CN206656886U (en) * | 2017-04-19 | 2017-11-21 | 中国石油大学(北京) | Realize the sampler of the anti-shearing sampling of Double-way sucking isothermal with pressure |
| CN206656879U (en) * | 2017-04-17 | 2017-11-21 | 中国石油大学(北京) | A kind of tube sampler for realizing the anti-shearing sampling of isothermal with pressure |
| CN112727449A (en) * | 2021-04-06 | 2021-04-30 | 东营钧辰石油设备有限责任公司 | Automatic monitor for liquid level of sound source oil well |
-
2021
- 2021-06-21 CN CN202110684964.2A patent/CN113216950B/en active Active
Patent Citations (8)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101189409A (en) * | 2005-04-29 | 2008-05-28 | 石油研究和发展公司 | Methods and apparatus of downhole fluid analysis |
| CN103806901A (en) * | 2012-11-08 | 2014-05-21 | 中国石油大学(北京) | Oil well downhole rapid test system and test method |
| CN105443113A (en) * | 2014-08-29 | 2016-03-30 | 中国石油天然气股份有限公司 | Test string for gas storage |
| CN204552741U (en) * | 2015-03-02 | 2015-08-12 | 高博学 | Device for testing liquid level of oil well |
| CN204989082U (en) * | 2015-08-11 | 2016-01-20 | 中国石油大学(北京) | Device for measuring water content of crude oil |
| CN206656879U (en) * | 2017-04-17 | 2017-11-21 | 中国石油大学(北京) | A kind of tube sampler for realizing the anti-shearing sampling of isothermal with pressure |
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