Some standard content:
ICS 75.180.99
Registration No.: 3085—1999
Petroleum and Natural Gas Industry Standard of the People's Republic of ChinaSY/T 5345—1999
Oil--water relative permeability measurement
Oil -- water relative permeability measurement1999-05-17Published
State Administration of Petroleum and Chemical Industry
Implemented on 1999-12-01
SY/T 5345--1999
Referenced standards
Test oil
Test water
Establish initial oil-water saturation state of rock sample
Restore rock wettability
Determination of oil-water relative permeability by steady-state method
9 Revision of data for determination of oil-water relative permeability by non-steady-state method
11 Content and format of report:
Appendix A (Appendix to the standard)
Appendix B (Appendix to the standard)
Report format for determination of oil-water relative permeability by steady-state method·Report format for determination of oil-water relative permeability by non-steady-state methodSY/r5345-1999
This standard is revised on the basis of SY5345-89 "Determination of oil-water relative permeability by non-steady-state method". The revised standard adds the steady-state method part
This standard amends SY 5345-89 The following major revisions were made: (1) The name of the standard was newly determined, and the phrase "Non-steady-state method" was deleted from "Non-steady-state method for determination of oil-water relative permeability" to make it conform to the requirements of GB/T [1993; (2) Chapter 1 and Chapter 2 of SY 5345-89 were revised in accordance with the provisions of GB/T 1.1-1993; (3) The rock sample preparation for determination of oil-water relative permeability by non-steady-state method and steady-state method in SY5345-89 was changed to Chapter 3 of this standard; (4) Chapter 3 of SY5345-89 was revised to add requirements for rock sample drilling; (5) Chapter 6 "Establishing the initial oil-water saturation state of rock samples" was added; (6) 8.1.3.2 and 8.3.3 of SY 5345-89 were revised. （7） Chapter 9 of SY5345-89 was appropriately shortened; (8) Chapter 10 of SY5345-89 was deleted; (9) Chapter 8 "Determination of oil-water relative permeability by steady-state method" was added; (10) The report format of steady-state method and non-steady-state method was added [see Appendix A (Appendix of the standard) and Appendix B (Appendix of the standard) of this standard
This standard will replace SYS345-89 from the date of entry into force. Appendix A and Appendix B of this standard are both appendices of the standard. This standard was proposed by China National Petroleum Corporation. This standard was drafted by the Petroleum Exploration and Development Professional Standardization Association. This standard was drafted by the Petroleum Exploration and Development Research Institute. The drafters of this standard are Jiang Yirong, Dai Zhijian, Luo Manli, Hong Dian, Zhang Zubo, and Jia Fenshu. This standard was first issued on March 31, 1989. 1 Scope
Petroleum and Natural Gas Industry Standard of the People's Republic of China Oil-water relative permeability measurement
Oil-water relative permeability measurementSY/T5345—1999
Replaces SY5345—89
This standard specifies the basic principles, measurement methods, data processing and report format for measuring oil-water relative permeability. This standard includes two measurement methods: steady-state method and non-steady-state method. The steady-state method is applicable to measuring the oil-water relative permeability of cylindrical rock samples with an air permeability range of 50×10-3~103×10-um; the non-steady-state method is applicable to measuring the oil-water relative permeability of cylindrical rock samples with a permeability greater than 5×10-3um2.
This standard is applicable to cemented sandstone. There are two methods in the non-steady-state water flooding test: constant pressure and constant rate. These two methods are equivalent. 2 Referenced Standards
The provisions contained in the following standards constitute the provisions of this standard through reference in this standard. When this standard is revised, the versions shown are valid. All standards will be revised. Parties using this standard should explore the possibility of using the latest versions of the following standards. SY/T5153-1999 Determination of wettability of reservoir rocksSY/T5336-1996 Conventional analysis method of core 3 Rock samples
3.1 Rock sample drilling
The rock sample is drilled into a cylindrical shape with a diameter of 2.5cm or 3.8cm and a length of not less than 1.5 times the diameter. 3.2 Fresh rock samples
3.2.1 Select the required cores at the drilling site and use any of the following two packaging methods: a) After the cores are extracted, wrap them with polyethylene film, then wrap them with tin foil and seal them with wax; b) At the drilling site, immerse the cores in a self-concentrated (such as 5%) NaCl aqueous solution and seal them. 3.2.2 Use a saturated high-concentration (such as 5%) NCl aqueous solution or neutral kerosene as a circulating fluid to drill and sample. The drilled samples are soaked in evacuated crude oil and sealed.
3.3 Cleaning of non-fresh rock samples
Choose a cleaning solvent based on the original wettability of the reservoir. If the original wettability of the reservoir is water-solidified, use benzene and alcohol to clean the rock samples. If the original wettability of the reservoir is oil-wet, use carbon tetrachloride and high-grade (No. 120) solvent gasoline to clean the rock samples. After the rock samples are cleaned with these solvents, there is no need to restore the wettability. If the original wettability of the formation is unknown, the provisions of SY/T5153 shall be followed. 4 Test oil
4.1 Use refined oil or simulated oil prepared by adding fresh degassed crude oil to neutral kerosene, and select the oil-water viscosity ratio according to the actual situation of each oil field.
4.2 Use refined oil for fresh rock samples and simulated oil for non-fresh rock samples (restored wettability rock samples). 5 Test water
Experimental injection water or formation water (bound water) Use actual injection water, formation water or artificially prepared injection water and formation water. Approved by the State Administration of Petroleum and Chemical Industry on December 1, 1999, 6 Establish the initial oil-water saturation state of the rock sample
6.1 Determination of effective pore volume and porosity of rock samples 6.1.1 Weighing of the sample.
$Y/T 5345-—1999
6.t.2 Draw out some empty rock samples to saturate them with simulated formation water. The method and requirements for drawing out saturated formation water shall be in accordance with the provisions of SY/T5336. 6.1.3 Weigh the rock samples saturated with simulated formation water, and then calculate the effective pore volume and porosity according to formula (1) and formula (2). Vr
Where: mo
mi - m
mass of dry rock sample, name:
mass of rock sample saturated with simulated formation water, name: density of simulated formation water saturating the rock sample under the measured flow rate, g in m; Vp——effective pore volume of rock sample, cm; V——total volume of rock sample, cm2;
—porosity of rock sample, %.
6.1.4 Determination of rock sample saturation: The determination method is to check whether the rock sample saturation meets the requirements strictly, or to proceed according to the following method, that is, to compare the effective porosity obtained after the rock sample is saturated with formation water with the gas-measured porosity. The two data should satisfy the following relationship: 4-, ≤1%
Where: 中*
Gas-measured porosity,%.
When low permeability rock samples are saturated with water, it is recommended to saturate the rock sample with CQ2 first, and then evacuate the saturated water to make the rock sample fully saturated. 6.2 Establish bound water saturation
Establish bound water saturation using the oil-displacement method. The bound water saturation is calculated according to formula (4); Ye- Vmi×100
Where: Sui is bound water saturation, %;
-the volume of water driven out of the rock, cm. www.bzxz.net
To restore the wettability of rock
The method for restoring the wettability of rock shall be implemented in accordance with the provisions of SY5153. 8 Determination of oil-water relative permeability by steady-state method
8.1 Original
.·[3]
The steady-state method for determining the relative permeability of oil and water is to inject oil and water into the rock sample at a constant rate at a certain flow rate ratio. When the inlet and outlet pressures and the oil and water flow rates are stable, the water saturation distribution of the rock sample is also stable. At this time, the distribution of oil and water in the pores of the rock sample is balanced, and the effective permeability value of the rock sample to oil and water is a constant. Therefore, the inlet and outlet pressures and the oil and water flow rates of the rock sample can be measured, and the effective permeability and relative permeability of the oil and water of the rock sample can be directly calculated by Darcy's law, and the corresponding average saturation value of the rock sample can be calculated by weighing method or mass balance method. By changing the ratio of oil injection flow rate, the permeability values of injection and water phases at different water saturations can be obtained, and the oil and water relative permeability curves can be drawn. See Appendix A (Standard Appendix) Figure AI18.2 Experimental flow and experimental equipment
8.2.1 Experimental flow sample
The schematic diagram of the steady-state method for determining the relative permeability of oil and water is shown in Figure 1. 8.2.2 Experimental equipment and measuring instruments
a) Core holder:
SY/T 5345—1999
[—-Filter: 2—Oil storage tank 3—Water storage: 4—Oil pump; 5-Water pump; 6--Annular pressure 7—Core 8--Pressure sensor: 9-Separator diagram! Schematic diagram of the steady flow oil-water relative permeability experiment process b) Circulation pump, flow accuracy is 1%,
c) Pressure sensor: measurement error is 0.4%FS: precision pressure sensor with small measuring cavity, measurement error is 0.45%F·Sd) Glass oil-water separator; 0--10ml-, graduation value is 0.05ml; e) Electronic day: graduation value is 0.0001g=
f) Electronic stopwatch: graduation value is 0.01s; g) Vernier caliper: graduation value is 0.02mm; h) Empty box barometer: graduation value is 15Paa8.3 Oil-water relative permeability determination steps
8,3.1 Determination of oil phase permeability under bound water state. 8.3.1.1 Fresh rock samples:
a) After the rock samples soaked in crude oil or kerosene are kept at the test temperature for 2 hours and evacuated for 1 hour, they are placed in the core holder and kept at the test temperature for 4 hours.
b) After the refined oil is displaced to the volume of [times of the pore volume, the effective permeability of the oil phase is measured. The effective permeability of the oil phase under bound water saturation is calculated according to formula (5):
where; Kas)
Kus) = Apr=p ×10-
Effective permeability of the phase under bound water saturation conditions: ?:4---Oil flow, nl/s;
Red--Viscosity at the test temperature, m!a*: Sample K, rm;
A--Sample cross-sectional area, mr;
-Sample inlet pressure (), MP
P2--Rock sample outlet pressure (gauge), MPr
When measuring the effective permeability of oil phase under bound water conditions, continuous measurement for one time, the relative error of the effective permeability of the oil phase under bound water conditions is less than 3%,
8.3.1.2 Non-fresh rock samples: Establish bound water saturation (or after recovery wetting) SY/T5345-1999) is used to test the oil displacement of 10 times the pore volume, and the effective permeability of the oil phase is measured. The calculation formula, measurement frequency and deviation requirements are the same as those of fresh rock samples (see 8.3.1.1). 8.3.2 Inject oil and water into the rock sample according to the set ratio, and when the flow is stable, record the inlet and outlet pressure of the rock sample and the oil and water flow rate, weigh the mass of the rock sample (when using the weighing method) or measure the changes in the oil and water volume in the oil-water separator (when using the material balance method). 8.3.3 Change the oil-water injection ratio and repeat the measurement of 8.3.1.2 until the test is completed. 8.4 Stability judgment basis a) At each level of oil-water flow ratio injection, each liquid should be injected into the rock sample at least 3 times the pore volume; b) The pressure difference at both ends of the rock sample is stable.
When the above two conditions are met at the same time, it is determined to be stable. 8.5 Oil-water injection ratio
Under the condition of constant total velocity, oil and water are injected in the following ratio! Oil
8. Determination of relative permeability and water saturation of oil and water 8.6.1 Determination of water saturation by weighing method
S. - miv-VCe × 100
V(pw-pu)
Water saturation of rock sample, %:
Where Sw
The mass of the oil-water rock sample at any moment, g; The density of simulated oil at the measurement temperature, /cm2. 8.6.2 Determine the water saturation of the rock sample by material balance method - (6)
The premise of using this method to determine the water saturation of the rock sample is that the inlet and outlet pressures of the rock sample must be measured with a precise pressure sensor to ensure that the oil and water are accurately measured at the outlet of the entire circuit, Su- Sxi
Where: V. is the volume of the original oil in the metering tube, cm; V- V. × 100
V is the volume of oil in the metering tube after the oil and water are stabilized under the i-th oil-water ratio. (mSi
is the bound water concentration, %
8,6.3 Calculation of oil-water relative permeability
Calculate the relative permeability of oil and water according to formula [8)·formula (11). qwwL
Kw\ A(tb) × 10-
K= Atpr- p2)
Wherein: qw
Water flow mL/s;
SY/T 5345—1999
Kn=Ksisu)
Oil viscosity at the test temperature, ml'a'siWater viscosity at the test overflow, Ina-s; Kw——Water phase effective permeability, um:
Water phase relative permeability;
Porous phase effective permeability, μm;
Oil relative permeability.
9. Determination of oil-water relative permeability by non-steady-state method 9.1 Principle
Non-steady-state oil-water relative permeability is based on the one-dimensional water flooding theory. In the process of water-to-oil displacement, the distribution of water and oil saturation in porous media is a function of distance and time. This process is called an unsteady process. According to the requirements of the simulation conditions, a water-to-oil displacement test at a constant pressure difference or constant speed is carried out on the reservoir rock sample. The production of each fluid and the pressure difference at both ends of the sample are recorded at the outlet of the rock sample over time. The test data are sorted out using the "3.BV" method to obtain the oil-water relative permeability, and the relationship curve between the oil-water relative permeability and water saturation can be drawn [see Appendix B (Standard Appendix) Figure B1]. 9.2 Driving conditions
9.2.1 Constant speed method
The constant speed method determines the injection speed according to formula (12): L-uwVl
Wherein: 1- rock sample length, cm:
Injection water viscosity, mPa's;
-seepage velocity, cm/mino
9.2.2 Constant pressure method
Constant pressure method An Yuan 10.6 determines the initial driving difference △0: 10-3g
Wu Zhong:
The ratio of driving pressure difference to capillary pressure difference:
Oil-water interfacial tension, mN/m;
K. - air permeability of rock sample. um2; porosity of a rock sample, porridge;
Ap—initial driving pressure difference, MPa
9.3 Main equipment and processes for constant rate test and constant pressure test 9.3.1 Experimental process
The experimental process is shown in Figure 2.
9.3.2 Experimental equipment and measuring instruments
a) Core holder;
b) Circulation pump: flow accuracy is 1%;
) Pressure sensor: measurement error is 0.4%FS: precision pressure sensor with small measuring cavity, measurement error is 0.45%F·S; d) Glass oil-water separator: 0~10mL, graduation value is 0.05mL: e) Set valuer.
9.4 Main steps of determination
9.4.1 Constant rate method
9.4.1.1 Fresh rock sample is the same as 8.3.1.1
9.4.1.2 Non-fresh rock sample is the same as 8.3.1.2h
SY/T5345-—1999
9.4.1.3 Water flooding:
2) Before water flooding, establish a pressure of ·m in the rock sample inlet (the pressure difference value is less than the pressure difference value when measuring the effective permeability of the oil phase). b) The experiment should record the oil production in the water-free period before water appears, accurately record the time of water appearance, the cumulative oil production, the cumulative liquid production, and the pressure difference at both ends of the rock sample
c) In the early stage of water appearance, record intensively, select the time interval according to the amount of oil production, and gradually lengthen the recording time interval as the output continues to decrease. After injecting 30 times the pore volume of water (or when the water content reaches 99.95%), measure the water phase permeability when residual oil is present. d) Fresh rock samples must be tested for water content at the end of the test using DeanStark throwing, and bound water saturation is calculated using the material balance method.
Insulation box
1-High-pressure core holder; 2-Pressure sensor: 3-High-pressure container: 4-Gate seat: 5-High-pressure coil; 6-High-pressure setter (for constant pressure method): 7-High-pressure metering pump, 8-Oil-water separator; 9-Filter Figure 2 Schematic diagram of the experimental flow of oil-water relative permeability in non-steady flow 9.4.2 Constant pressure method
9.4.2.1 When water drives oil, calculate the initial pressure difference according to Yuan; ≤0.6, and maintain constant differential pressure injection. 9.4.2.2 Accurately record the time of water breakthrough, the cumulative liquid production, cumulative oil production, and cumulative injection time when water breakthrough occurs. 9.4.2.3 The other steps are the same as the constant speed method. 9.5 Data integration
The basic formula is as follows:
Kruis, = Ka e Tus)
Sw- Swi + Vn) -fus.
Wherein: Knxs) Relative permeability of oil phase; S
Water saturation of rock sample;
Oil content;
Swe——Water saturation at outlet end;
SY/T 5345—1999
V\ dimensionally cumulative water injection volume (V/V, where V. represents the effective pore volume of rock sample); x? ——Dimensionally cumulative oil production (VV.); Krs)
Relative permeability of water phase;
Flowability ratio;
Sw——Immobile water saturation;
Viscosity of water at the test temperature, mPa's; —— Viscosity of oil at the test temperature, mPa's. During constant pressure test:
During constant speed test:
Where: Q)-
-the output at time t, cm;
Qoit--the initial output, cmt:
-the pressure difference at time t, MPa:
Ap(t)-
-the initial pressure difference, MPa.
According to formula (13) and formula (15), the oil and water relative permeability and the corresponding water saturation and water content are calculated by microcomputer. 10 Data rounding
Round the length value of the rock sample to 2 decimal places (cm). Round the diameter value of the rock sample to 2 decimal places (cm). 10.2
Round the area value of the rock sample to 2 decimal places (cm2). 10.4Round the volume value of the rock sample to 2 decimal places (cmm2). 10.5 Round the rock sample porosity value to 1 decimal place (%), -(17)
·(18)
10.6 Round the rock sample permeability and the effective permeability values of the oil phase and water phase of the right sample to 3 significant figures (expressed in scientific notation as 10-3μm2).
10.7 Round the relative permeability values of the oil phase and water phase of the rock sample to 3 decimal places, 10.8 Round the rock sample saturation value to 1 decimal place (%) 11 Report content and format
11.1 The report format for the determination of relative permeability of steady-state boiling water is shown in Appendix A (Appendix to the standard). 11.2 The report format for the determination of relative permeability of water by the non-steady-state method is shown in Appendix B (Appendix to the standard). A1 Report cover format
SY/T 5345—1999
Appendix A
(Appendix to the standard)
Report format for determination of relative permeability of oil and water by steady-state methodReport location for determination of relative permeability of oil and water by steady-state method
Rock sample number:
Sample sending unit:
Test basis:
Technical responsibility:
Report date:
(Measurement unit)
Report homepage format
This report has
pages, total rock samples
Main testing equipment and number:
Other instructions:
Measurer:
Verifier:
SY/T 5345—1999
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