Standard No.:	SY/T 5358-2024
English Name:	Formation damage evaluation by flow test
Chinese Name:	储层敏感性流动实验评价方法
Professional Classification:	SY    Professional Standard - Oil & Gas
Source Content Issued by:	Nation Energy Administration
Issued on:	2024-12-25
Implemented on:	2025-6-25
Status:	valid
Superseding:	SY/T 5358-2010 Formation damage evaluation by flow test
Target Language:	English
File Format:	PDF
Word Count:	19000 words
Translation Price(USD):	570.0
Delivery:	via email in 1~5 business day

SY/T 5358-2024 Formation damage evaluation by flow test English, Anglais, Englisch, Inglés, えいご This is a draft translation for reference among interesting stakeholders. The finalized translation (passing through draft translation, self-check, revision and verification) will be delivered upon being ordered. ICS E Professional standard of the People's Republic of China SY/T 5358-2024 Replaces SY/T 5358-2010 Formation damage evaluation by flow test 储层敏感性流动实验评价方法 (English Translation) Issue date: 2024-12-25 Implementation date: 2025-06-25 Issued by National Development and Reform Commission, P.R.C Contents Foreword 1 Scope 2 Normative References 3 Terms and Definitions 4 Method Principle 5 Instruments and Equipment 6 Rock Sample Preparation 7 Velocity Sensitivity Evaluation Experiment 8 Water Sensitivity Evaluation Experiment 9 Salinity Sensitivity Evaluation Experiment 10 Acid Sensitivity Evaluation Experiment 11 Alkaline Sensitivity Evaluation Experiment 12 Stress Sensitivity Evaluation Experiment 13 Work Fluid Evaluation 14 Numerical Rounding Appendix A (Informative) Report Format for Reservoir Sensitivity Evaluation Experiments Evaluation Method for Reservoir Sensitivity Flow Experiments 1 Scope This document specifies the measurement procedures, technical requirements, calculation methods, and evaluation indicators for evaluating velocity sensitivity, water sensitivity, salinity sensitivity, acid sensitivity, alkaline sensitivity, stress sensitivity, and work fluids using flow experiments. This document applies to the sensitivity evaluation of reservoir rock samples with air permeability greater than 1 mD. For reservoir rock samples with air permeability not greater than 1 mD, reference may be made for implementation. 2 Normative References The following documents contain provisions which, through normative reference in this text, constitute essential provisions of this document. For dated references, only the edition cited applies. For undated references, the latest edition (including any amendments) applies. GB/T 10247 Methods for the measurement of viscosity GB/T 21784.2 Laboratory glassware — Hydrometers for general purposes — Part 2: Test methods and use GB/T 28912 Test method for two phase relative permeability in rock GB/T 29172 Practices for core analysis SY/T 5815 Determination method of compressibility for rock pore volume SY/T 6385 Measurement method of rock porosity and permeability under overburden pressure 3 Terms and Definitions For the purposes of this document, the following terms and definitions apply. 3.1 velocity sensitivity The phenomenon where changes in fluid flow velocity cause particle migration in reservoir rocks, leading to changes in reservoir rock permeability. 3.2 water sensitivity The phenomenon where injected water with lower salinity causes clay swelling, dispersion, and migration after entering the reservoir, leading to changes in reservoir rock permeability. 3.3 salinity sensitivity The phenomenon where a series of brines with different salinities enter the reservoir, and changes in fluid salinity cause clay mineral swelling or dispersion/migration, leading to changes in reservoir rock permeability. 3.4 acid sensitivity The phenomenon where acid contacts and reacts with reservoir minerals, producing precipitates or releasing particles, leading to changes in reservoir rock permeability. 3.5 alkaline sensitivity The phenomenon where alkaline fluid contacts and reacts with reservoir minerals, producing precipitates or causing clay dispersion and migration, leading to changes in reservoir rock permeability. 3.6 stress sensitivity The phenomenon where changes in net stress applied to the rock cause deformation of pore throats and channels, or closure or opening of fractures, leading to changes in reservoir rock permeability. 3.7 critical velocity The flow velocity at the point preceding the point where the rate of change between the rock permeability at different flow velocities and the rock permeability at the minimum flow velocity exceeds 20% as the flow velocity increases. 3.8 critical salinity The salinity at the point preceding the point where the rate of change between the rock permeability corresponding to solutions of different salinities and the rock permeability corresponding to the initial fluid exceeds 20% as the salinity increases or decreases. 3.9 critical pH value The pH value at the point preceding the point where the rate of change between the rock permeability corresponding to potassium chloride solutions of different pH values and the rock permeability corresponding to potassium chloride solution with pH 7.0 exceeds 20% as the pH of the injected fluid increases. 3.10 critical stress The net stress value at the point preceding the point where the rate of change between the rock permeability at different net stresses and the rock permeability at the initial net stress exceeds 20% as the net stress loaded onto the core increases. 3.11 work fluid Fluids used in various processes such as drilling and completion, development, and stimulation measures, or other liquids required for use in oilfields. Note: Work fluids include drilling fluids, completion fluids, perforating fluids, acidizing fluids, injection water, kill fluids, fracturing fluids, flushing fluids, etc. 4 Method Principle Based on Darcy's law, various fluids related to formation damage are injected under conditions set by the experiment, or flow conditions (flow velocity, net confining pressure, etc.) are changed. The permeability of the rock sample and its changes are measured to evaluate the degree of damage caused by the experimental fluids and changes in flow conditions to the rock sample permeability. 5 Instruments and Equipment 5.1 Sensitivity Flow Experiment Evaluation Device 5.1.1 Experimental Flow Chart A schematic diagram of the sensitivity flow experiment flow is shown in Figure 1. 5.1.2 Injection System 5.1.2.1 Injection pump: Flow rate accuracy not less than 1%. 5.1.2.2 Intermediate container: Pressure resistance not less than 30 MPa. 5.1.2.3 Filter: Membrane filter 0.2 μm ~ 0.45 μm. 5.1.2.4 Multi-way valve: Pressure resistance not less than 30 MPa. 5.1.2.5 Pressure gauge: Pressure gauge accuracy not less than Class 0.4, pressure sensor accuracy not less than 0.25% FS. 5.1.3 Model System 5.1.3.1 Core holder: Capable of holding cylindrical rock samples with a diameter of 2.5 cm or 3.8 cm and a length greater than 1.5 times the diameter, resistant to acid and alkali corrosion. 5.1.3.2 Confining pressure pump: Pressure accuracy not less than 0.4% FS. 5.1.3.3 Back pressure pump: Pressure accuracy not less than 0.4% FS. 5.1.3.4 Back pressure valve: Pressure resistance not less than 30 MPa, control accuracy not less than 0.1 MPa. 5.1.4 Production System 5.1.4.1 Electronic balance: Sensitivity not higher than 0.01 g. 5.1.4.2 Stopwatch: Resolution not lower than 0.01 s. 5.1.4.3 Graduated cylinder: Accuracy not lower than 0.1 ml. 5.2 Other Instruments 5.2.1 Viscometer: Kinematic viscosity accuracy not less than 0.001 mm²/s. 5.2.2 pH meter: pH measurement range 0 ~ 14, resolution not lower than 0.1. 5.2.3 Electronic balance: Sensitivity not higher than 0.001 g. 5.2.4 Caliper: Resolution not lower than 0.02 mm. 6 Rock Sample Preparation 6.1 Drilling, Cleaning, and Drying of Rock Samples Rock samples shall be drilled, cleaned, and dried according to the provisions of GB/T 29172. The fluid flow direction shall be marked on the rock samples.