SY/T 5745-2024 Terminology of oil and gas production engineering English, Anglais, Englisch, Inglés, えいご
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ICS
E
Professional standard of the People's Republic of China
SY/T 5745-2024
Replaces SY/T 5745-2008
Terminology of oil and gas production engineering
采油采气工程术语
(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 Reservoir Protection
4 Oil and Gas Well Completion
5 Reservoir Stimulation Processes
6 Oil and Gas Production Processes
7 Water Injection Processes
8 Water Shutoff and Profile Control
9 Other Production Methods
10 Prevention and Control of Sand, Wax, Scale, Corrosion, and Natural Gas Hydrates
11 Oil, Gas, and Water Well Production Performance Monitoring
12 Energy Saving and Consumption Reduction in Oil, Gas, and Water Well Production
13 Remedial Downhole Operations
14 Prevention and Major Repair of Oil, Gas, and Water Well Casing Damage
15 Offshore Oil and Gas Production
16 Digitalization of Oil and Gas Production
17 Wellbore Integrity
18 Oil and Gas Production Engineering Scheme Design
Chinese Index
English Index
Oil and Gas Production Engineering Terminology
1 Scope
This document specifies commonly used terms in oil and gas production engineering.
This document applies to the field of oil and gas production engineering in the petroleum and natural gas industry, as well as to other fields of the petroleum industry.
2 Normative References
The contents of the following documents constitute essential provisions of this document through normative reference. For dated references, only the edition corresponding to that date applies; for undated references, the latest edition (including all amendments) applies.
GB/T 28911-2012 Petroleum and natural gas drilling engineering terminology
3 Reservoir Protection
3.1
reservoir cementing type
Determined based on the composition and distribution of rock particles and cement in the reservoir, categorized as basal cementation, pore cementation, contact cementation, or no cementation.
3.2
reservoir damage
The phenomenon of reduced natural fluid production or injection capacity in the near-wellbore area of the reservoir caused by various operations such as drilling, completion, oil and gas production, stimulation measures, and workover operations.
3.3
permeability decrease rate
The degree of permeability reduction in the reservoir caused by damaging factors such as velocity sensitivity, water sensitivity, salinity sensitivity, acid sensitivity, and particles, i.e., the ratio of the permeability difference before and after damage to the permeability before damage of the reservoir rock sample.
3.4
reservoir sensitivity
The characteristic of an oil and gas reservoir where its pore structure and permeability change due to various physical or chemical interactions between the reservoir and foreign fluids.
3.5
sensitivity evaluation
Evaluation and analysis, through experiments, of the degree of reservoir permeability reduction and its contributing factors, such as experimental evaluations for velocity sensitivity, water sensitivity, acid sensitivity, salinity sensitivity, alkali sensitivity, pressure sensitivity, and temperature sensitivity.
3.6
sensitive mineral
A general term for minerals in the reservoir that readily undergo physical, chemical, or physicochemical reactions upon contact with fluids, leading to a significant decrease in permeability.
3.7
velocity sensitivity
The phenomenon where an increase in the flow rate of injected or produced fluids causes particle migration that blocks pore throats, leading to a significant decrease in reservoir permeability.
3.8
water sensitivity
The phenomenon where the entry of water from wellbore fluids into the reservoir causes clay minerals to swell, disperse, and migrate, altering flow paths and resulting in changes in reservoir permeability.
3.9
acidity sensitivity
The phenomenon where acid fluids entering the reservoir react with acid-sensitive minerals, producing precipitates or releasing particles, thereby causing a decrease in reservoir permeability.
3.10
salinity sensitivity
The phenomenon where a series of fluids with varying salt contents entering the reservoir cause hydration, swelling, dispersion, or migration of clay minerals, leading to a decrease in reservoir permeability.
3.11
alkalinity sensitivity
The phenomenon where alkaline fluids contact and react with reservoir minerals or fluids, producing precipitates or releasing particles, thereby causing a decrease in reservoir permeability.
3.12
stress sensitivity
The phenomenon where changes in the net overburden pressure on the rock cause deformation of pore throats and channels, or closure or opening of fractures, leading to changes in reservoir rock permeability. Also known as pressure sensitivity.
3.13
critical velocity
The flow velocity at the point preceding the point where the rate of change between the water permeability of the rock sample and the initial permeability exceeds 20% as the flow velocity increases.
3.14
water sensitivity index
The ratio of the maximum decrease in water permeability of a rock sample to its water permeability before damage.
3.15
water sensitivity level
The degree of reservoir water sensitivity expressed using the water sensitivity index, categorized as strong water sensitivity, medium water sensitivity, weak water sensitivity, or non-water sensitivity.
3.16
acidity sensitivity index
The ratio of the difference in water permeability of a rock sample before and after contact with acid to the water permeability before contact with acid.
3.17
critical salinity
The salinity at the point preceding the point where the rate of change between the water permeability of the rock sample and the initial permeability exceeds 20% as the salinity of the injected fluid increases or decreases.
3.18
critical pH value
The pH value at the point where the rate of change between the water permeability of the rock sample and the initial permeability exceeds 20% as the pH value of the injected fluid increases.
3.19
Jamin effect
The phenomenon where gas bubbles in oil or oil droplets in water deform as they pass through pore throats or narrow pore constrictions during flow in porous media, generating additional resistance.
3.20
skin effect
The phenomenon where changes in permeability near the wellbore reservoir, caused by drilling, completion operations, or stimulation measures, result in changes to the additional flow resistance.
3.21
skin factor
A dimensionless coefficient used to evaluate the skin effect of a well. It is the natural logarithm of the ratio of the completion radius to the equivalent wellbore radius.
