Some standard content:
IS 75.180.99
Registration No.: 6968—2000
Petroleum and Natural Gas Industry Standard of the People's Republic of China SY/T5388—2000
The dividing method for carbonate reservoir
The dividing method for carbonate reservoir2000-03-31 Issued
State Administration of Petroleum and Chemical Industry
2000-10-01 Implementation
SY/T5388—2000
1 Scope
2 Parameter symbols and codes
3 Establishment of reservoir division standard
4 Steps for single well reservoir division
Appendix A (Appendix to the standard)
Appendix B (Appendix to the standard)
Carbonate reservoir division diagrams
Carbonate reservoir division data table
SY/T 5388-200
SY/T5388-91 "Division of Carbonate Reservoirs" was officially issued by the Ministry of Energy of the People's Republic of China as an industry standard on July 19, 1991, and was implemented nationwide on December 1, 1991. From the implementation of more than 8 years, this standard has played a certain role in regulating the division of carbonate oil reservoirs, and at the same time, some existing problems have been found. With the rapid development of science and technology, some new technologies and methods are constantly applied to oilfield exploration and development. In order to make this standard more scientific and practical, further improve the accuracy of reservoir division, and make it play a greater role in oil exploration and development, it is necessary to revise the original standard. In the revision, we first conducted a technical investigation on the classification method of domestic carbonate reservoirs, the implementation effect and existing problems of SY/T5388-91, collected relevant data on the classification of carbonate reservoirs using new measurement technologies, solicited opinions from relevant domestic experts, and re-studied the content of the original standard. On this basis, the original standard was revised according to GB/T1.1-1993. In this revision, parameter symbols, the definition and classification of reservoir levels were added, the triangle intersection diagram was removed, the deep lateral resistivity and natural gamma, deep lateral resistivity and neutron Sherman, neutron gamma and natural ray intersection diagrams and special layer point processing were added, and the content of distinguishing reservoirs and non-reservoir layers based on the measurement data of new methods such as supermarket imaging was added. This standard will replace SY/T5388-91 from the month of implementation. This standard is proposed by China National Petroleum Corporation. This standard is under the jurisdiction of the Oil and Gas Field Development Professional Standardization Committee. The drafting unit of this standard is: Exploration and Development Research Institute of North China Petroleum Administration. The main drafters of this standard are Zhang Shancheng, Guo Shuiyin and Chen Quanjun. Scope
Petroleum and natural gas industry standard of the People's Republic of China The dividing method for carbonate reservoirs
The dividing method for carbonate reservoirsSY/T 5388—2000
Replaces SY/T 5388-9!
This standard specifies the reservoir division standard for carbonate oil reservoirs and the basic methods and requirements for single well reservoir division. This standard is applicable to the division of carbonate oil reservoirs. 2 Parameter symbols and codes
Borehole compensated sonic logging;
CAL-wellbore caliper logging;
-ultrasonic imaging logging;
CNL-dual source distance compensated neutron logging:
IDL-dual lateral logging;
-formation density logging;
FIL---fracture identification logging;
GR-natural gamma logging;
-lithology density logging;
LSS-long source distance sonic logging;
microspherical focusing logging;
NG-neutron gamma logging; www.bzxz.net
-natural gamma ray spectrum logging:
STAR-Ⅱ-micro resistivity scanning imaging logging: CGR-uranium removal logging Natural gamma, API;
DT——-sonic time difference, μs/m;
-skeleton identification:
M—parameters used to determine lithology;
-parameters used to determine lithology;
-lithology density logging value (lithology measurement code), effective photoelectric adsorption cross-sectional index: R——deep lateral resistivity, ·m;
Rlg——shallow lateral resistivity, am;
microspherical focusing resistivity, Q·m;
total natural gamma, API;
mud content, %;
Ph—formation density, g/cm2;
Neutron porosity, %;
neutron porosity, %.
Approved by the State Administration of Petroleum and Chemical Industry on March 31, 2000, implemented on October 1, 2000
3 Establishing the standard for reservoir classification
3.1 Definition of reservoir and non-reservoir
This standard adopts the following definitions.
3.1.1 Reservoir
SY/T5388—2000
Refers to carbonate rock formations with developed fractures, caves and pores and with storage capacity. 3.1.2 Nonreservoir
Refers to dense layers without developed fractures, caves and pores. 3.2 Reservoir division workflow and basic contents of electrical standards 3.2.1 Reservoir division workflow See Appendix A (Standard Appendix) Figure A1 3.2.2 The basic contents of reservoir division electrical standards include: a) lithology identification plate;
b) porosity plate;
c) reservoir (non-high natural gamma reservoir) division plate; d) method for distinguishing high natural gamma reservoirs (including weathering crust reservoirs and high uranium content reservoirs) and high natural gamma non-reservoir layers; e) logging parameter cutoff value reflecting the upper limit of reservoir mud content; f) logging parameter cutoff value reflecting the lower limit of reservoir pore seepage capacity; g) lower limit of reservoir total porosity.
3.3 Basic data requirements
3.3.1 Logging data
Each well must have logging curves during drilling, logging surfaces of rock cuttings, gas logging and drilling fluid logging data, as well as oil and gas displays, the degree and accurate depth of emptying, leakage and well kick. 3.3.2 Core data
a) Core profiles of complete monthly layers; b) Core description data that systematically describes lithology, fracture development, reservoir type and oil-bearing grade; c) Sampling: take more than 5 rock samples per meter; d) Core analysis: including lithology, physical properties, pore structure, etc.; e) Junxin homing map
3.3.3 Logging data
a) Optimize the logging series according to the geological characteristics of the target layer: b) Standardized logging data.
3.3.4 Oil test and well test data
a) There should be at least 3 wells and 15 layers of representative single-layer oil test data in the work area; b) There should be single-layer oil test data for all types of reservoirs, non-reservoir layers and the boundary layers between them;) Select representative well test data.
3.4 Determine the types of reservoirs and non-reservoir layers and the characteristics of the measurement curve 3.4.1 Determine the types of reservoirs and non-reservoir layers
a) Determine the types of reservoirs and non-reservoir layers based on core description and core analysis data; b) Identify large fractures and large cave reservoirs based on the drilling tool emptying, drilling fluid leakage and well kick in the logging data; c) Determine the reservoir type based on the liquid production in the oil test data and the logging data; d) Determine the reservoir type based on the imaging logging data. 3.4.2 Characteristics of logging curves of various reservoirs and non-reservoir layers The morphological characteristics of logging curves of various reservoirs and non-reservoir layers in the work area are summarized, and a list of their logging curve characteristics is compiled [see 2
Appendix B (Standard Appendix) Table B1J.
SY/T5388—2000
3.5 Determination of reservoir grade and its lithology and physical property standards 3.5.1 Determination of reservoir grade
a) Class I reservoir: refers to high-yield reservoir with developed fractures, caves and pores; b) Class II reservoir: refers to medium- and low-yield reservoir with poorly developed fractures, caves and pores 3.5.2 Determination of reservoir lithology and physical property standards a) Prepare lithology and oil content relationship diagram [see Appendix A (Standard Appendix) Figure A2], physical property and oil content relationship diagram [see Appendix A (Standard Appendix) Figure A3], pore mean and oil content relationship diagram [see Appendix A (Standard Appendix) Figure A4], porosity and pore mean relationship diagram [see Appendix A (Standard Appendix) Figure A5], etc.; b) According to the difference in oil or gas storage in the reservoir, determine the lithology and physical property standards of Class I and Class II reservoirs and non-reservoirs [see Appendix A (Standard Appendix) Figure A6].
3.6 Establishment of logging standards for reservoir division
3.6.1 Preparation of core analysis parameter and logging parameter data table Based on core analysis, core description data and core homing map, and in comparison with logging data, select the reservoir with a thickness greater than 1.0m, relatively stable lithology, and easy-to-read logging curves, compile core analysis parameters and logging parameter data tables (see Appendix B (Standard Appendix) Table B2). The percentage of rock components is the average value of the analysis samples within the layer. 3.6.2 Compile reservoir and non-reservoir logging parameter data tables Based on the reservoir or non-reservoir confirmed by one of the basic data such as single-layer oil testing, drilling coring, and comprehensive logging, read the logging parameters of the corresponding layer and compile reservoir and non-reservoir logging parameter data tables (see Appendix B (Standard Appendix) Table B3). 3.6.3 Correction of logging parameters
The reading logging parameters should be corrected with various necessary corrections using the interpretation chart corresponding to the logging instrument, and all logging parameters should be corrected to the values under the most commonly used well diameter conditions. , fill in Appendix B (Standard Appendix) Table B2 and Table B3. 3.6.4 Select or compile various relationship charts
3.6.4.1 Lithology identification chart
Under the condition of having LDL, CNL, FDL, BHC and other logging data, you can choose ph-Pe, MN, MID, P%- and other lithology identification charts to determine the rock composition and its percentage layer by layer. By compiling a relationship chart or directly analyzing the data in Appendix B (Standard Appendix) Table B2, select the lithology identification chart that is closest to the main rock composition and percentage of the core analysis. In the absence of the above-mentioned logging data, according to the core and logging data, combined with the logging data summary rules, determine the identification chart suitable for the geological characteristics of this area. Method to identify the main lithology. 3.6.4.2 Porosity chart
When multiple logging data such as CNL, FDL, BHC, NG, etc. are available, various porosity charts can be selected to calculate the total porosity of each layer. Then, compare with the core analysis porosity to select the porosity chart suitable for this area. When only NG and BHC porosity logging data are available, the neutron gamma porosity chart can be used. 3.6.4.3 Mud content chart
When NGS logging data are available, a CGR-V relationship diagram [see Appendix A (Standard Appendix) Figure A7] is compiled as the mud content chart for the area. When NGS logging data are not available, core analysis data and natural gamma logging data can be used to compile G The R-V relationship diagram is shown in Appendix A (Appendix to the standard) Figure A8, which is used as a plate for estimating the mud content in this area. The GR-V relationship diagram can be used to determine whether there are high-uranium-containing layers in this area, which are mainly sedimentary types; if so, the characteristics of its logging curves should be summarized and treated as special layers.
3.6.4.4 Prepare reservoir division and logging parameter relationship diagrams a) Prepare frequency histograms of Rild, CGR, SGR or GR, 9., V and other parameters based on the corrected reservoir logging parameters and interpretation results in Table B3 of Appendix B (Appendix to the standard) [see Figure A9 of Appendix A (Appendix to the standard)]: b) Based on the reservoir division conclusions and corrected logging parameters and interpretation results obtained from non-logging data in Table B3 of Appendix B (Appendix to the standard) 3
SY/T 5388—2000
results, and various cross-plots such as Rm-CGR, Ra-,,-CGR are compiled respectively; c) In the absence of NGS logging data and only NG porosity logging data, various cross-plots such as Ru-GR, Rit-NG, GR-NG can be compiled respectively according to the reservoir division conclusions obtained from non-logging data in Table B3 of Appendix B (Standard Appendix) and the corrected logging parameters [see Appendix A (Standard Appendix) Figures A10, A11, and A12]. 3.6.5 Determination of logging parameter standards for reservoir division 3.6.5.1 Determination of reservoir boundaries
According to the distribution law of Class I, II reservoirs (excluding high natural gamma reservoirs) and non-reservoirs on each cross-plot, and referring to the main distribution range on the frequency histogram of reservoir single parameters, the boundary between Class I, II reservoirs and non-reservoirs is drawn on each cross-plot. If the boundary between reservoir and non-reservoir on the intersection pavilion is unclear, it is greatly affected by the horizon and the standard should be set according to the horizon. 3.6.5.2 Statistics of the coincidence rate of the intersection map
a) The coincidence rate of Class I and Class II reservoirs is the percentage of the number of reservoir layers of this level in their respective ranges to the total number of layers: b) The coincidence rate of non-reservoir layers is the percentage of the number of non-reservoir layers in the non-reservoir range to the total number of layers in the non-reservoir range: c) The coincidence rate of the plate is the percentage of the sum of the number of reservoir and non-reservoir layers that meet the boundary standards to the total number of layers on the plate. 3.6.5.3 Determination of the reservoir division plate
According to the contents specified in 3.2, the intersection map with a coincidence rate of more than 80% for the division of reservoirs and non-reservoirs and a coincidence rate of more than 70% for the division of Class I and Class II reservoirs in this area shall be selected as the reservoir division plate of this area. 3.6.5.4 Determination of logging parameter standards for reservoir division If the requirements specified in 3.2.2 are met, the cutoff values of various logging parameters of the reservoir determined by these relationship diagrams shall be used as the logging parameter standards for reservoir division in this area [see Appendix B (Standard Appendix) Table B4]. Under the condition of having special logging data such as CHI1, STARII, LSS and FIL, combined with the reservoir division conclusions obtained from non-logging data, a qualitative and quantitative evaluation of the degree of fracture development of reservoirs at all levels is made as an important indicator for carbonate reservoir division.
4 Steps for single well reservoir division
4.1 Collect basic data
Collect logging, well logging, oil testing and other data of this well and adjacent wells. 4.2 Layering
4.2.1 Layering mainly uses logging curves such as DLL, MSFI, NGS or GR, CNL or NG. 4.2.2 The principle of layering is: the lithology, mud content, total porosity and pore seepage capacity within the layer should be basically the same, that is, under the condition that CAL does not change much, the logging curves such as Pe, CGR or GR, y or NG, Rl should not have great fluctuations within the layer. 4.3 Reading and correcting measurement parameters
The measurement parameters should read the half-mean value within the layer, and the correction should be carried out according to the provisions of 3.6.3. 4.4 Identify lithology, calculate porosity and shale content 4.4.1 Apply the lithology identification chart in the reservoir classification standard of this area, refer to the rock logging data of this well, identify the main lithology of each layer in this well, and calculate its percentage:
4.4.2 Apply the porosity chart and shale content chart in the reservoir classification standard of this area to calculate the total porosity and shale content of each layer in this well.
4.5 Evaluate the degree of fracture development
The method shall be implemented in accordance with the provisions of 3.6.5.4.
4.6 Determine the reservoir type
Determine the reservoir type of each reservoir section based on the logging curve characteristics of each type of reservoir in the reservoir classification standard of this area. 4.7 Classification of reservoirs and non-reservoir layers
Based on the logging parameter standards for the classification of various reservoirs in this area and the corrected logging parameters of each layer in this well, refer to the basic data of logging, coring and oil testing, logging, logging, etc. of this well and neighboring wells, the 1,1 reservoirs and non-reservoir layers of this well are classified. 4.8 Preparation of single well reservoir data table
The single well reservoir data table is shown in Appendix B (Standard Appendix) Table B5, including: a) depth and thickness;
b) original and corrected logging parameters; c) rock composition and total porosity obtained from logging data; d) reservoir classification conclusion.
4.9 Preparation of single well reservoir thickness and porosity statistics table The contents of the single well reservoir thickness and porosity statistics table are shown in Appendix B (Standard Appendix) Table B6, including: sub-layer, oil group, total thickness of the whole well, 1, Class II reservoir thickness, non-reservoir thickness, thickness-weighted average porosity and percentage of each level of reservoir thickness to total thickness. 5
SY/T5388—2000
Appendix A
(Standard Appendix)
Carbonate reservoir division map
Carbonate reservoir division map is shown in Figures A1 to A12. Core description data
Determine reservoir and non-reservoir
Determine logging curve characteristics of various reservoirs and non-reservoir
Core physical property analysis data
Determine various reservoirs and non-reservoir
Lithology and physical property standards
Select or compile lithology and physical property logging interpretation charts
Reservoir division, establishment of logging parameter standards Division of single well reservoir
Comprehensive logging data of this well
Logging, oil testing, logging and other data of neighboring wells
Geophysical logging data
Read, correct
Measurement and parameters
Comprehensive logging data
Distinguish reservoir
and non-reservoir
Oil testing data
Determine reservoir level
and non-reservoir
Prepare various reservoir and non-reservoir measurement and parameter relationship diagrams, determine reservoirs, and classify logging parameter standards
Comprehensive logging data of this well
Stratification, reading, and correction of logging parameters
Identify lithology and calculate mixed material content
Calculate physical property parameters
Classify reservoir levels and non-reservoir layers
Prepare single well reservoir classification data table
Figure A1 Flow chart of carbonate reservoir classification 100
Thrombolite dolomite,
conical stromatolite
dolomite
laminated stone, small ripple
stromatolite dolomite
SYT53882000
mud-fine powder crystal
dolomite
Oil spot
Gritty dolomite
Siliceous dolomite,
Siliceous rock
No oil
Figure A2 Schematic diagram of the relationship between lithology and oil content of carbonate reservoirs1
Porosity, %
·Oil content
×No oil
Figure A3 Schematic diagram of the relationship between physical properties and oil content of carbonate reservoirs9
Muddy dolomite
SY/T 5388—2000
Average pore value,
Figure A4 Schematic diagram of the relationship between the average pore value and oil content of carbonate reservoirs 12
·Class 1
Average pore value, m
XNon-reservoir
5 Schematic diagram of the relationship between the average pore value and porosity of carbonate reservoirs Figure A5
Capillary pressure,
Calculate saturation, %
Pore distribution;
Throat width, "
Porosity, %
Submergence, 10u2"
Average pore gland value,
Hg and degree, %
Class ester scene
SY/T 5388--2000
Type II reservoir
Male stromatolite
Daytime rock,
Thrombolite dolomite,
02 0.5 1 2\5
Value layered thrombolite
Baiyi rock,
Gouden Jiaosen dolomite
Layered flower dolomite
Non-reservoir
020.51725
020.51 2 5
Layered siliceous
Dolomite,
Siliceous dolomite
Figure A6 Schematic diagram of carbonate reservoir classification
Vsh = 0. 468CGR
APT
Muddy dolomite
Figure A7 Schematic diagram of the relationship between deuranium natural gamma and mud content in carbonate reservoirs 9
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