SY/T 5387-2000 Geological technical requirements for test production of conventional crude oil reservoirs
Some standard content:
ICS 75.180.99
Registration No.: 8188-2001
Petroleum and Natural Gas Industry Standard of the People's Republic of China SY/T 5387---2000
Technical requirement of geology for conventional oilreservoir production test
Published on 2000-12-25
State Administration of Petroleum and Chemical Industry
Implemented on 2001-06-01
SY/T 5387---2000
１ Scope
2 Referenced standards
3 Purpose and tasks of trial production
4 Geological basis of trial production
5 Development deployment of trial production and area
6 Trial production management
7 Compilation and summary of trial production data
Appendix A (suggested appendix)
Format of trial production table
SY/T 5387—2000
Before being put into development, oil reservoirs generally undergo trial production. The static and dynamic data of oil reservoirs obtained from test production are important first-hand data for understanding the geological characteristics of oil reservoirs, understanding the production capacity of oil layers, mastering the production characteristics of test production wells, and evaluating the natural energy size of oil reservoirs. They provide geological basis for reasonably determining the scale of oil field production and construction and formulating oil field development plans. The formulation of this standard is helpful to standardize oil reservoir test production work and improve the quality of test production work.
This standard is revised on the basis of SY/T5387-91 "Geological Technical Requirements for Test Production of Sandstone Oilfields". The original standard content is relatively simple. This revision supplements the tasks and tasks of the test production month, the geological basis of test production, the development deployment of the test production well area, and the management of the test production, so that the content of oil reservoir test production work is more substantial and the requirements are clearer. From the date of entry into force, this standard will replace SY/T5387-91. 5387—91. Appendix A of this standard is a suggestive appendix.
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 the Sixth Oil Production Plant of Daqing Oilfield Co., Ltd. The main drafters of this standard are Liu Yuchen and Ye Qingquan. This standard was first issued in July 1991, and this is the first revision. V
1 Scope
Petroleum and Natural Gas Industry Standard of the People's Republic of China Technical requirement of geology for conventional oil reservoir production SY/T 5387---2000
Technokogical requirement of geology for conventional oil replaces SY/T 5387-91reservoir production test
This standard specifies the tasks, contents and technical requirements for test production of conventional crude oil reservoirs. This standard applies to the test production of conventional crude oil reservoirs. 2 Cited standards
The provisions contained in the following standards constitute the provisions of this standard through reference in this standard. At the time of publication of this standard: the versions shown are valid. All standards will be revised, and parties using this standard should explore the possibility of using the latest versions of the following standards. SY/T6167—1995 Natural energy evaluation method for oil reservoirsSY/T6172--1995 Technical requirements for oil well testingSY/T6287—1997 Method for determining non-recovery indexSY/T 6313.1—1998 Method for determining gas-water interface Oil-gas, oil-water interface SY/T6365—1998 Method for determining original formation pressure and pressure system of oil-gas cut-off 3 Objectives and tasks of production test
3.1 Conduct system well testing to determine the reasonable working system and initial production of the production test well. 3.2 Analyze the production changes of production test, evaluate the production capacity of the oil layer, and analyze the stable production conditions of the oil layer. 3.3 Master the production characteristics of the production test well and the advancement of edge water (bottom water). 3.4 Clarify the flow properties of the reservoir, the distribution of gas, oil and water, temperature, pressure system, etc., and determine the type of reservoir. 3.5 Determine the type of reservoir drive, evaluate the natural energy of the reservoir, and propose the idea of reservoir development and development. 3.6 Analyze the production technical conditions of production test, and propose a reasonable development structure and completion method. 3.7 "Understand the sensitivity and pollution of the reservoir, and propose the best measures for oil layer transformation and protection; understand the sand production of the oil layer, and propose sand control measures.
3.8 Implement the geological reserves of the reservoir, calculate the economically recoverable reserves, and evaluate the economic benefits of Shantian development. 3.9 Analyze the development and deployment effects of the test well area, and provide parameters and basis for reasonable oil field development deployment. 4 Geological basis for test production
41 Under normal circumstances, after evaluation drilling (detailed exploration), the geological characteristics of the oil line must be understood fundamentally before the test can be carried out. Test production can be carried out. a) Structural type, fault properties and their distribution; b) Reservoir lithology, physical properties, heterogeneity, thickness changes, etc.; c) Interlayer lithology, physical properties and their distribution; d) Reservoir sedimentary phase type;
e) Surface and underground properties of fluids and their changes in the plane and vertical direction; ) Gas, oil, water distribution, original formation pressure, pressure system, and original formation temperature, etc.; g) Proven reserves,
State Administration of Petroleum and Chemical Industry 2000-12-25 Approved 2001-06 -01 Implementation
SY/T5387—2000
4.2 In addition to a comprehensive understanding of the above issues, fractured reservoirs should also have some understanding of reservoir space type, fracture occurrence, opening degree, filling distribution, development location, etc. 4.3 For Xiaoshanzang (including fault block reservoirs) that adopt rolling exploration and development, a preliminary understanding of structural type, reservoir characteristics, fault block distribution characteristics, fluid properties, etc. should be obtained.
5 Development deployment of test well area
5.1 Determination of test well area and test well area
5.1.1 Test well area The scale should be determined according to the size of the reservoir's geological reserves, the complexity of the geology and the needs of oilfield development. For large-scale reservoirs (geological reserves greater than 1×10°t), a test production area can be opened for test production; for medium-sized reservoirs [geological reserves (0.1~1)×108t], 1~2 well groups can be designed for test production; for small reservoirs (geological reserves less than 0.1×10°t), 1~3 wells can be designed for test production; and for the main blocks of complex fault-block oilfields, at least one well should be used for test production. 5.1.2 The selection of test production areas, test production well groups and test production well locations should take into account their representativeness, independence, topography and intersection. 5.2 Division and combination of test production strata
5.2.1 The oil layer is single, not thick, and the well section is not long. It is not necessary to divide the strata during the test production. However, it is necessary to divide the test strata in the following situations: a) The types of closures between oil layers are different;
b) There are many oil layers, the oil layer properties are very different, and the well section is long; c) The distribution patterns and pressure systems of oil, gas, and water between oil layers are different; d) The properties of crude oil between oil layers are very different;
e) The driving types between oil layers are different.
5.2.2 The following principles should be followed when dividing and combining test production strata: a) Each There must be certain thickness and stable distribution of separation layers between the test production layers to ensure that the fluids between the test production layers cannot be misaligned.
b) Each test production layer has certain geological reserves, production capacity and economic benefits. c) The oil layer properties, sedimentary types, structural morphology, driving type, pressure system, crude oil properties, etc. within the same test production layer should be roughly consistent.
5.3 Determination of well network
5.3.1 The well network form and well row direction of the test production well area (test production area, test production well group) should be determined according to its structural type, sand body morphology, fault and fracture distribution conditions, etc.
5.3.2 The well density of the test well area should be determined according to the following principles: a) The oil layer can be basically controlled, and the connected thickness reaches more than 70% of the total thickness of the oil layer; b) A high oil production rate is required to avoid too long test production time. The oil production rate of fractured and bottom water reservoirs can be reduced: c) The grid connection should have a certain flexibility, which is conducive to the connection with the future oil field development well network; d) The investment is small and good economic benefits are guaranteed. 5.3.3 For single and test production, representative exploration wells can be selected, evaluated and used as test wells. 5.4 Determination of oil production method
The oil production method should be determined according to the natural energy size and economic benefits of the oil reservoir. If the natural energy is sufficient, the self-spraying method can be used for test production: if it cannot be sprayed in vain, the mechanical oil production method can be used for test production. 5.5 Determination of test production time
The test production time should be determined according to the natural energy size of the oil reservoir and the needs of development work, generally one to three years. For small oil reservoirs that adopt rolling exploration and development, it can be determined according to specific circumstances. 6 Test production management
6.1 Determination of the test production well work system
SY/T5387—2000
6.1.1 A systematic well test should be carried out before the test production, and an indication curve should be drawn based on the data obtained from the well test. 6.1.2. Determine the working system of the test well according to the normal indication curve. The determined initial production should be conducive to: a) uniform advancement of the oil-bearing edge of the edge water reservoir; b) prevent the formation of cone in the bottom water reservoir; c) be conducive to the uniform expansion of the gas cap fluid in the gas cap reservoir; d) prevent oil layer degassing and excessive increase of gas-oil ratio; c) control the sand output to ensure normal production, economically reasonable, and achieve the highest economic recovery rate. 6.1.3 Adjust the working system in time according to the changes in the production status of the test well. 6.2 Establish a dynamic monitoring system
6.2.1 During the test production, a dynamic monitoring system for formation pressure, formation temperature, production surface, fluid properties, ground stress and fracture distribution direction should be established. The gas cap reservoir, edge water and bottom water reservoir should monitor the oil and gas, oil-water interface and bottom water movement. 6.2.2 The number of observation wells should be determined according to the specific conditions of the reservoir and the design requirements of the test production. 6.3 Test production data collection
6.3.1 Oil, gas and water production
Measure the oil, gas and water production once per shift, and calculate the daily oil production, daily water production and gas production once a day. 6.3.2 Pressure
The formation pressure and pressure recovery curve should be measured before and at the end of the test production. During the normal test production, the formation pressure of the self-flowing wells shall be measured once a month, and the formation pressure of the non-white-flowing wells shall be measured once a quarter. The flowing pressure or dynamic liquid level of the self-flowing wells and non-self-flowing wells shall be measured once every half month. The tubing pressure and casing pressure shall be recorded once in each shift.
6.3.3 Formation temperature
Measure the formation pressure and the pressure recovery curve while measuring the formation temperature. Measure the flowing pressure while measuring the bottom flow temperature. 6.3.4 Oil, gas, water samples and sand content analysis Take oil, gas, water samples and sand content analysis once a month, and take oil, gas and water samples once a quarter for full analysis. 6.3.5 High-pressure physical properties
According to the requirements of the production test design, high-pressure physical properties shall be sampled and analyzed. 6.3.6 Production test
According to the requirements of the production test design, the production test well shall be tested once every 3 to 6 months to obtain the oil and water production data of the layered production. If necessary, the layered pressure data shall be obtained. 6.3.7 Well testing
According to the requirements of the production test design, representative production test wells shall be selected and tested once every six months. The well testing methods, steps, data collection, etc. shall be carried out in accordance with the provisions of SY/T6172.
6.4 Dynamic analysis and adjustment
6.4.1 A single well dynamic analysis shall be carried out once a month to study whether the changes in pressure, production, water content, gas-oil ratio, etc. are normal, whether the working system is reasonable, and whether the downhole technical conditions are good. 6.4.2 A comprehensive analysis of the test well area should be conducted once a quarter to study the changing trends of pressure, production, water content, oil-gas ratio, oil layer production capacity, interlayer and plane relationship, and working conditions of various oil layers, analyze the causes of changes, and formulate corresponding measures. 6.4.3 Numerical simulation and other means can be used to predict the development effect. 7. Compilation and summary of test production data
7.1 Content of data compilation
The following data should be compiled at the end of the test production.
a) Oil production, gas production, water production, oil-gas ratio, water content change curve: SY/T 5387-2000
b) Formation pressure, flow pressure, dynamic liquid level, tubing pressure, casing pressure change curve; :) Formation temperature and flow temperature and their gradient change curve; d) Pressure drop curve and pressure recovery curve;
e) System well test data and indication curve;
1) Analysis data of oil, gas and water samples;
g) High-pressure physical property sampling and analysis data.
7.2 Parameter calculation and determination method
7.2.1 Calculate the oil production index of the test well according to the relevant formula in SY/T6287. 7.2.2 Determine the original formation pressure and pressure system according to the method specified in SY/T6365. 7.2.3 Determine the oil-gas and oil-water interface according to the method specified in SY/T6313.1. 7.2.4 Calculate the natural energy of the reservoir according to the method specified in SY/T6167, and evaluate it according to its evaluation indicators. 7.2.5 Obtain the following according to the method specified in SY/T6172: productivity coefficient, skin coefficient, pressure conductivity, combined storage coefficient, detection radius, effective well radius, boundary distance, geological reserves, pore volume connected to the combined tube, oil leakage area, vertical fracture length, vertical self-fracture braid conductivity, etc.
7.3 Prepare the test production report
7.3.1 Contents of preparation
The text part of the report should include the following contents. a) Purpose and tasks of the test production;
b) Geological overview of the test production well area;
c) Test production history;
d) Test production analysis and conclusions;
e) Opinions on oilfield development and next steps. 7.3.2 Main drawings
The following main drawings should be attached to the report.
a) Well location and geological comprehensive map of the test well area; b) Comprehensive test production curve of the test well area;
c) Current mining situation map of the test well area;
d) Liquid production profile;
c) Test production curve of each single well:
f) Indicator curve;
g) Basic map of various well testing methods.
7.3.3 Main appendixes
The following main appendixes should be attached to the report.
a) Single test production data table;
b) Comprehensive test production data table of the test well area;
c) Test and test data table;
d) Oil, gas and water analysis data table;
e) High-pressure physical property analysis data sheet.
The formats of each table are shown in Appendix A (Suggested Appendix) Period
Test production table formats are shown in Table A1-Table A8
Formulator:
SY7T 5387—2000
Appendix A
(Suggested Appendix)
Test production table format
×× oil reservoir ×× and test production data table
Open well, close well, open well!
Reviewer
Formulator:
Formulation period:
×× oil reservoir ×× and area ×× month test production comprehensive data table oil
Reviewer:
m*/dm/dm/d/m
Formulation date:
Year Month H
Cumulative, cumulative cumulative
Oil layer! Preparation
Water production) Gas production
Oil production"
Quantity! Quantity
Year Month Day
Tester:
Well shut-in time
Tester:
SY/T5387—2000
×× and stable test and test data table
Auditor:
Oil production Gas production Base water production
Test date:
Table A4×× well is unstable Well test data table Shut-in oil Shut-in casing Actual well
Cumulative shut-in
Pressure (absolute) Pressure (absolute) Bottom pressure
Well time
Reviewer:
Test date:
Year/month/day
Table A5×× oil reservoir×× test well area crude oil analysis results Surface layer
Preparer:
Reviewer:
Freezing point
Wax content
Gel content|| tt||Date of preparation:
Before shutting in the well, the stable
oil and gas production and the corresponding
flow pressure must be measured
Year, month, day
Asphalt content
Sulfur content
Year, month, day
Prepared by:
SY/T5387—2000
Table A6×× oil reservoir×× test well area gas analysis results table Laboratory
Overview layer Overview sample Laboratory C| |tt||Date Date
Preparer:
Reviewer:
Preparation Date:
X×Oil Reservoir××Test Production Well Area Formation Water Analysis Results Table CL
Reviewer:
Preparation Date:
Year Month Day
Year Month Day
Trace Elements
SY/r5387--2000
Table A8××Oil× ×Test production and high pressure physical property analysis results table Formation flowing oil
Well olive sample Room sample Test sample
Lili Le
Location Date Date
Preparer
Reviewer
Oil-gas ratio
Original formation viscosity
ml'a*s
Preparation date:
m/(MPa*m)
Year Month Day2 Establish a dynamic monitoring system
6.2.1 During the trial production, a dynamic monitoring system for formation pressure, formation temperature, production surface, fluid properties, ground stress and fracture distribution direction should be established. Gas-cap reservoirs, edge water and bottom water reservoirs should monitor oil and gas, oil-water interface and bottom water movement. 6.2.2 The number of observation wells should be determined according to the specific conditions of the reservoir and the design requirements of the trial production. 6.3 Recording of trial production data
6.3.1 Oil, gas and water production
Measure the oil, gas and water production once per shift, and calculate the daily oil production, daily water production and mouth gas production once a day. 6.3.2 Pressure
The formation pressure and pressure recovery curve should be measured before and at the end of the trial production. During the normal trial production, the formation pressure of the self-flowing wells shall be measured once a month, and the formation pressure of the non-white-flowing wells shall be measured once a quarter. The flowing pressure or dynamic liquid level of the self-flowing wells and non-self-flowing wells shall be measured once every half month. Record tubing pressure and casing pressure once per shift.
6.3.3 Formation temperature
Measure formation pressure and pressure recovery curve while measuring formation temperature. Measure flow pressure while measuring bottom hole flow temperature. 6.3.4 Oil, gas, water samples and sand content analysis Take oil, gas, water samples and sand content analysis once a month, and take oil, gas and water samples once a quarter for full analysis. 6.3.5 High-pressure physical properties
According to the requirements of the production test design, high-pressure physical properties sampling and analysis are carried out. 6.3.6 Production test
According to the requirements of the production test design, the production test wells are tested once every 3 to 6 months to obtain the oil and water production data of the layers, and the layer pressure data should be obtained when necessary. 6.3.7 Well test
According to the requirements of the production test design, select representative production test wells and conduct well tests every six months. The well test methods, steps, data collection, etc. shall be carried out in accordance with the provisions of SY/T6172.
6.4 Dynamic analysis and adjustment
6.4.1 A single well dynamic analysis should be conducted once a month to study whether the changes in pressure, production, water content, gas-oil ratio, etc. are normal, whether the working system is reasonable, and whether the downhole technical conditions are good. 6.4.2 A comprehensive analysis of the test well area should be conducted once a quarter to study the changing trends of pressure, production, water content, oil-gas ratio, oil layer production capacity, interlayer and plane relationships, and the working conditions of various oil layers, analyze the causes of the changes, and formulate corresponding measures. 6.4.3 Numerical simulation and other means can be used to predict the development effect. 7 Trial production data collation and summary
7.1 Data collation content
The following data should be collated at the end of the trial production.
a) Oil production, gas production, water production, oil-gas ratio, water content change curve: SY/T 5387-2000
b) Formation pressure, flow pressure, dynamic liquid level, tubing pressure, casing pressure change curve; :) Formation temperature and flow temperature and their gradient change curve; d) Pressure drop curve and pressure recovery curve;
e) System well test data and indication curve;
1) Analysis data of oil, gas and water samples;
g) High-pressure physical property sampling and analysis data.
7.2 Parameter calculation and determination method
7.2.1 Calculate the oil production index of the test well according to the relevant formula in SY/T6287. 7.2.2 Determine the original formation pressure and pressure system according to the method specified in SY/T6365. 7.2.3 Determine the oil-gas and oil-water interface according to the method specified in SY/T6313.1. 7.2.4 Calculate the natural energy of the reservoir according to the method specified in SY/T6167, and evaluate it according to its evaluation indicators. 7.2.5 Obtain the following according to the method specified in SY/T6172: productivity coefficient, skin coefficient, pressure conductivity, combined storage coefficient, detection radius, effective well radius, boundary distance, geological reserves, pore volume connected to the combined tube, oil leakage area, vertical fracture length, vertical self-fracture braid conductivity, etc.
7.3 Prepare the test production report
7.3.1 Contents of preparation
The text part of the report should include the following contents. a) Purpose and tasks of the test production;
b) Geological overview of the test production well area;
c) Test production history;
d) Test production analysis and conclusions;
e) Opinions on oilfield development and next steps. 7.3.2 Main drawings
The following main drawings should be attached to the report.
a) Well location and geological comprehensive map of the test well area; b) Comprehensive test production curve of the test well area;
c) Current mining situation map of the test well area;
d) Liquid production profile;
c) Test production curve of each single well:
f) Indicator curve;
g) Basic map of various well testing methods.
7.3.3 Main appendixes
The following main appendixes should be attached to the report.
a) Single test production data table;
b) Comprehensive test production data table of the test well area;
c) Test and test data table;
d) Oil, gas and water analysis data table;
e) High-pressure physical property analysis data sheet.
The formats of each table are shown in Appendix A (Suggested Appendix) Period
Test production table formats are shown in Table A1-Table A8
Formulator:
SY7T 5387—2000
Appendix A
(Suggested Appendix)
Test production table format
×× oil reservoir ×× and test production data table
Open well, close well, open well!
Reviewer
Formulator:
Formulation period:
×× oil reservoir ×× and area ×× month test production comprehensive data table oil
Reviewer:
m*/dm/dm/d/m
Formulation date:
Year Month H
Cumulative, cumulative cumulative
Oil layer! Preparation
Water production) Gas production
Oil production"
Quantity! Quantity
Year Month Day
Tester:
Well shut-in time
Tester:
SY/T5387—2000
×× and stable test and test data table
Auditor:
Oil production Gas production Base water production
Test date:
Table A4×× well is unstable Well test data table Shut-in oil Shut-in casing Actual well
Cumulative shut-in
Pressure (absolute) Pressure (absolute) Bottom pressure
Well time
Reviewer:
Test date:
Year/month/day
Table A5×× oil reservoir×× test well area crude oil analysis results Surface layer
Preparer:
Reviewer:
Freezing point
Wax content
Gel content|| tt||Date of preparation:
Before shutting in the well, the stable
oil and gas production and the corresponding
flow pressure must be measured
Year, month, day
Asphalt content
Sulfur content
Year, month, day
Prepared by:
SY/T5387—2000
Table A6×× oil reservoir×× test well area gas analysis results table Laboratory
Overview layer Overview sample Laboratory C| |tt||Date Date
Preparer:
Reviewer:
Preparation Date:
X×Oil Reservoir××Test Production Well Area Formation Water Analysis Results Table CL
Reviewer:
Preparation Date:
Year Month Day
Year Month Day
Trace Elements
SY/r5387--2000
Table A8××Oil× ×Test production and high pressure physical property analysis results table Formation flowing oil
Well olive sample Room sample Test sample
Lili Le
Location Date Date
Preparer
Reviewer
Oil-gas ratio
Original formation viscosity
ml'a*s
Preparation date:
m/(MPa*m)
Year Month Day2 Establish a dynamic monitoring system
6.2.1 During the trial production, a dynamic monitoring system for formation pressure, formation temperature, production surface, fluid properties, ground stress and fracture distribution direction should be established. Gas-cap reservoirs, edge water and bottom water reservoirs should monitor oil and gas, oil-water interface and bottom water movement. 6.2.2 The number of observation wells should be determined according to the specific conditions of the reservoir and the design requirements of the trial production. 6.3 Recording of trial production data
6.3.1 Oil, gas and water production
Measure the oil, gas and water production once per shift, and calculate the daily oil production, daily water production and mouth gas production once a day. 6.3.2 Pressure
The formation pressure and pressure recovery curve should be measured before and at the end of the trial production. During the normal trial production, the formation pressure of the self-flowing wells shall be measured once a month, and the formation pressure of the non-white-flowing wells shall be measured once a quarter. The flowing pressure or dynamic liquid level of the self-flowing wells and non-self-flowing wells shall be measured once every half month. Record tubing pressure and casing pressure once per shift.
6.3.3 Formation temperature
Measure formation pressure and pressure recovery curve while measuring formation temperature. Measure flow pressure while measuring bottom hole flow temperature. 6.3.4 Oil, gas, water samples and sand content analysis Take oil, gas, water samples and sand content analysis once a month, and take oil, gas and water samples once a quarter for full analysis. 6.3.5 High-pressure physical properties
According to the requirements of the production test design, high-pressure physical properties sampling and analysis are carried out. 6.3.6 Production test
According to the requirements of the production test design, the production test wells are tested once every 3 to 6 months to obtain the oil and water production data of the layers, and the layer pressure data should be obtained when necessary. 6.3.7 Well test
According to the requirements of the production test design, select representative production test wells and conduct well tests every six months. The well test methods, steps, data collection, etc. shall be carried out in accordance with the provisions of SY/T6172.
6.4 Dynamic analysis and adjustment
6.4.1 A single well dynamic analysis should be conducted once a month to study whether the changes in pressure, production, water content, gas-oil ratio, etc. are normal, whether the working system is reasonable, and whether the downhole technical conditions are good. 6.4.2 A comprehensive analysis of the test well area should be conducted once a quarter to study the changing trends of pressure, production, water content, oil-gas ratio, oil layer production capacity, interlayer and plane relationships, and the working conditions of various oil layers, analyze the causes of the changes, and formulate corresponding measures. 6.4.3 Numerical simulation and other means can be used to predict the development effect. 7 Trial production data collation and summary
7.1 Data collation content
The following data should be collated at the end of the trial production.
a) Oil production, gas production, water production, oil-gas ratio, water content change curve: SY/T 5387-2000
b) Formation pressure, flow pressure, dynamic liquid level, tubing pressure, casing pressure change curve; :) Formation temperature and flow temperature and their gradient change curve; d) Pressure drop curve and pressure recovery curve;
e) System well test data and indication curve;
1) Analysis data of oil, gas and water samples;
g) High-pressure physical property sampling and analysis data.
7.2 Parameter calculation and determination method
7.2.1 Calculate the oil production index of the test well according to the relevant formula in SY/T6287. 7.2.2 Determine the original formation pressure and pressure system according to the method specified in SY/T6365. 7.2.3 Determine the oil-gas and oil-water interface according to the method specified in SY/T6313.1. 7.2.4 Calculate the natural energy of the reservoir according to the method specified in SY/T6167, and evaluate it according to its evaluation indicators. 7.2.5 Obtain the following according to the method specified in SY/T6172: productivity coefficient, skin coefficient, pressure conductivity, combined storage coefficient, detection radius, effective well radius, boundary distance, geological reserves, pore volume connected to the combined tube, oil leakage area, vertical fracture length, vertical self-fracture braid conductivity, etc.
7.3 Prepare the test production report
7.3.1 Contents of preparation
The text part of the report should include the following contents. a) Purpose and tasks of the test production;
b) Geological overview of the test production well area;
c) Test production history;
d) Test production analysis and conclusions;
e) Opinions on oilfield development and next steps. 7.3.2 Main drawings
The following main drawings should be attached to the report.
a) Well location and geological comprehensive map of the test well area; b) Comprehensive test production curve of the test well area;
c) Current mining situation map of the test well area;
d) Liquid production profile;
c) Test production curve of each single well:
f) Indicator curve;
g) Basic map of various well testing methods.
7.3.3 Main appendixes
The following main appendixes should be attached to the report.
a) Single test production data table;
b) Comprehensive test production data table of the test well area;
c) Test and test data table;
d) Oil, gas and water analysis data table;
e) High-pressure physical property analysis data sheet.
The formats of each table are shown in Appendix A (Suggested Appendix) Period
Test production table formats are shown in Table A1-Table A8
Formulator:
SY7T 5387—2000
Appendix A
(Suggested Appendix)
Test production table format
×× oil reservoir ×× and test production data table
Open well, close well, open well!
Reviewer
Formulator:
Formulation period:
×× oil reservoir ×× and area ×× month test production comprehensive data table oil
Reviewer:
m*/dm/dm/d/m
Formulation date:
Year Month H
Cumulative, cumulative cumulative
Oil layer! Preparation
Water production) Gas production
Oil production"
Quantity! Quantity
Year Month Day
Tester:
Well shut-in time
Tester:
SY/T5387—2000
×× and stable test and test data table
Auditor:
Oil production Gas production Base water production
Test date:
Table A4×× well is unstable Well test data table Shut-in oil Shut-in casing Actual well
Cumulative shut-in
Pressure (absolute) Pressure (absolute) Bottom pressure
Well time
Reviewer:
Test date:
Year/month/day
Table A5×× oil reservoir×× test well area crude oil analysis results Surface layer
Preparer:
Reviewer:
Freezing point
Wax content
Gel content|| tt||Date of preparation:
Before shutting in the well, the stable
oil and gas production and the corresponding
flow pressure must be measured
Year, month, day
Asphalt content
Sulfur content
Year, month, day
Prepared by:
SY/T5387—2000
Table A6×× oil reservoir×× test well area gas analysis results table Laboratory
Overview layer Overview sample Laboratory C| |tt||Date Date
Preparer:
Reviewer:
Preparation Date:
X×Oil Reservoir××Test Production Well Area Formation Water Analysis Results Table CL
Reviewer:
Preparation Date:bZxz.net
Year Month Day
Year Month Day
Trace Elements
SY/r5387--2000
Table A8××Oil× ×Test production and high pressure physical property analysis results table Formation flowing oil
Well olive sample Room sample Test sample
Lili Le
Location Date Date
Preparer
Reviewer
Oil-gas ratio
Original formation viscosity
ml'a*s
Preparation date:
m/(MPa*m)
Year Month Day3 Formation temperature
Measure formation pressure and pressure recovery curve while measuring formation temperature. Measure flow pressure while measuring bottom flow temperature. 6.3.4 Oil, gas, water samples and sand content analysis Take oil, gas, water samples and sand content analysis once a month, and take oil, gas and water samples once a quarter for full analysis. 6.3.5 High-pressure physical properties
According to the requirements of the test production design, high-pressure physical properties are sampled and analyzed. 6.3.6 Production test
According to the requirements of the test production design, the test production wells are tested once every 3 to 6 months to obtain the oil and water production data of the layer, and the layer pressure data should be obtained when necessary. 6.3.7 Well test
According to the requirements of the test production design, select representative test production wells and conduct well tests every six months. The well test methods, steps, data collection, etc. shall be implemented in accordance with the provisions of SY/T6172.
6.4 Dynamic analysis and adjustment
6.4.1 A single well dynamic analysis should be conducted once a month to study whether the changes in pressure, production, water content, gas-oil ratio, etc. are normal, whether the working system is reasonable, and whether the downhole technical conditions are good. 6.4.2 A comprehensive analysis of the test well area should be conducted once a quarter to study the changing trends of pressure, production, water content, oil-gas ratio, oil layer production capacity, interlayer and plane relationships, and the working conditions of various oil layers, analyze the causes of the changes, and formulate corresponding measures. 6.4.3 Numerical simulation and other means can be used to predict the development effect. 7 Trial production data collation and summary
7.1 Data collation content
The following data should be collated at the end of the trial production.
a) Oil production, gas production, water production, oil-gas ratio, water content change curve: SY/T 5387-2000
b) Formation pressure, flow pressure, dynamic liquid level, tubing pressure, casing pressure change curve; :) Formation temperature and flow temperature and their gradient change curve; d) Pressure drop curve and pressure recovery curve;
e) System well test data and indication curve;
1) Analysis data of oil, gas and water samples;
g) High-pressure physical property sampling and analysis data.
7.2 Parameter calculation and determination method
7.2.1 Calculate the oil production index of the test well according to the relevant formula in SY/T6287. 7.2.2 Determine the original formation pressure and pressure system according to the method specified in SY/T6365. 7.2.3 Determine the oil-gas and oil-water interface according to the method specified in SY/T6313.1. 7.2.4 Calculate the natural energy of the reservoir according to the method specified in SY/T6167, and evaluate it according to its evaluation indicators. 7.2.5 Obtain the following according to the method specified in SY/T6172: productivity coefficient, skin coefficient, pressure conductivity, combined storage coefficient, detection radius, effective well radius, boundary distance, geological reserves, pore volume connected to the combined tube, oil leakage area, vertical fracture length, vertical self-fracture braid conductivity, etc.
7.3 Prepare the test production report
7.3.1 Contents of preparation
The text part of the report should include the following contents. a) Purpose and tasks of the test production;
b) Geological overview of the test production well area;
c) Test production history;
d) Test production analysis and conclusions;
e) Opinions on oilfield development and next steps. 7.3.2 Main drawings
The following main drawings should be attached to the report.
a) Well location and geological comprehensive map of the test well area; b) Comprehensive test production curve of the test well area;
c) Current mining situation map of the test well area;
d) Liquid production profile;
c) Test production curve of each single well:
f) Indicator curve;
g) Basic map of various well testing methods.
7.3.3 Main appendixes
The following main appendixes should be attached to the report.
a) Single test production data table;
b) Comprehensive test production data table of the test well area;
c) Test and test data table;
d) Oil, gas and water analysis data table;
e) High-pressure physical property analysis data sheet.
The formats of each table are shown in Appendix A (Suggested Appendix) Period
Test production table formats are shown in Table A1-Table A8
Formulator:
SY7T 5387—2000
Appendix A
(Suggested Appendix)
Test production table format
×× oil reservoir ×× and test production data table
Open well, close well, open well!
Reviewer
Formulator:
Formulation period:
×× oil reservoir ×× and area ×× month test production comprehensive data table oil
Reviewer:
m*/dm/dm/d/m
Formulation date:
Year Month H
Cumulative, cumulative cumulative
Oil layer! Preparation
Water production) Gas production
Oil production"
Quantity! Quantity
Year Month Day
Tester:
Well shut-in time
Tester:
SY/T5387—2000
×× and stable test and test data table
Auditor:
Oil production Gas production Base water production
Test date:
Table A4×× well is unstable Well test data table Shut-in oil Shut-in casing Actual well
Cumulative shut-in
Pressure (absolute) Pressure (absolute) Bottom pressure
Well time
Reviewer:
Test date:
Year/month/day
Table A5×× oil reservoir×× test well area crude oil analysis results Surface layer
Preparer:
Reviewer:
Freezing point
Wax content
Gel content|| tt||Date of preparation:
Before shutting in the well, the stable
oil and gas production and the corresponding
flow pressure must be measured
Year, month, day
Asphalt content
Sulfur content
Year, month, day
Prepared by:
SY/T5387—2000
Table A6×× oil reservoir×× test well area gas analysis results table Laboratory
Overview layer Overview sample Laboratory C| |tt||Date Date
Preparer:
Reviewer:
Preparation Date:
X×Oil Reservoir××Test Production Well Area Formation Water Analysis Results Table CL
Reviewer:
Preparation Date:
Year Month Day
Year Month Day
Trace Elements
SY/r5387--2000
Table A8××Oil× ×Test production and high pressure physical property analysis results table Formation flowing oil
Well olive sample Room sample Test sample
Lili Le
Location Date Date
Preparer
Reviewer
Oil-gas ratio
Original formation viscosity
ml'a*s
Preparation date:
m/(MPa*m)
Year Month Day3 Formation temperature
Measure formation pressure and pressure recovery curve while measuring formation temperature. Measure flow pressure while measuring bottom flow temperature. 6.3.4 Oil, gas, water samples and sand content analysis Take oil, gas, water samples and sand content analysis once a month, and take oil, gas and water samples once a quarter for full analysis. 6.3.5 High-pressure physical properties
According to the requirements of the test production design, high-pressure physical properties are sampled and analyzed. 6.3.6 Production test
According to the requirements of the test production design, the test production wells are tested once every 3 to 6 months to obtain the oil and water production data of the layer, and the layer pressure data should be obtained when necessary. 6.3.7 Well test
According to the requirements of the test production design, select representative test production wells and conduct well tests every six months. The well test methods, steps, data collection, etc. shall be implemented in accordance with the provisions of SY/T6172.
6.4 Dynamic analysis and adjustment
6.4.1 A single well dynamic analysis should be conducted once a month to study whether the changes in pressure, production, water content, gas-oil ratio, etc. are normal, whether the working system is reasonable, and whether the downhole technical conditions are good. 6.4.2 A comprehensive analysis of the test well area should be conducted once a quarter to study the changing trends of pressure, production, water content, oil-gas ratio, oil layer production capacity, interlayer and plane relationships, and the working conditions of various oil layers, analyze the causes of the changes, and formulate corresponding measures. 6.4.3 Numerical simulation and other means can be used to predict the development effect. 7 Trial production data collation and summary
7.1 Data collation content
The following data should be collated at the end of the trial production.
a) Oil production, gas production, water production, oil-gas ratio, water content change curve: SY/T 5387-2000
b) Formation pressure, flow pressure, dynamic liquid level, tubing pressure, casing pressure change curve; :) Formation temperature and flow temperature and their gradient change curve; d) Pressure drop curve and pressure recovery curve;
e) System well test data and indication curve;
1) Analysis data of oil, gas and water samples;
g) High-pressure physical property sampling and analysis data.
7.2 Parameter calculation and determination method
7.2.1 Calculate the oil production index of the test well according to the relevant formula in SY/T6287. 7.2.2 Determine the original formation pressure and pressure system according to the method specified in SY/T6365. 7.2.3 Determine the oil-gas and oil-water interface according to the method specified in SY/T6313.1. 7.2.4 Calculate the natural energy of the reservoir according to the method specified in SY/T6167, and evaluate it according to its evaluation indicators. 7.2.5 Obtain the following according to the method specified in SY/T6172: productivity coefficient, skin coefficient, pressure conductivity, combined storage coefficient, detection radius, effective well radius, boundary distance, geological reserves, pore volume connected to the combined tube, oil leakage area, vertical fracture length, vertical self-fracture braid conductivity, etc.
7.3 Prepare the test production report
7.3.1 Contents of preparation
The text part of the report should include the following contents. a) Purpose and tasks of the test production;
b) Geological overview of the test production well area;
c) Test production history;
d) Test production analysis and conclusions;
e) Opinions on oilfield development and next steps. 7.3.2 Main drawings
The following main drawings should be attached to the report.
a) Well location and geological comprehensive map of the test well area; b) Comprehensive test production curve of the test well area;
c) Current mining situation map of the test well area;
d) Liquid production profile;
c) Test production curve of each single well:
f) Indicator curve;
g) Basic map of various well testing methods.
7.3.3 Main appendixes
The following main appendixes should be attached to the report.
a) Single test production data table;
b) Comprehensive test production data table of the test well area;
c) Test and test data table;
d) Oil, gas and water analysis data table;
e) High-pressure physical property analysis data sheet.
The formats of each table are shown in Appendix A (Suggested Appendix) Period
Test production table formats are shown in Table A1-Table A8
Formulator:
SY7T 5387—2000
Appendix A
(Suggested Appendix)
Test production table format
×× oil reservoir ×× and test production data table
Open well, close well, open well!
Reviewer
Formulator:
Formulation period:
×× oil reservoir ×× and area ×× month test production comprehensive data table oil
Reviewer:
m*/dm/dm/d/m
Formulation date:
Year Month H
Cumulative, cumulative cumulative
Oil layer! Preparation
Water production) Gas production
Oil production"
Quantity! Quantity
Year Month Day
Tester:
Well shut-in time
Tester:
SY/T5387—2000
×× and stable test and test data table
Auditor:
Oil production Gas production Base water production
Test date:
Table A4×× well is unstable Well test data table Shut-in oil Shut-in casing Actual well
Cumulative shut-in
Pressure (absolute) Pressure (absolute) Bottom pressure
Well time
Reviewer:
Test date:
Year/month/day
Table A5×× oil reservoir×× test well area crude oil analysis results Surface layer
Preparer:
Reviewer:
Freezing point
Wax content
Gel content|| tt||Date of preparation:
Before shutting in the well, the stable
oil and gas production and the corresponding
flow pressure must be measured
Year, month, day
Asphalt content
Sulfur content
Year, month, day
Prepared by:
SY/T5387—2000
Table A6×× oil reservoir×× test well area gas analysis results table Laboratory
Overview layer Overview sample Laboratory C| |tt||Date Date
Preparer:
Reviewer:
Preparation Date:
X×Oil Reservoir××Test Production Well Area Formation Water Analysis Results Table CL
Reviewer:
Preparation Date:
Year Month Day
Year Month Day
Trace Elements
SY/r5387--2000
Table A8××Oil× ×Test production and high pressure physical property analysis results table Formation flowing oil
Well olive sample Room sample Test sample
Lili Le
Location Date Date
Preparer
Reviewer
Oil-gas ratio
Original formation viscosity
ml'a*s
Preparation date:
m/(MPa*m)
Year Month Day) Formation temperature and flow temperature and their gradient change curves; d) Pressure drop curve and pressure recovery curve;
e) System well test data and indication curve;
1) Analysis data of shale, gas and water samples;
g) High-pressure physical property sampling and analysis data.
7.2 Parameter calculation and determination method
7.2.1 Calculate the oil production index of the test well according to the relevant formula in SY/T6287. 7.2.2 Determine the original formation pressure and pressure system according to the method specified in SY/T6365. 7.2.3 Determine the oil-gas and oil-water interfaces according to the method specified in SY/T6313.1. 7.2.4 Calculate the natural energy of the reservoir according to the method specified in SY/T6167, and evaluate it according to its evaluation indicators. 7.2.5 Obtain the following according to the method specified in SY/T6172: productivity coefficient, skin coefficient, pressure conductivity, combined storage coefficient, detection radius, effective well radius, boundary distance, geological reserves, pore volume connected to the combined tube, oil leakage area, vertical fracture length, vertical self-fracture braid conductivity, etc.
7.3 Prepare the test production report
7.3.1 Contents of preparation
The text part of the report should include the following contents. a) Purpose and tasks of the test production;
b) Geological overview of the test production well area;
c) Test production history;
d) Test production analysis and conclusions;
e) Opinions on oilfield development and next steps. 7.3.2 Main drawings
The following main drawings should be attached to the report.
a) Well location and geological comprehensive map of the test well area; b) Comprehensive test production curve of the test well area;
c) Current mining situation map of the test well area;
d) Liquid production profile;
c) Test production curve of each single well:
f) Indicator curve;
g) Basic map of various well testing methods.
7.3.3 Main appendixes
The following main appendixes should be attached to the report.
a) Single test production data table;
b) Comprehensive test production data table of the test well area;
c) Test and test data table;
d) Oil, gas and water analysis data table;
e) High-pressure physical property analysis data sheet.
The formats of each table are shown in Appendix A (Suggested Appendix) Period
Test production table formats are shown in Table A1-Table A8
Formulator:
SY7T 5387—2000
Appendix A
(Suggested Appendix)
Test production table format
×× oil reservoir ×× and test production data table
Open well, close well, open well!
Reviewer
Formulator:
Formulation period:
×× oil reservoir ×× and area ×× month test production comprehensive data table oil
Reviewer:
m*/dm/dm/d/m
Formulation date:
Year Month H
Cumulative, cumulative cumulative
Oil layer! Preparation
Water production) Gas production
Oil production"
Quantity! Quantity
Year Month Day
Tester:
Well shut-in time
Tester:
SY/T5387—2000
×× and stable test and test data table
Auditor:
Oil production Gas production Base water production
Test date:
Table A4×× well is unstable Well test data table Shut-in oil Shut-in casing Actual well
Cumulative shut-in
Pressure (absolute) Pressure (absolute) Bottom pressure
Well time
Reviewer:
Test date:
Year/month/day
Table A5×× oil reservoir×× test well area crude oil analysis results Surface layer
Preparer:
Reviewer:
Freezing point
Wax content
Gel content|| tt||Date of preparation:
Before shutting in the well, the stable
oil and gas production and the corresponding
flow pressure must be measured
Year, month, day
Asphalt content
Sulfur content
Year, month, day
Prepared by:
SY/T5387—2000
Table A6×× oil reservoir×× test well area gas analysis results table Laboratory
Overview layer Overview sample Laboratory C| |tt||Date Date
Preparer:
Reviewer:
Preparation Date:
X×Oil Reservoir××Test Production Well Area Formation Water Analysis Results Table CL
Reviewer:
Preparation Date:
Year Month Day
Year Month Day
Trace Elements
SY/r5387--2000
Table A8××Oil× ×Test production and high pressure physical property analysis results table Formation flowing oil
Well olive sample Room sample Test sample
Lili Le
Location Date Date
Preparer
Reviewer
Oil-gas ratio
Original formation viscosity
ml'a*s
Preparation date:
m/(MPa*m)
Year Month Day) Formation temperature and flow temperature and their gradient change curves; d) Pressure drop curve and pressure recovery curve;
e) System well test data and indication curve;
1) Analysis data of shale, gas and water samples;
g) High-pressure physical property sampling and analysis data.
7.2 Parameter calculation and determination method
7.2.1 Calculate the oil production index of the test well according to the relevant formula in SY/T6287. 7.2.2 Determine the original formation pressure and pressure system according to the method specified in SY/T6365. 7.2.3 Determine the oil-gas and oil-water interfaces according to the method specified in SY/T6313.1. 7.2.4 Calculate the natural energy of the reservoir according to the method specified in SY/T6167, and evaluate it according to its evaluation indicators. 7.2.5 Obtain the following according to the method specified in SY/T6172: productivity coefficient, skin coefficient, pressure conductivity, combined storage coefficient, detection radius, effective well radius, boundary distance, geological reserves, pore volume connected to the combined tube, oil leakage area, vertical fracture length, vertical self-fracture braid conductivity, etc.
7.3 Prepare the test production report
7.3.1 Contents of preparation
The text part of the report should include the following contents. a) Purpose and tasks of the test production;
b) Geological overview of the test production well area;
c) Test production history;
d) Test production analysis and conclusions;
e) Opinions on oilfield development and next steps. 7.3.2 Main drawings
The following main drawings should be attached to the report.
a) Well location and geological comprehensive map of the test well area; b) Comprehensive test production curve of the test well area;
c) Current mining situation map of the test well area;
d) Liquid production profile;
c) Test production curve of each single well:
f) Indicator curve;
g) Basic map of various well testing methods.
7.3.3 Main appendixes
The following main appendixes should be attached to the report.
a) Single test production data table;
b) Comprehensive test production data table of the test well area;
c) Test and test data table;
d) Oil, gas and water analysis data table;
e) High-pressure physical property analysis data sheet.
The formats of each table are shown in Appendix A (Suggested Appendix) Period
Test production table formats are shown in Table A1-Table A8
Formulator:
SY7T 5387—2000
Appendix A
(Suggested Appendix)
Test production table format
×× oil reservoir ×× and test production data table
Open well, close well, open well!
Reviewer
Formulator:
Formulation period:
×× oil reservoir ×× and area ×× month test production comprehensive data table oil
Reviewer:
m*/dm/dm/d/m
Formulation date:
Year Month H
Cumulative, cumulative cumulative
Oil layer! Preparation
Water production) Gas production
Oil production"
Quantity! Quantity
Year Month Day
Tester:
Well shut-in time
Tester:
SY/T5387—2000
×× and stable test and test data table
Auditor:
Oil production Gas production Base water production
Test date:
Table A4×× well is unstable Well test data table Shut-in oil Shut-in casing Actual well
Cumulative shut-in
Pressure (absolute) Pressure (absolute) Bottom pressure
Well time
Reviewer:
Test date:
Year/month/day
Table A5×× oil reservoir×× test well area crude oil analysis results Surface layer
Preparer:
Reviewer:
Freezing point
Wax content
Gel content|| tt||Date of preparation:
Before shutting in the well, the stable
oil and gas production and the corresponding
flow pressure must be measured
Year, month, day
Asphalt content
Sulfur content
Year, month, day
Prepared by:
SY/T5387—2000
Table A6×× oil reservoir×× test well area gas analysis results table Laboratory
Overview layer Overview sample Laboratory C| |tt||Date Date
Preparer:
Reviewer:
Preparation Date:
X×Oil Reservoir××Test Production Well Area Formation Water Analysis Results Table CL
Reviewer:
Preparation Date:
Year Month Day
Year Month Day
Trace Elements
SY/r5387--2000
Table A8××Oil× ×Test production and high pressure physical property analysis results table Formation flowing oil
Well olive sample Room sample Test sample
Lili Le
Location Date Date
Preparer
Reviewer
Oil-gas ratio
Original formation viscosity
ml'a*s
Preparation date:
m/(MPa*m)
Year Month Day3 Main appendices
The following main appendices should be attached to the report.
a) Single and test production data table;
b) Test production comprehensive data table of test production well area;
c) Test and test data table;
d) Oil, gas and water analysis data table;
e) High-pressure physical property analysis data table.
The format of each table is shown in Appendix A (suggested appendix) Period
The format of test production table is shown in Table A1-Table A8
Preparer:
SY7T 5387—2000
Appendix A
(suggested appendix)
Test production table format
×× oil production and test production data table
Open well, close well, open well!
Reviewer
Preparer:
Preparation period:
×× oil reservoir×× and ×× district×× month trial production comprehensive data table oil
Reviewer:
m*/dm/dm/d/m
Preparation date:
Year Month H
Cumulative, cumulative cumulative
Oil layer! Preparation
Water production) Gas production
Oil production"
Quantity! Quantity
Year Month Day
Tester:
Well shut-in time
Tester:
SY/T5387—2000
×× and stable test and test data table
Auditor:
Oil production Gas production Base water production
Test date:
Table A4×× well is unstable Well test data table Shut-in oil Shut-in casing Actual well
Cumulative shut-in
Pressure (absolute) Pressure (absolute) Bottom pressure
Well time
Reviewer:
Test date:
Year/month/day
Table A5×× oil reservoir×× test well area crude oil analysis results Surface layer
Preparer:
Reviewer:
Freezing point
Wax content
Gel content|| tt||Date of preparation:
Before shutting in the well, the stable
oil and gas production and the corresponding
flow pressure must be measured
Year, month, day
Asphalt content
Sulfur content
Year, month, day
Prepared by:
SY/T5387—2000
Table A6×× oil reservoir×× test well area gas analysis results table Laboratory
Overview layer Overview sample Laboratory C| |tt||Date Date
Preparer:
Reviewer:
Preparation Date:
X×Oil Reservoir××Test Production Well Area Formation Water Analysis Results Table CL
Reviewer:
Preparation Date:
Year Month Day
Year Month Day
Trace Elements
SY/r5387--2000
Table A8××Oil× ×Test production and high pressure physical property analysis results table Formation flowing oil
Well olive sample Room sample Test sample
Lili Le
Location Date Date
Preparer
Reviewer
Oil-gas ratio
Original formation viscosity
ml'a*s
Preparation date:
m/(MPa*m)
Year Month Day3 Main appendices
The following main appendices should be attached to the report.
a) Single and test production data table;
b) Test production comprehensive data table of test production well area;
c) Test and test data table;
d) Oil, gas and water analysis data table;
e) High-pressure physical property analysis data table.
The format of each table is shown in Appendix A (suggested appendix) Period
The format of test production table is shown in Table A1-Table A8
Preparer:
SY7T 5387—2000
Appendix A
(suggested appendix)
Test production table format
×× oil production and test production data table
Open well, close well, open well!
Reviewer
Preparer:
Preparation period:
×× oil reservoir×× and ×× district×× month trial production comprehensive data table oil
Reviewer:
m*/dm/dm/d/m
Preparation date:
Year Month H
Cumulative, cumulative cumulative
Oil layer! Preparation
Water production) Gas production
Oil production"
Quantity! Quantity
Year Month Day
Tester:
Well shut-in time
Tester:
SY/T5387—2000
×× and stable test and test data table
Auditor:
Oil production Gas production Base water production
Test date:
Table A4×× well is unstable Well test data table Shut-in oil Shut-in casing Actual well
Cumulative shut-in
Pressure (absolute) Pressure (absolute) Bottom pressure
Well time
Reviewer:
Test date:
Year/month/day||
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