SY/T 5594-1993 Method for compiling development planning for water-flooded sandstone oilfields
Some standard content:
Petroleum and Natural Gas Industry Standard of the People's Republic of China SY/T5594--93
Method for Preparation of Development Plan for Water-Driven Sandstone Oilfields 1993-03-27 Issued
Ministry of Energy of the People's Republic of China
Implementation on 1993-09-01
1 Topic Content and Applicable Scope
Petroleum and Natural Gas Industry Standard of the People's Republic of China Method for Preparation of Development Plan for Water-Driven Sandstone Oilfields This standard specifies the method, content and requirements for the preparation of development plan for water-drive sandstone oilfields. SY/T 5594-93
This standard is applicable to the preparation of development plan for large and medium-sized water-drive sandstone oilfields. For small oilfields, complex fault block oilfields and other types of sandstone oilfields, the content can be increased or decreased according to the specific situation. 2 Reference standards
GBn269 Petroleum reserve specification
GBn270 Natural gas reserve specification
SY5155 Common parameter symbols and measurement units for oil and gas reservoir engineeringSY 5154 Recommended practice for oil and gas fluid samplingSY5336 Recommended practice for conventional core analysis
SY5367 Method for calibration of recoverable reserves of oil mountain
3 Determination of development planning objectives
3.1 Determined according to the national requirements and technical policies for crude oil production. 3.2 Determined according to the underground resource status of the oil field, development and mining technology, objective production laws and economic benefits. 4 Analysis of oil field development status
4.1 Overview of oil fields
4.1.1 Overview of the geographical location, traffic conditions, climate, water sources and economic conditions of the oil field, ground altitude, oil layer burial depth and oil-bearing strata of the oil field.
4.1.2 Explain the time when the oilfield was put into development, the exploitation layer, the F-production method, the layer division, the well network density, the water injection method, the capacity construction situation, and the adjustment of the layer and well network. Correctly count the total number of oil and water wells before the completion of the project, the number of wells opened, the daily oil production, the daily liquid production, the daily water injection, the formation pressure, the oil recovery index, the water absorption index, the comprehensive water content, the oil recovery rate and the degree of recovery, the oil recovery rate and the degree of recovery calculated according to the recoverable reserves, the oil recovery rate of the remaining recoverable reserves, the cumulative oil recovery, the flood water recovery, the cumulative water injection and other indicators. 4.2 Inspection of the implementation of the oilfield development plan
4.2.1 The inspection of the completion of the crude oil production task includes the production of old wells that have not taken measures, the increase in oil production from fracturing, pumping, electric pumping, pumping well replacement and pumping well replacement, the increase in oil production from new wells, and the production of the entire area. 4.2.2 The inspection contents of the implementation of the production increase measures include the number of drilled oil and water wells, the number of basic oil and water wells and the completed production capacity, the number of self-flowing wells converted to pumping, the number of wells with electric pumps, the number of oil and fracturing, and the number of pumping wells with pump changes. 4.2.3 The inspection contents of various development indicators include oilfield liquid production, water injection plate, water content, water content increase rate, production base decline rate, reserve-production ratio, and the increase in available reserves after the new wells are put into production, single well production capacity, water content, and single well production increase effect after measures are taken for old wells. Approved by the Ministry of Energy of the People's Republic of China on March 27, 1993 and implemented on September 1, 1993
4.3 Evaluation of development effect
SY/T 5594—93
4.,3,1 Analyze and evaluate the adaptability of oilfield development volume and injection and production pressure system. 4,3,2 Analyze and evaluate the grid connection adaptability of various pumping layers in the oilfield and the degree of water drive storage and dispersion control. 4.3.3 Analyze and evaluate the volume of water injection and water injection utilization rate of the oil field. 4,3,4 Analyze and evaluate the oil field liquid production rate, oil production rate and remaining recoverable reserves oil production rate. 4.3,5 Analyze and evaluate the water content rise rate and recovery degree of the oil field. 4.3.6 Summarize the experience gained in the implementation process and the evaluation of the development effect and the re-understanding of the underground situation, and find out the existing problems. 5 Description of geological characteristics of oil nests
5.1 Structure
5.1.1 Describe the structural type, shape, dip, combined height, closure area, and closure conditions. 5,1.2 Describe the nature, number, distribution status, sealing degree, and fault elements of the fault. 5.2 Reservoir development
5.2.1 Summarize the rock properties of the oil layer, the division of the oil layer, the thickness and distribution of the interlayer. 5.2.2 Describe the occurrence of the oil layer, including the total effective thickness of the oil layer, the effective thickness of a single layer, the number of layers, and the distribution status. 5.2.3 Sedimentary phase analysis, including sedimentary type, sand body morphology, and sand body distribution. 5.2.4 Describe the physical properties of the oil layer, including oil layer porosity, permeability, oil saturation, relative permeability, rock wettability, microstructure, capillary pressure, and water flooding efficiency. For experimental methods, see SY5154*SY5336. 5.3 Fluid properties
5.3.1 Crude oil properties, describing the density, viscosity, freezing point, and wax content of ground crude oil. Sulfur content, colloidal glycoside content, and pVT properties of formation crude oil.
6.3,2 Natural gas properties, mainly describing its relative density, components, and condensate content. 5.3,3 Formation water properties, mainly describing water type and mineralization. 5.4 Oil, gas, and water distribution
Mainly including the gas-gas interface, oil-water interface, oil-gas-water distribution control factors, distribution type, gas cap, pure oil area, and transition zone area of dividing blocks and stratified systems.
5,5 Oil film type and driving mode
5.5.1 Determine the reservoir type.
5,5.2 Calculate the natural energy and determine the driving type. 5.5.3 Explain the oil layer pressure system, original formation pressure, formation temperature and geothermal gradient. 5,6 Reserves calculation
According to GBm269, GBn270, SY5367, and approved by the State Reserves Committee, determine the geological reserves and recoverable reserves of oil and natural gas to be mobilized.
6 Oilfield reserve utilization status and potential analysis
6.1 Analysis of oil layer reserve utilization status
6.1.1 Statistical analysis of oil and layer thickness, liquid production, liquid production intensity and water content and other stratified production status. Statistical analysis of stratified water injection status such as layer water absorption thickness, water injection volume and water injection intensity of water injection wells. 6.1.2 Statistical analysis of the thickness distribution of oil layers with no oil production and poor production. Statistics of unproduced and poorly produced reserves. 6.1.3 By checking well data, statistics of water-seeing layer thickness, water section thickness and oil recovery efficiency of different types of oil layers are made, and the production status of oil layer reserves is analyzed.
6,2 Analysis of oil layer development potential
SY/T 5584-93
6.2.1 Based on the analysis of oil field oil layer reserve production status and the evaluation results of oil field development effect, potential areas and adjustment objects are proposed, and economically reasonable grid density analysis is conducted on oil adjustment areas and strata, and the increased oil and water numbers, production capacity and recoverable reserves after adjustment are calculated and analyzed.
6,2,2 Based on the inspection results of the implementation of the plan, the potential for increasing production by fracturing, pumping, electric pumping, mechanical production and pump replacement in oil field wells is analyzed, and the feasible numbers of various measures, production increase effect and economic benefit evaluation are calculated and analyzed. 7 Development planning preparation
7.1 Determine the reduction principle and technical limit
7.1.1 According to the development stage of the oil field, the existing production potential and process technology conditions, the adjustment principle of the oil field well network, stratum division, water injection method and production method is proposed.
.1.2 According to the development stage of the oil field and the actual production situation, based on the development mechanism of the oil field, the comprehensive water content, water content increase rate, production decline rate, remaining recoverable reserves oil production rate, water injection pressure, formation pressure, flow pressure, maximum liquid production, liquid production rate, injection-production ratio and injection-production ratio are analyzed to determine the technical limit of the body.
7.2 Development index prediction content
7.2.1 Annual production of Shantian, annual water injection, annual liquid production, annual average water content, water content at the end of the year, water content increase rate. 7.2.2 Oil and fruit liquid and oil production index, formation pressure, flow pressure, water well injection pressure and water absorption index. 7.3 Prediction methods for development indicators that have been put into production and are commonly used 7.3.1 Production determination method based on water drive characteristic curve
This method establishes the water drive characteristic curve of the oil field. Given the annual liquid production QLt of the oil field, the annual oil production of the oil mountain can be obtained. The formula is:
+1g( 1+.24 yuan Q±-
In the formula: Q.—Annual oil production of the oil field at time t, 10*t/a: QL—Annual liquid production at the oil pressure moment, 10*t/as ZQt-1~———The flood water production of the oil field at time t-1, 10*m, F—The slope of the oil-water drive characteristic curve.
7.3.2 Oil production index method
(1)
This method is based on the oil well production index, bottom hole flowing pressure, water content upper The three basic relationships between the rate of increase and the change of water content are used to obtain the oil production rate of the whole area. The solution formula is:
t.Mer-Ji(f)
Where: 1. Annual oil production rate of the oil field at the time, f; t—-production time of an oil well, ds
M. t—number of oil wells at the time of the oil field, mouth,
N—-geological reserves of the oil field,
f=-1——water content at the end of the year of the oil field at the time of 11, fBwuot.
B→--—Annual water content increase rate of the oil field at time t, dimensionless P+-1—Almost average formation pressure of the oil field at time t-1, MPa4P1—Average formation pressure increment of the oil field at time t, MPa.(PrI\1+aPr+--Pw+(f-+)I**.- (2)J(f,)-Change value of the production index of the oil field at time with water content, m*/(MPa·d)SY/T $$84--$6
P(f) The value of the oil field flow pressure changing with water content, MPa. 7,,3 Production volume balance
This method is based on the relationship between the oil and water index and the water content and pressure change, the relationship between the water injection well ice index, the water content rise rate and the water content change, to establish the balance relationship between the oil well production volume and the water injection volume, and to predict the production at a constant liquid or constant pressure. The injection volume balance formula is:
M-.Iwt(PI-ft-Prt)-IPR.M.:
B.JI(PrIP-)(If-,)
+JLr(PrI-Pw+t)fu+
The number of water wells and the number of oil wells at the time of oil use, where Mwt. Mt
PjwFt—water injection and bottom flow pressure of a field at time t, MPaPrt—oil and formation pressure of an oil field at time t, MPaPwtt\
—oil well flow pressure at time t, MPatft
—annual average water content of an oil field at time t, f1
—water injection and quasi-absorption index of an oil field, m\/(MPa·d)Jr—oil and liquid production index of an oil field, t/(MPad)B. Crude oil volume coefficient, dimensionless;
—relative density of crude oil, dimensionless quantity:
—oil Field injection-production ratio, dimensionless quantity.
7.3.4 Decline Curve Method
·（3）
This method is derived from the decline rate differential equation of the decline rate of oil field production after the decline of oil field production. The hyperbolic, exponential and harmonic decline formulas of its production over time are: Q. .-Q. (1+nD,t)-（Hyperbolic)..
（Exponential）
Q. -Q. (1+D:)-1（Harmonic).
Where; D;-initial decline rate of oil or oil well, 1/aQ.i||t t||The production of an oil field when it starts to decline, 10*t/aQ. tThe production of an oil field at a certain moment, 10'ta
Decline index
Development time, a.
7.3,5 Numerical fitting method for oil field
According to the geological conditions of the oil field, a mathematical model is established to perform dynamic historical fitting and prediction. 7.4 Prediction method for development index of new area and new merger and old area whole well 7,4.1 According to the development plan of the new area and the adjustment plan of the old area, the development index of the new area and the port area adjustment well is determined. 了,4,2, when there is no adjustment plan, the development index of the new area and the port area adjustment well can be determined according to the production area. Adjust the well production and water content changes to predict. 7.6 Development planning scheme design
7.5.1 Planning scheme design principles:
a. The planning indicators of oil production and new production capacity of oil wells must meet the requirements of national plans and technical and economic conditions and benefits. b. The deployment of oil field development work must leave a proper amount of room: (4)
c. The work arrangements of various measures should be based on the development plan or planning plan and be adapted to the oil field construction capacity and technical development. d. The various measures required to be taken by the planning indicators should be reasonably matched to implement the plan!
$YT 94—$
e. Different schemes should be optimized and the best one should be adopted. The planning of each stage should be reasonably connected to prepare conditions for the concurrent work of the next stage. .5.2 Develop at least three different crude oil production levels for selection. 7.5.3 For each design planning scheme, make specific arrangements for the areas and numbers of merging, the areas and numbers of capacity construction, as well as the number of wells for fracturing, pumping, electric pumping, and replacement of old wells, and calculate the increased oil and water production, determine the production structure of the planning scheme, and compare the measures and increased production of different planning schemes. 7.6 Calculation of development indicators and economic indicators of planning schemes 7.6.1 Calculate the development indicators such as annual oil production, annual water production, annual liquid production, annual water injection, oil (liquid) production rate, production degree, water content, remaining recoverable reserve oil production rate, natural (comprehensive) decline rate of the production plate in the whole area, stage water content increase rate, and accumulated oil production plate of different planning schemes.
76.2 Calculate the economic indicators such as total investment, total output value, total production cost, marginal cost of crude oil, comprehensive cost of crude oil, and total tax and profit income of different planning schemes.
7.6,3 According to the comparative analysis of various development indicators and economic indicators of different planning schemes, determine the recommended scheme. 7,7 Feasibility study of development planning scheme
7.7.1 Explain the reliability of the geological reserves, recoverable reserves and the newly added recoverable reserves after various measures during the planning period. 7.7.2 Discuss in detail the implementation degree of the increased production of oil well fracturing, pumping, electric pumping, type change, layer grid connection adjustment, etc. proposed in the planning scheme.
7.73 Carry out various production increase measures and economic boundary analysis such as shaft fracturing, pumping, electric pumping, type change, water plugging, acidification, etc., determine the economically reasonable well network density, and analyze the relationship between crude oil price and cost, oil field investment, and the trend of crude oil cost with the increase of oil field water content, so as to discuss the economic rationality of the planning scheme. 7.74 According to the needs of the planning scheme, oil wells are tested, drilled and cemented. Analyze the completion technology, as well as thin oil layer logging, water flooding layer interpretation, plugging and repairing, oil layer fracturing and plugging, and discuss their implementation degree. 7.7.5 Analyze the construction conditions such as drilling, downhole operations, oil construction, water supply, and crude oil export, and discuss the feasibility of implementing the planning scheme.
7.7.6 Analyze the growth trend of crude oil costs, as well as the country's investment and funding sources in detail, and discuss the feasibility of the actual planning scheme.
7.8 Requirements for the implementation of the development plan
7.8.1 After the development plan is determined, the person in charge of production in the oil field should make overall arrangements and organize its implementation. 7.8.2 The oil field should organize human and material resources to carry out construction according to the planning plan. 7.8,3 According to the requirements of the planning plan, do a good job in new processes and new technologies to ensure the smooth implementation of the planning plan. 7,8.4 Carefully check the implementation of the planning plan, carefully analyze the problems that arise, and adjust the planning plan deployment in a timely manner. 7, 8.5 Put forward the problems and suggestions in the planning scheme. 8 Development planning report writing format
8.1 Contents and requirements of development planning report writing 8.1.1 Contents of development planning report:
a. Introduction
b. Description of reservoir geological characteristics,
c. Current status of oilfield development:
d. Implementation of the previous stage of oilfield planning:
e. Planning ear mark and compilation principles;
f. Comparison, optimization and development planning deployment of planning schemes. 5
SY/T 5594—95
8.1.2 Requirements for report writing The information should be complete, accurate and reliable, the chart data should be consistent with the text content, and the report text should be fluent. 8.2 Attachments and appendices to the development planning report
8,2,1 Main attachments:
a, comprehensive geological map of the oil field
b, current status map of the oil field development:
c: oil field development planning deployment map
d. Oil field production composition map;
e: oil field production curve;
f. Oil field reserve-production relationship change map.
8.2.2 AppendixbzxZ.net
a. Table 1
b, Table 2
c. Table 3
Annual increase in production
Comprehensive measures table for old wells in oil fields,
Workload table for drilling, infrastructure and production in oil fields, Oil field production composition table;
Calculation results table of single field development indicators.
Subtotal of old and new wells
Prepared by
Comprehensive measures for old wells in Zibo
Replace pump and change type
Hangzhou type machine
Auditor
Table 2 Workload of drilling, infrastructure and production in oil fields
Prepared by
Capacity construction
Number of infrastructure and new wells
Injection wells
Construction or capacity
Auditor
Injection wells
Example
Table date
New wells put into production
Subtotal of "Injection wells"
Table date
Annual production
Time, a
Annual production of liquid
Additional instructions:
SY/T 5594--93
Table 3 Oilfield production structure table
Annual production
Oil production of old wells
Measures to increase production
Oil and fracturing oil production
Prediction
Pump change, type change, parameter adjustment"
Compiler
Annual oil production
Compiler
Auditor
Oilfield development index calculation results table
Annual water content
Rise rate
Oil production speed,
Auditor
This standard is proposed and managed by the Oil and Gas Field Development Professional Standardization Committee. This standard is drafted by the Exploration and Development Research Institute of Daqing Petroleum Administration Bureau. The drafters of this standard are Ren Yulin and Chen Luhan. New
Production process changes,§
Annual decline rate
Date of preparation
Annual water injection
Remaining
Geological reservesRecoverable reserves
Recoverable reserves
Date of preparation
Annual injection-production ratio
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