SY/T 6512-2000 Technical requirements for preparation of feasibility plan for tertiary oil recovery - Chemical flooding part
Some standard content:
IcS 75. 180.99
Registration No.: 8212-21H01
Petroleum and Natural Gas Industry Standard of the People's Republic of China SY/T 6512-2000
Technical requirements for drawing up a feasible EOR projectchemical flooding
2000~12-25 Issued
State Administration of Petroleum and Chemical Industry
2001 06 01 Implementation
SY/T6512-2000
Cited Standards
3 Technical contents and requirements for drawing up a feasible plan 4 Writing of a feasibility plan report
SY/T 6512—2MHO
The tertiary oil recovery technology in my country has developed rapidly. After the "Eighth Five-Year Plan" and "Ninth Five-Year Plan" scientific and technological research, the tertiary oil recovery technology has made new breakthroughs: the compound flooding technology has entered the stage of large-scale industrial application, and is an important technical measure to improve the daily recovery rate of the pool. In order to meet the development of tertiary oil recovery technology and the requirements for the preparation of tertiary oil recovery development plans, this standard is specially formulated. This standard is formulated based on a large number of chemical flooding field test research plans and indoor related research data in my country. This standard was proposed by China National Petroleum Corporation and is under the jurisdiction of the Oil and Gas Development Professional Standardization Committee. The drafting unit of this standard: Daqing Oilfield Co., Ltd. Exploration and Development Research Institute, the main drafter of this standard is Hao Yuexing
Technical requirements for drawing up a feasible KOK project chemical flooding
This standard specifies the content and technical requirements for the preparation of a feasible KOK project chemical flooding feasibility plan for clastic reservoirs. SY/T,6512—2000
This standard is applicable to the preparation of feasibility plans for improving oil recovery by chemical flooding methods (surfactant flooding, polymer flooding, alkali flooding, ASP flooding, ternary composite flooding) in water-flooding oil fields. 2 Referenced standards
The provisions contained in the following standards constitute the provisions of this standard through reference in this standard. When this standard is published, the versions shown are valid. All standards will be revised, and all parties using this standard shall discuss the possibility of using the latest versions of the following standards. SY/T5367—1998 Calculation method of daily recoverable reserves of oil SY/I'5579—2000 Detailed description method of clastic oil and gas reservoirs 3 Technical contents and requirements for preparation of feasibility plan 3.1 Reservoir description
3.1.1 Overview
Overview of the geographical location of the oil field or block, reservoir structural morphology, reservoir closure type and distribution range, fault distribution, mining strata, geological reserves and recoverable reserves of oil and gas,
3.1.2 Detailed sedimentary facies study
Follow the provisions of 6.1--6.3 in SY/T5579—2000. 3.1.3 Reservoir physical properties
According to the provisions of 7.[~7.11 in SY/T5579-2000 3.1.4 Reservoir heterogeneity
According to the provisions of 8.1~8.3 in SY/T5579-2000 3.1.5 Reservoir pore structure
According to the provisions of 9.1~9.3 in SY/5579-2000 3.1.6 Fluid properties
3.1.6.1 Describe the density, viscosity, acid value, freezing point, flash point, wax content, sulfur content, total distillation, saturated hydrocarbons, aromatic hydrocarbons, non-hydrocarbons, green quality and IV\I parameters of ground crude oil; study the rheological properties of crude oil. 3.1.6.2 Describe the relative density, components and content of natural gas. 3.1.6.3 Describe the water type, hardness, pH value, mineralization, water quality composition and content, dissolved oxygen and bacteria content of formation water, injection water and produced water.
3.2 Analysis of water drive development status
3.2.1 Basic situation of the block
Approved by the State Administration of Petroleum and Chemical Industry on 20H)-12-25, implemented on 2001-06-01
SY/T 6512-2000
Describe the time when the block was put into development, a brief history of development, the current development layer division, well network type, injection and production well spacing, production layer, production method, and non-underground technical status.
3.2.2 Analysis of current mining situation
3.2.2,1 Injection capacitywwW.bzxz.Net
Analyze the injection pressure, injection ratio, water absorption intensity, water absorption index and their changing rules of single wells and blocks; study the water absorption surface of oil layers, stratified water absorption capacity and its changing rules. 3.2.2.2 Liquid production capacity
Analyze the daily liquid production, H oil production, cumulative liquid production, cumulative oil production, water content and its changes, formation pressure, and flow pressure of single wells and blocks; stratified production, water content and pressure conditions; liquid production intensity and liquid production index, oil production intensity and production index, liquid production profile, stratified liquid production capacity and its changes.
3.2.2.3 Connectivity between injection and production wells
Use down-disturbance test lift, bay tracer technology, formation testing and production dynamic data to analyze the connectivity between bays, fluid movement rules, swept volume and oil layer heterogeneity. 3.2.2.4 Distribution of Remaining Oil
Use the interpretation data of water-flooded layers in new wells, core analysis data of closed coring inspection, production test data and numerical simulation methods to study and analyze the water-flooding status of oil layers and the distribution of remaining oil: clarify the characteristics of water-flooding in oil layers, the causes and types of remaining oil, and make vertical and horizontal water-flooding status and remaining oil distribution maps of oil layers. 3.2.2.5 Water-flooding Recovery
Evaluate the water-flooding recovery rate according to the provisions of SY/5367. 3.3 Screening and Effect Evaluation of Chemical Flooding Methods
3.3.1 Preliminary Screening of Chemical Flooding Methods
Compare the main reservoir parameters of a specific area with the screening criteria for improving oilfield recovery methods, and preliminarily determine which method can meet the screening criteria as the chemical flooding method suitable for the block. When screening chemical flooding methods, the genesis and existence form of residual oil should also be considered to determine the most suitable chemical flooding method:
3.3.2 Effect prediction
3.3.2.1 Use the recovery prediction model to predict the oil recovery effect of the selected chemical flooding method. 3.3.2.2 Establish a geological model according to the following requirements: a) The geological model should be simulated to the small layer;
b) Input oil layer depth, effective thickness, porosity, permeability, bound water saturation, residual oil saturation, oil-water relative permeability curve:
c) Input grid area, injection and production speed, injection number, injection oil segment plug composition, characteristic parameters and dosage! 3.3.2.3 Carry out water flooding history fitting: mainly fit the recovery degree and comprehensive water content under the corresponding mining years, and obtain the initial conditions for using chemical flooding methods. Parameter adjustment should follow the following requirements: a) The adjustment of oil layer porosity, permeability and oil-water saturation should be in line with geological characteristics; b! The adjusted relative permeability curve cannot change the original basic characteristics: c) The adjustment range of the permeability variation coefficient is less than 0.1: 3.3.2.4 The water drive effect is predicted based on the water drive history fitting, and the predicted final water drive recovery rate should be consistent with the calibration value. 3.3.2.5 The effect of chemical drive method is predicted based on the water drive history, and the production indicators at 95% and 98% of comprehensive water cut are compared with the water drive prediction results. The main indicators are: a) total increased oil production, stage increased oil production; b) increased recovery rate;
c) water consumption per ton of oil;
d) chemical agent utilization rate (chemical agent cost required for increased production of ton of oil); 2
e) stage oil production rate.
3.3.3 Economic feasibility evaluation
SY/T 6512-2000
3.3.3.1 Input parameters for economic evaluation: including prices of various chemicals and oil and gas, production costs, investment, taxation, depreciation, 3.3.3.2 Use economic evaluation software and adopt H increment analysis method to conduct economic evaluation on chemical flooding effect. Analyze the sales revenue of the part of oil production (including gas production) increased by chemical flooding project compared with water flooding project, and the investment and cost that need to be increased. Calculate and analyze its incremental benefits and incremental evaluation indicators.
3.3.3.3 The main indicators of economic feasibility evaluation are as follows: a) After-tax financial internal rate of return is greater than 12% for feasibility; b) After-tax financial net present value is greater than zero for feasibility; c) After-tax investment payback period is less than 6 years for feasibility 3.4 Optimal Chemical Flooding Method
Based on the above technical evaluation and economic evaluation results, combined with the current process technology and raw material sources, a comprehensive analysis is conducted to select the method with good mining indicators, great oil increase potential and high economic benefits as the best chemical flooding method, and use it for field tests. 4 Feasibility report writing
4.1 Report text content
4.1.1 Overview.
4.1.2 Reservoir description.
4.1.3 Analysis of water flooding development status.
4.1.4 Screening of chemical flooding methods and effect evaluation. 4.1.5 Economic feasibility evaluation,
4.1.6 Determination of the most common chemical flooding method
4.1.7 Suggestions for the next step of work,
4.2 Main drawings in the report
The main drawings should include:
a) Structural well location map;
b) Related drawings of Shantou-Tibet description;
c) Related drawings of water flooding development status:
d) Related drawings of chemical flooding effect prediction;
e) Economic evaluation sensitivity analysis map.
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