SY/T 10014-1998 Guidelines for the preparation of overall development plans for offshore sandstone gas fields
Some standard content:
Registration No.: 1888—1998
People's Republic of China Offshore Oil and Gas Industry Standard SY/r10014—1998
Guide to Programming Overall Development Program for Offshorc Sandstone Gas Fields1998-06—07 Issued
China National Offshore Oil Corporation
1998-10—01Implementation
SY/T 10014—1998
Policy statement
Cited by
Basic conditions for the preparation of the overall development plan for offshore sandstone gas Gas field geology and reservoir engineering
Drilling, completion and workover
Gas reservoir development project
Production operations
Safety analysis
Environmental protection
Natural gas market
Economic evaluation
Report writing requirements
SY/T10014—1998
Offshore gas field development is a huge cost and a huge systematic project. The Overall Development Plan (ODP) is a compilation of multi-disciplinary technical research results, including not only gas field geology and gas reservoir engineering, but also drilling, completion, workover, gas supply technology, gathering and transportation system engineering, safety, environmental protection and economic evaluation. This standard is mainly based on the experience of oil and gas field development at home and abroad, as well as the practice of offshore oil and gas exploration and development in my country over the years, and is written with reference to the advanced ODP reports at home and abroad and the relevant requirements of the "Outline for the Preparation of the Overall Development Plan of Offshore Oil (Gas) Fields" of the Development and Production Department of China National Offshore Oil Corporation, as well as safety, environmental protection and other standards and regulations. The purpose of writing this standard is to standardize the basic conditions, technical content and requirements of the overall development plan of offshore sandstone gas fields, optimize the plan design, reduce investment, so as to improve the quality and profit level of the overall development plan design of gas fields, rationally develop gas fields and improve economic benefits. This standard was issued on June 7, 1998 and implemented on October 1, 1998. Since 1999 All offshore sandstone gas field overall development plans submitted for approval from April 1, 2017 shall comply with the provisions of this standard. This standard was proposed and coordinated by China National Offshore Oil Corporation. This standard was drafted by China National Offshore Oil Corporation Nanhai West Company. The main drafters of this standard: Liu Guannan, Yu Hongji The chief reviewer of this standard: Lin Guanqun.
Policy Statement
Offshore oil and gas industry standard publications only address issues of a general nature. When it comes to specific situations, national and local laws and regulations should be consulted.
Offshore oil and gas industry standard publications do not undertake to provide users, manufacturers or suppliers with advance notice and training on health, safety and hazard prevention for their employees and other on-site operators, nor do they assume any responsibility for them under national and local laws and regulations. The content of any offshore oil and gas industry standard publication cannot be interpreted by implication or otherwise as granting any right to manufacture, sell or use any method, equipment or product involving patent rights, nor does it assume any responsibility for any person who infringes patent rights. Generally, offshore oil and gas industry standards At least once every five years, the review, revision, or re-certification or revocation shall be carried out. Sometimes, this review cycle may be extended by one year, but not more than two years. Therefore, the validity period of a publication shall not exceed five years from the date of publication, unless an extension of validity is authorized. The status of the publication can be found from the Secretariat of the Technical Committee for Standardization of Offshore Oil and Gas Industry (Tel. 01064610022-7875, mailing address: Standardization of Offshore Oil Production Research Center, Box 235, Beijing, zip code 101149) or the Technical Committee for Standardization of Offshore Oil and Gas Industry (Tel. 010-64665361, mailing address: Offshore Oil Science and Technology Office, 25th Floor, Dongjingxin Building, Yuanqiao, Beijing, zip code 100027).
The purpose of issuing offshore oil and gas industry standards is to promote proven and good engineering technologies and operating practices. It is not intended to eliminate the need to make correct judgments on when and where to apply these technologies and practices. The formulation and publication of offshore oil and gas industry standards are not intended to restrict anyone from adopting any other technologies and practices in any way. This standard can be used by anyone who wishes to adopt it. The Offshore Oil and Gas Industry Standardization Technical Committee and its authorized issuing units have made unremitting efforts to ensure the accuracy and reliability of the data contained therein. However, the Offshore Oil and Gas Industry Standardization Technical Committee and its authorized issuing units do not represent, guarantee or warrant the standards they publish, and hereby expressly state that the Offshore Oil and Gas Industry Standardization Technical Committee and its authorized issuing units do not assume any obligations or responsibilities for losses or damages caused by the use of these standards, for the use of standards that may conflict with any national and local regulations, and for the consequences of infringement of any patent rights caused by the use of these standards.
1 Scope
Offshore Oil and Gas Industry Standard of the People's Republic of China Guide to Programming Overall Development Programfor Offshore Sandstone Gas FieldsSY/T10014—1998
This standard specifies the basic conditions, technical contents and requirements for the preparation of the overall development plan for offshore sandstone gas fields. This standard is applicable to the preparation of the overall development plan for offshore sandstone gas fields, and can be used as a reference for other types of offshore gas fields. 2 Cited standards
The clauses contained in the following standards constitute the clauses of this standard by being cited in this standard. At the time of publication of the 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. CGBn270-87 Natural Gas Reserves Specifications
GB 3550-83
GB 491485
Emission Standards of Water Pollutants from Petroleum Development Industry Discharge Standards of Oily Wastewater from Offshore Petroleum Development Industry GB9052.1-88 Oil and Gas IV Liquefied Petroleum Gas
GB 9053-88
SY5615-93
Stable Geology
Natural Gas Geological Mapping Specifications and Diagrams
SY/T5895-93
SY/T 10011-1997
Common Quantities and Units in the Industry Exploration and Development Department
Overall Development Plan of Oil Fields
3 Guidelines for the Preparation of Overall Development Plan of Offshore Sandstone Gas Fields
Basic Conditions for Preparation
The preparation of the overall development plan of offshore sandstone gas fields is carried out on the basis of the feasibility evaluation confirming that the gas outlet has mining value. The following basic conditions should be clarified:
a) The structural morphology and fault distribution of the producing layer
b) The layer section, lithology and lithofacies,
effective thickness and porosity, permeability, saturation and other parameters of the producing layer and the distribution and properties of the interlayer;
c) The mutual
physical and chemical properties of oil, gas and water;
the basic conditions of the oil
metal pressure system and the production capacity of the gas well;
d) The pressure of oil, gas and water layers;
||e) Gas reservoir type and driving type,
f) Proven reserves have been reported to the State Reserves Commission for approval: g) Environmental conditions necessary for engineering design h) Gas pipeline route survey has been conducted) Natural gas market has been basically determined
4 Gas field geology and gas reservoir engineering
4.1 Overview
4.1.1 Geographical location
The sea area where the gas field is located, the distance to the nearest major port city and the longitude and latitude, with a geographical location map attached. Approved by China National Offshore Oil Corporation on June 7, 1998 and implemented on October 1, 1998
4.1.2 Brief description of environmental conditions
4.1.2.1 The sea where the gas field is located minus the water depth.
4.1.2.2 Tidal, tidal and ocean current conditions. 4.1.2.3 Wave frequency, wave height and wavelength
4.1.2.4 Monsoon, typhoon, tropical storm situation, 4.1.2.5 Air temperature, sea temperature and seabed temperature. 4.1.2.6 Sea ice situation,
4.1.2.7 Sea area ground development situation.
4.1.2.8 Disaster geological situation.
4.1.3 Regional geology
SY/T 10014-1998
4.1,3.1 Structural location of gas production, regional geological background. Attached is the structural location map. 4.1.3.2 Stratigraphic sequence. Attached is the stratigraphic sequence table and the data table of each layer. 4.1.3.3 Oil and gas bearing strata, source-reservoir-cap combination. Attached is the stratigraphic comprehensive columnar section. 4.1.4 Current status of exploration and evaluation
4.1.4.1 Brief information of discovery wells:
4.1.4.2 Seismic methods, workload, line density and interpretation results. Attached is a typical seismic interpretation profile. 4.1.4.3 Number of exploration and evaluation wells, coring and formation testing. Attached is a chart and table of exploration results. 4.1.4.4 Items and workload of core and reservoir fluid sample analysis and testing, high-pressure physical property test data. 4.1.4.5 Well testing and trial production. Attached is a table and curve of data of major well testing and trial production. 4.1.4.6 Statistical table of basic data of gas field exploration. 4.2 Description of geological characteristics
4.2.1 Structure
4.2.1.1 Structural morphology, trap type, closure area, closure height, and vertical variation of structure. Attached is a map of the main gas-producing structures and vertical and horizontal structural profiles.
4.2.1.2 Fault distribution and division of fault blocks. Attached is a table of fault elements. 4.2.2 Reservoirs
4.2.2.1 Basis and results of layer group division. Attached is a comparative profile of typical reservoirs. 4.2.2.2 Lithology: rock name, mineral composition, cement, cement type and degree of cementation, etc. 4.2.2.3 Structure and formation: grain size, polishing degree, sorting and bedding. Attached is a photo of grain size distribution curve, etc. 4.2.2.4 Clay content and clay mineral components and their impact on reservoirs when drilling and reforming gas layers. 4.2.2.5 Thickness and occurrence: total thickness, single layer thickness and number of layers. 4.2.2.6 Reservoir distribution: Focus on the continuity, stability and small layer drilling rate of the plane and vertical distribution of gas-bearing sand bodies in different fault blocks and different layer groups in different structural parts, with small layer distribution plane map and thickness contour map attached. 4.2.2.7 Sedimentary phase analysis, with sedimentary phase map attached. 4.2.2.8 Diagenetic epigenesis.
4.2.3 Reservoir space
4.2.3.1 Reservoir space type and combination characteristics, 4.2.3.2 Pore structure pore radius, throat radius pore-throat ratio and capillary pressure oil line characteristics, with capillary pressure two lines, capillary radius statistical map:
4.2.3.3 Porosity and distribution of each reservoir. Attached porosity distribution frequency map: such as reservoir description made by seismic method. Attached reservoir distribution, effective thickness and porosity distribution map.
4.2.3.4 Fracture distribution and characteristics
4.2.3.5 Air permeability, effective permeability and multiplied vertical permeability, with horizontal permeability and porosity logarithmic relationship diagram. 2
4.2.4 Reservoir classification evaluation
4.2.4.1 Classification standard and basis.
sY/r10014-1998
4.2.4.2 Classification evaluation results, including longitudinal and horizontal classification results. 4.2.5 Fluid distribution
4.2.5.1 Gas (including CO, N2, etc.), oil and water distribution and their controlling factors, 4.2.5.2 Gas, oil and water saturation, attached gas and oil saturation distribution chart, 4.2.5.3 Oil-gas interface, oil-water interface, depth and occurrence of gas-water interface, attached representative gas, oil and water relationship profile comparison chart 4.2.6 Fluid characteristics
4.2.6.1 Fluid (gas, oil, water) properties and characteristics, for condensate gas fields, the condensate oil content and properties should be clear, attached gas, oil and water component analysis table.
4.2.6.2 High-pressure physical properties of natural gas: compressibility, volume coefficient, viscosity, viscosity and gas deviation coefficient. Attached are the relationship charts of each parameter and pressure.
4.2.6.3 Condensate gas state: critical pressure, critical temperature, critical condensate pressure, critical condensate temperature, reverse condensate volume and characteristics, with relevant phase diagrams and underground reverse condensate curves,
4.2.7 Formation pressure and temperature system
4.2.7, 1 Formation pressure system is divided in horizontal and horizontal directions. The ground pressure, pressure coefficient and pressure gradient of each pressure system, with the relationship curve between formation pressure and altitude depth.
4.2.7.2 Gas reservoir temperature, geothermal gradient. With the relationship curve between formation temperature and altitude depth. 4.2.8 Gas reservoir type - driving type
4.2.8.1 Gas reservoir type: Determined comprehensively according to the trap type, reservoir type, gas-water distribution, pressure coefficient size and oil-gas underground volume ratio: 4.2.8.2 Original driving energy and driving type. 4.2.8.3 Water-break volume evaluation
4.3 Reserve calculation
4.3.1 Reserve classification and calculation unit
Reserves classification and calculation unit division shall be carried out according to the provisions of (I3n270). 4.3.2 Determination of reserve parameters
Determine all parameters of volumetric reserve calculation. 4.3.3 Reserve calculation
4.3.3.1 When the volumetric method is used to calculate reserves, the results shall include condensate reserves and crude oil reserves of the oil ring when there is an oil ring, and the volume of the side and bottom water bodies shall be estimated, and a table of reserve calculation results shall be attached.
4.3.3.2 When there is test production data, the dynamic reserves shall be calculated by the dynamic method with representative dynamic curves attached. 4.3.4 Reserve evaluation
4.3.4.1 The distribution of reserves in the vertical and horizontal directions and their characteristics. 4.3.4.2 Productivity, abundance, classification evaluation, burial depth Classification, 4.3.4.3 Problems and reliability in reserve calculation. 4.3.4.4 Reserves value selection in development plan design 4.4 Development plan
4.4.1 Basic principles
The general principle of gas field development plan design is to determine a reasonable development plan based on the specific characteristics of the gas field, to ensure safe, quality and stable gas supply to downstream users during the contract period, and to achieve the goals of low investment, high recovery rate and good economic benefits. 4.4.1.1 Determine a reasonable gas supply rate to ensure long-term and stable gas supply to downstream users and enable the gas field to maintain a certain peak-shaving gas supply capacity. 4.4.1.2 Fewer wells with high production to improve recovery rate. Gas fields should be laid in high structural parts with good reservoir properties. When laying wells in the wing parts, the degree of reservoir uncovering should be studied to prevent premature water production from gas.
SY/T10014—1998
4.4.1 .3 Make full use of gas reservoir energy and reduce operating costs. 4.4.1.4 Adopt safe and reliable advanced processes, equipment and new technologies to improve the production efficiency of gas fields. 4.4.1.5 Take necessary environmental protection technical measures to effectively prevent environmental pollution. 4.4.2 Division of development layers
Depending on the vertical pressure system of the production layer, oil and gas properties, reservoir physical properties, reservoir distribution and interlayer conditions, consider whether there is mutual interference during development that affects production capacity, gas supply component requirements, recovery rate and economic benefits to divide the development layers. 4.4.3 Development method
4.4.3.1 Make full use of natural energy for depletion-type exploitation. For condensate gas fields, determine whether to use depletion-type exploitation or pressure-maintaining exploitation based on the condensate oil content and reserve size.
4.4.3.2 Determine the time pressure for reasonable use of compressors. 4.4.3.3 Determine the minimum wellhead pressure force, gas well and gas field abandoned production. 4.4.4 Gas well production capacity
4.4.4.1 Comprehensive analysis of gas well production capacity. Attached is a summary table of gas well test interpretation results 4.4.4.2 Determine the open-flow rate of gas wells.
4.4.4.3 Determine the reasonable production capacity of a single well
Including the following situations:
a) For sandstone edge water gas reservoirs and fixed volume gas reservoirs with good cementation, production can be allocated according to 15%~25% of its initial open-flow rate. At the same time, it should be noted that the production of gas wells must be lower than the maximum allowable flow without erosion; for bottom water gas reservoirs, the basis is to effectively control the water cone: b) For loose sandstone reservoirs, the reasonable production capacity of gas is based on not destroying the gas layer structure and effectively controlling sand production; c) According to the test well production capacity and tubing structure, production node analysis is carried out, inflow and outflow dynamic curves are calculated, the maximum stable production is evaluated, and the minimum liquid-carrying gas production is calculated.
4.4.4.4 Production and port pressure and temperature prediction 4.4.5 Determination of tubing size
According to the vertical pipe flow calculation results, the relationship between the wellbore pressure loss (△P) and the gas production (d) under different pipe diameters (d) is selected considering the wellbore structure and the need for the later liquid carrying capacity. Attached is the AP~9d relationship diagram. 4.4.6 Reasonable gas production rate and stable production period
The determination of reasonable gas production rate should take into account national needs and market supply and demand, gas field reserves and resource replacement status, gas field geological conditions and formation water activity jump, enterprise economic benefits and Social benefits, development experience of similar gas fields at home and abroad 4.4.6.1 For the gas-driven gas reservoirs with no water or inactive edge water, the production degree of the gas field during the stable production period and the user's requirements for the stable gas supply period, determine a more reasonable gas production rate. Generally, it is about 70% of the recoverable reserves. According to 4.4.6.2 multiple gas use areas, rich resources, the gas production rate can be selected to be relatively high, such as 5% 8%. 4.4.6.3 The gas production rate for the atmosphere should be lower, generally not more than 3% 4.4.6.4 For bottom water gas reservoirs, in order to avoid premature water cone, single wells should be controlled to produce at a reasonable rate. 4.4.7 Number of production wells
The number of production wells in a gas field can be determined based on the reserves to be utilized, gas production rate, single well production and peak regulation coefficient. The calculation formula is: Wn=Qg×Kp
Wherein: Wn is the number of production wells, mouth;
Qg is the designed daily gas supply of the gas field, 10°m/d;9k is the average single well production, 10°m/d;
Kp is an additional coefficient (generally 1.1-1.3), a dimensionless quantity: The additional coefficient K should mainly consider the following points: uneven gas use;
SY/T10014—1998
Due to various geological and engineering factors, the gas utilization rate cannot reach 100%; the importance of the gas field in the gas supply system and other factors; necessary observation wells.
4.4.8 Grid layout and platform location
Well network layout includes well spacing and well network form. Attached is the development well network layout diagram and the calculation table of development well inclination parameters. 4.4.8.1 Well Spacing
Consider the heterogeneity of the gas field and the existence of faults, as well as the balanced production on the entire gas field surface. 4.4.8.2 Positioning
According to the geological structure and reservoir characteristics of the gas field, determine the favorable area for layout. Gas wells should be laid out in the high part of the structure as much as possible, and there should be a certain distance from the inner boundary of gas and water to prevent premature water breakthrough and affect the recovery rate. 4.4.8.3 Well Network Form
The well network form should be selected according to the geological structure characteristics and the connectivity of the reservoir. The number of wells with uniform or uneven layout should be adjusted.
4.4.8.4 Determination of the location and number of platforms
Appropriate space should be left in the well network deployment
It should be based on the current mature international technology and facilities, and the minimum number of platforms should be used to meet the requirements of well layout according to development needs. 4.4.9 Principles of perforation of production layers
4.4.9.1 For bottom water gas fields, a single well cone model is used for simulation or surface model analysis, and a reasonable degree of perforation is determined in combination with the experience of similar developed gas reservoirs
4.4.9.2 For edge water gas fields, the high part of the platform should be fully perforated. For the edge of the platform, a certain thickness of perforation avoidance should be left. Its size is determined by factors such as the physical properties of the section, the activity of the edge water and the designed production pressure difference. 4.4.10 Development Program Index Prediction
Numerical simulation method should be used for program index prediction4.4.10.1 Selection of mathematical model
Simulation software should be selected according to the geological characteristics, reservoir physical properties and fluid properties of the gas mountain4.4.10.2 Geological model
Should include:
Overall model
According to the geological characteristics of the gas field and the functions of the simulation software, the corresponding geological model should be established. The number of layers in the vertical direction should be able to reflect the changes in reservoir physical properties and the distribution law of oil, gas and water: In general, uneven grids can be used on the plane, with dense wells in the center and sparse wells at the edges. The overall model is used for program index calculation.
Attached is a simulation plane grid diagram.
Surface model, cone model and well group model
The characteristics of the profile model and cone model are small number of grids and short calculation time. Generally, the model is established with the actual data of the wells that have been drilled. It is suitable for quantitative analysis of parameters selected for uncertain programs and sensitivity analysis of parameters. For a condensate gas field, a well group model is selected to study the parameters of gas injection and pressure maintenance. Surface model diagram, cone model diagram and group model diagram. 4.4.10.3 Initial model parameters
Include the following contents:
a) Comprehensive geological parameters, attached gas layer top surface structural contour map, layered formation thickness contour map, layered porosity and permeability contour map; b) Capillary pressure and relative permeability data, attached curve diagram and minimum gas flow saturation and residual gas saturation data table: c) Natural gas PVT parameters, mainly gas deviation coefficient (Z) and gas viscosity (g) data under different pressures (P). Attached drawings (Z, ~P diagram);
d) Basic gas reservoir parameters, mainly including gas reservoir temperature (T), rock compression coefficient (C), formation water viscosity (p), relative density (r), volume coefficient (B), critical pressure (P), critical temperature (T) and gas relative density (r) of reservoir natural gas, etc. Attached data table. 5
4.4.10.4 Dynamic model parameters
Include the following contents:
a) Well location coordinates, well diameter:
b) Each well production, skin factor (s);
c) Perforation well section and its Kh value;
d) Each well vertical true pipe flow (VIP) calculation result table: SY/T 10014-- 1998
e) Well restriction parameters, including well pressure setting, minimum production of single well, gas waste production, etc. 4.4.10.5 Single well drill stem test (LST) test fitting. 4.4.10.6 Historical matching and understanding.
4.4.10.7 Establish simulation plan
4.4.10.8 Index prediction. Attached is the summary table of development index prediction. 4.4.11 Preliminary optimization of development schemeswwW.bzxz.Net
4.4.11.1 Analysis and comparison of technical indicators of development schemes. 4.4.11.2 Recommended development schemes. Attached are the development index tables and development curves of representative wells in the gas field. 4.4.12 Sensitivity analysis
Analyze the geological uncertainties of the recommended schemes, further demonstrate the reliability of the schemes, understand the changing rules, and propose corresponding measures. Attached are relevant charts.
Main uncertainties in geology 1 are:
a) The volume of side and bottom water;
b) The sealing of faults;
c) The connectivity between layers and the vertical permeability; d) The change of permeability of the production layer.
4.5 Implementation requirements of the scheme
4.5.1 Development procedures
4.5.1.1 Requirements for platform construction, drilling and well commissioning procedures. 4.5.1.2 Arrangement and requirements for development test: 4.5.1.3 Before drilling the development well, additional geological work and further confirmation of the well location should be done. 4.5.1.4 After drilling the development well, the reserves should be verified, and corresponding adjustment plans should be made when there are major changes. 4.5.2 Data acquisition requirements and establishment of dynamic monitoring system Data acquisition should include the following items: 4.5.2.1 Drilling and recording requirements. Including supplementary core sampling plan: 4.5.2.2
Measurement and system selection and data processing and interpretation requirements 4.5.2.3
Gas expansion and commissioning, data acquisition arrangement and requirements during the test period 4.5.2.4 Requirements for data acquisition during normal production. 4.5.3 Backup resources
4.5.3.1 Are there other gas intercepts or gas-bearing layers above and below the gas reservoir? Briefly describe the characteristics of the gas reservoir, reserves, and replacement ideas. 4.5.3.2
Whether there are gas fields and favorable structures in the adjacent structures of the gas field. Briefly describe the gas characteristics, reserves, measures to implement reserves and replacement ideas. 5 Drilling, completion and workover engineering
5.1 Drilling design
5.1.1 Basis of drilling design
5.1.1.1 The requirements for drilling in the gas reservoir engineering development plan mainly include:
SY/T10014—199a
a) Platform location and development well location and number of wells, and production sequence; b) Special requirements for drilling to achieve a certain geological purpose, such as coring, testing and special logging. 5.1.1.2 Lithological characteristics of formations in the area of combination
Briefly describe the name, lithology, thickness and top and bottom exploration depth of each formation from the seabed to the bottom of the completion drill. 5.1.2 Casing design
5.1.2.1 Briefly describe the design principles, including the safety factor used. 5.1.2.2 Casing program design
Mainly includes:
a) Nominal size, grade, wall thickness or mass (kg/m), depth and ditch depth of watertight pipe; b) Nominal size, steel grade, wall thickness or mass (kg/m), buckle type and ditch depth of surface casing; c) Nominal size, steel grade, wall thickness or mass (kg/m), buckle type and ditch depth of technical casing; d) Nominal size, steel grade, wall thickness or mass (kg/m), buckle type and ditch depth of raw casing; e) Nominal size, steel grade, wall thickness or mass (kg/m), buckle type and ditch depth of tail pipe; g/m), buckle type and lowering depth; f) tail pipe hanging depth:
name) casing and tail pipe pressure test standard;
h) drill bit procedure:
5.1.3 Directional well design
should include the following charts, and necessary text can be attached to explain: a) Directional well calculation result table including well number, bull's eye mark, inclination point, inclination rate, maximum well inclination, bottom inclination depth, bottom vertical depth, horizontal section length, etc.:
b) Schematic diagram of two-dimensional trajectory of typical directional bull;) Top view of cluster type and trajectory of well 1 platform.
5.1.4 Cementing design
5.1.4.1 Non-mechanical method for cementing casings at each layer, cement return height. 5.1.4.2 Cement slurry density (including lead slurry and tail slurry), water seepage level. 5.1.4.3 Main additive types.
5.1.5 Mud design
5.1.5.1 Mud system types in the well section, selection principles and measures for gas layer protection 5.1.5.2 Mud technical indicators: density, water loss, funnel-bucket viscosity, dynamic shear force, static shear force, solid content and solid type, etc. 5.1.5.3 Main additive types.
5.1.6 Drill tool design
5.1.6.1 Drill bit size and type,
5.1.6.2 Drill key size.
Drill pipe size and steel grade
5.1.6.4 Other drilling tool accessories name and type. 5.1.7 Drilling process technical requirements
5.1.7.1 Technical points and main measures for drilling the surface layer. 5.1.7.2 Technical points and main measures for drilling the intermediate formation. 5.1.7.3 Technical points and main measures for opening the layer: 5.1.7.4 Technical measures for handling harmful gases. 5.1.7.5 Implementation requirements of the measurement method and the series of measurement and opening requirements: 5.1.8 The diagram of the well structure should indicate the zero well depth position (sea level or the upper plane of the rotary table), the drill bit diameter and drilling depth of each well section, the casing size and the depth of each well section, the cement return height during cementing of each layer of casing and the designed depth of the artificial bottom of the well. 5.1.9 Selection of drilling rig and drilling method and other requirements 5.1.9.1 Selection of drilling rig can be selected from platform drilling rig blocks, self-elevating cantilever drilling platforms, semi-submersible drilling platforms, floating drilling platforms, platform drilling and repair combined equipment according to actual needs and possibilities. 5.1.9.2 Drilling method can be selected from platform top drilling, jacket drilling, tie-back drilling and side drilling according to actual needs and possibilities. 5.1.9.3 Wellhead equipment
Casing head and casing spool sizes, pressure ratings, BOP combination, drift size and pressure ratings. 5.1.9.4 Others
Drill stem test (DST), repeated formation test (RFT), high pressure physical property sampling, coring, special testing and other special requirements. 5.1.10 Drilling schedule
5.1.10.1 The process time should be divided according to the average single well preparation time, drilling time and cementing time of each well section, logging time, wellhead installation time and other necessary arrangements.
5.1.10.2 Arrange the time for mobilization and demobilization, and the number of mobilization and demobilization. 5.1.10.3 Tie-back time.
5.1.10.4 Time for installing the underwater base plate
5 Unforeseen time
5.1.10.6 The average single well time is calculated by summing up the above time. 5.1.11 Drilling and well cost estimation
A drilling cost estimation table should be prepared. Including: mobilization and demobilization costs, drilling and well engineering costs (including major daily sub-item costs), drilling material costs (including major material sub-item costs), indirect costs (such as management fees, design fees, supervision fees, insurance premiums) and unforeseen costs. 5.2 Completion process design
5.2.1 Completion method selection and basis
5.2.1.1 Select one or more of the following methods: a) Open hole completion:
b) Liner completion, liner size and depth; c) Slotted pipe completion, slot width and slot shape; d) Perforation completion.
5.2.1.2 If perforation is used to open the gas layer, the following should be made clear: a) The perforation section and layer:
b) Whether the perforation method is tubing-transmitted perforation (TCP), cable method or through-the-tubing perforation (TTP); c) Perforation parameters, including hole density, hole diameter and penetration depth (API cement target or Bailey sandstone target), drug properties, and negative pressure value. 5.2.2 Sand control design
5.2.2.1 Sand control methods and their selection basis. 5.2.2.2 Design requirements for sand control
There should be corresponding design requirements for the selected sand control method, for example: a) Gravel pack sand control should include:
1) Median value of formation sand ds and unevenness of formation sand dg/dsn; 2) Gravel mesh size (U.S. mesh) and quality: 3) Screen gap and size;
4) Schematic diagram of the open pipe string after gravel packing:
5) Properties of the filling sand-carrying fluid.
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