SY/T 10022.2-2000 Offshore oil cementing design specification Part 2: Cementing technology
Some standard content:
ICS75.020
Registration No.: 6951—2000
Offshore oil and gas industry standard of the People's Republic of ChinaSY/T10022.2—2000
Offshore oil cementing design specification
Part 2: Cementing technology
Sepcification for Cementing Design of Offshore oil wellUnit 2: Design of Cementing Technique2000 - 04- 10 Issued
State Administration of Petroleum and Chemical Industry
200010-01 Implementation
SY/T 10022.22000
Policy statement
2 References
3 Definitions and derivation symbols
4 Basis for cementing technology design
Zhou Jing. "\Technical design principles
6 Casing stop placement spacing design
7 Balanced pressure cementing design
8 Flushing wave and spacer fluid design
9 Cement slurry additional amount design
10 Technology design for improving cement slurry displacement efficiency A (Appendix to the standard) Casing stop specification Appendix (Appendix to the standard)||t t||Calculation method of eccentric cavitation rheology
SY/T1C022.2—2000
This standard is specially formulated to meet the characteristics of offshore oil drilling, improve the quality of cementing, and standardize the cementing slurry design. This standard partially integrates SY/T5.374—91 "Use of pre-liquid for oil and gas injection cementing", SY/T5480-92 "Calculation of cementing rheology" and SY/T5334:1996 "Calculation method of installation spacing of pipe centralizers". It is also combined with many years of experience in offshore oil consolidation operations and the latest research results in the industry, and is comprehensively compiled. This standard was issued on April 10, 2000 and will be implemented from October 1, 2000. Appendix A and Appendix B of this standard are both appendices of the standard. This standard was proposed and managed by China National Offshore Oil Corporation: Drafting unit of this standard: China National Offshore Oil Corporation Technical Service Company The person who drafted this standard: Li Banghe, Chief Reviewer of this standard: Tan Shuren: SY/T10022.2—2000 Policy Statement Offshore oil and gas industry standard publications are only for general issues. Involving specific National and local laws and regulations should be consulted when necessary.
Offshore oil and gas industry standards publications do not assume any responsibility for users, manufacturers or suppliers to provide advance notice and training on health, safety and hazard prevention for their employees and other field workers, nor do they assume any responsibility under national and local regulations. The contents of any offshore oil and gas industry standards publication shall not be construed, by implication or otherwise, as granting any right to manufacture, sell or use any method, apparatus or product covered by a patent, nor as incurring any liability for any infringement of a patent. Generally, offshore oil and gas industry standards are reviewed, revised, re-approved or revoked at least every five years. Sometimes, this review period may be extended by one year, but not more than two years. Therefore, the publication shall be valid for no more than five years from the date of publication unless an extension of validity is authorized. The status of publications can be obtained from the Secretariat of the Offshore Oil and Gas Industry Standardization Technical Committee (Tel. 010-84522162, mailing address: Standardization Office, Offshore Oil Production Research Center, Box 235, Beijing, 101149) or the Offshore Oil and Gas Industry Standardization Technical Committee
(Tel. 010-64665361, mailing address: Science and Technology Office, Offshore Oil Corporation, 25th Floor, Dongjingxin Building, Sanyuanqiao, Beijing, 100027).
Offshore oil and gas industry standards are issued to promote proven, good engineering techniques and operating practices. It is not intended to eliminate the need to make correct judgments on when and where to apply these techniques and practices. The formulation and publication of offshore oil and gas industry standards are not intended to restrict anyone from adopting any other techniques and practices in any way. This standard is available for use by anyone who wishes to adopt it. The Offshore Oil and Gas Industry Standardization Technical Committee and its authorized publication of standards guarantee the accuracy and reliability of the data contained therein. However, the Offshore Oil and Gas Industry Standardization Technical Committee has made every effort to ensure that the Committee and its authorized issuing units do not represent, guarantee or warrant the standards it publishes, and hereby clearly declare that the Offshore Oil and Gas Industry Standardization Technical Committee and its authorized issuing units will not bear any obligations and 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 the use of these standards.
People's Republic of China Offshore Oil and Gas Industry Standard Offshore Oil Cementing Design Specification
Part 2: Cementing Technology
Specification for Cementing Design of Offshore oil wellUnit 2: Design of Cementing Technique1 Scope
This standard specifies the basic principles and technical requirements for offshore oil cementing technology design: This standard is applicable to offshore oil and natural gas well cementing and repair operations: 2 Referenced standards
SY/T 10022.2—2000
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 the parties using this standard should explore the possibility of using the latest versions of the following standards. SY/T5374-91 Oil and gas pre-cementation fluid application method SY/T5480-92 Cementing rheological design S/T5334-1996 Casing centralizer installation distance calculation method 3 Definitions and symbols 3.1 Definitions 3.1.1 Normal pressure formation - a formation that can balance its pore repulsion or collapse pressure by using a drilling fluid column pressure with a density of 1.0g/cm to 1.3g/m. 3.1.2 High normal formation - a formation that can balance its pore pressure or uniform pressure by using a drilling fluid column pressure with a density greater than 1.3g/cm. 3.1.3 Formation prone to leakage - a formation whose leakage pressure or fracture pressure is close to its pore pressure or collapse pressure. Circulating drilling fluid is very likely to leak 3.2 Symbols See Table 1 for symbol explanation.
4 Basis for cementing technology design
Main basis for cementing technology design:
a) Designed wellbore structure or actual wellbore structure, casing specifications, entry depth and cement return height requirements; b) Data on lithology and geological stratification of actual drilled formations: pore pressure gradient and temperature gradient of oil, gas, water layer or other formations required for cementing; d) Minimum fracture pressure gradient required for cemented formations; e) Data on borehole basics such as diameter, well inclination and azimuth; d) Drilling fluid performance data of actual wellbore and drilling and engineering overview; SY/T10022 approved by the State Administration of Petroleum and Chemical Industry on April 10, 2000 for implementation in 2000-1001.2—2000
Table 1 Symbols and units
Calculation transition parameters
Casing inner diameter
Casing outer diameter
Average well diameter
Eccentricity
Maximum eccentricity of casing in the hole
Fanning friction coefficient
Gravity acceleration
Vertical depth of staged insertion
Vertical depth of lost formation
Consistency coefficient
Consistency coefficient of cement slurry
Consistency coefficient of combined liquid
Vertical distance between first-stage cement slurry return depth and staged collar Pipeline length
Flow index
Cement slurry flow index
Drilling fluid flow dynamic index
Critical Reynolds number
Reynolds number||tt ||Cement slurry well
Half-mouth pressure
Quick-setting cement slurry static water column pressure
Slow-setting cement slurry column pressure
Annulus drilling fluid, flushing fluid, isolation fluid and other fluid column pressure level cement slurry column pressure
Upper fluid column pressure
Tail hanger with
Graded hole
Upper annulus
Fluid circulation friction pressure Large
Fluid circulation friction pressure in the annulus above the tool outlet Kunming pipe delivery process
Formation pore pressure
Normal force in the retreat plane
Casing in average well inclination dogleg
Tube in plumb plane method
Normal force
Net water column pressure
Static
Fluid flow friction pressure in the annulus after grade cement weightlessness Pressure drop
Frictional pressure drop of fluid flow in pipe
Initial fracture pressure of formation
Static pressure of fluid in annulus
Static pressure of fluid in pipe
Pressure additional coefficient: 1.5~2
Plastic viscosity of cement slurry
Plastic viscosity of drilling fluid
Dimensionless
Dimensionless
Dimensionless
Dimensionless
Dimensionless
Dimensionless
SY/T10022.2—2000
Table 1 (end) Symbols and units
Displacement pump displacement
Wellbore radius
External radius of rigid centralizer
External radius of casing
Average flow rate in annulus Speed
Critical flow velocity of turbulence
Critical flow velocity of plug flow or minimum return velocity
Eliminate the dynamic shear stress of the minimum return velocity in the narrow side drilling fluid retention area of the eccentric annulus
Dynamic shear force of cement slurry
Dynamic shear force of drilling fluid
Eccentricity
Maximum eccentricity of casing in the wellbore
Eccentricity of casing in the average well
Eccentricity of inclined dogleg plane
Eccentricity on the vertical plane
Reading value of rotational viscometer at corresponding revolutionsFluid density
Grade cement slurry density
Formation loss pressure or fracture pressure
Equivalent fluid density
Grade drilling fluid density before cementing
g) Other special requirements for cementing put forward by geology and drilling engineering or production and development engineering. 5
Principles of cementing process design
Balanced pressure cementing
The annular pressure during the whole cementing process should be greater than the formation pore pressure and should not exceed the minimum fracture pressure of the main cemented formation. 5.2 Casing centering
The casing eccentricity of oil, gas, water layers and interlayer sections of directional wells, high-angle wells, large-reach wells or horizontal wells should be less than 30%. 5.3 Improve displacement efficiency
On the premise of meeting 5.1 and 5.2, displacement drilling and 5.4 Safe construction
The process design should meet the requirements of cement slurry to effectively displace the drilling fluid in the narrow gap of the eccentric annulus. The cementing process design should meet the requirements of continuous construction during the whole cementing process to avoid leakage, spraying and abnormal pressure holding. 6 Casing centralizer placement spacing design
The placement position of the centralizer should be selected in the cemented well section with denser formation and more regular wellbore 6.1 Vertical well technology casing
The placement spacing and number of casing centralizers should be determined according to the formation lithology, actual wellbore conditions and drilling operation requirements. In the following cases, each casing should be installed with an elastic casing centralizer that complies with Appendix A: 3
a) Five casings above the casing shoe;
SY/T 10022.2—2000
h) Three casings above and below the main cemented layer; c) Two casings below the graded hoop and one casing above; d) Three variable pipes for entering the upper layer to check the heavy section of the pipe. 6.2 Composition of casing and tail pipe in oil and gas layer
According to the lithology and wellbore conditions of the main wellbore section, the performance of the drilling fluid and the actual drilling conditions, the spacing and number of casing centralizers shall be determined. Each casing shall be properly installed in the following situations: only elastic casing centralizers or/and rigid centralizers in accordance with List A shall be installed: a) Five casings above the tail pipe: h) The main sealing sections of oil, gas, water layers and their spacing layers and 50m above and below; ) Five casing tail pipes entering the upper casing in the overlapping section of the tail pipe Two casing shoots below the pipe hanger finder: d) Two casings above and below the graded hoop
6.3 Technical casing of inclined wells and horizontal non-wells, oil and gas layer casing, Kun pipe 6.3.1 The placement of the centralizer shall comply with the requirements of SY/5334 standard 6.2, and accurately calculate the casing eccentricity of the main sealing layer section. 6.3.2 Combined with the lithology, diameter, eye removal trajectory parameters, drilling and fluid performance and actual drilling and lifting conditions of the main sealing layer section, adjust the calculation results and determine the final number and type of centralizers to be used. 6.3.3 The maximum eccentricity of casing between adjacent centralizers should be calculated for the adjusted casing centralizer placement distance, and the following requirements should be met:
· Maximum eccentricity of casing between two elastic centralizers: × 100≤ 30%
Emx=VerFer
Maximum eccentricity of casing between two rigid centralizers: em = (Rg - R,) + 20 Pi+ P
Maximum eccentricity of casing between a rigid centralizer and an elastic centralizer: +
Eu =(Ra - R.)
6.4 Casing friction calculation
200 VP+ P
After the spacing design of the pipe arching devices is completed, the friction resistance of the pipe is calculated: when the calculated friction resistance exceeds the allowable resistance of the designed pipe, the number of centralizers can be appropriately reduced, but the core density of the pipe in the main oil, gas and water layers and their spacing layers is less than 30%. 7 Balanced pressure cementing design
7.1 Requirements for the design of the internal pressure relief system
According to the method of 5Y/15480 and other specifications, calculate the static column pressure and flow friction pressure of the annulus fluid at different stages of the cementing and injection process. The total annulus pressure should be greater than the formation pore force and not exceed the main sealing formation rupture force: 7.2 Design requirements for flushing fluid, isolation fluid and graded collar and external packer design According to the requirements of the non-upper range of drilling and the principles of 7.1, design the flushing fluid and liquid density and return height, return speed of the cement slurry and the placement of the graded collar or external packer:
7.3 Design of cement slurry return height
7.3.1 Design principles
The design principles mainly include:
SY/T 10022.2 2000
) should meet the requirements of the next step of safe drilling and completion operations, oil and gas production, and future production increase measures; h) should be able to effectively seal the gas, water layer, and the corrosive, variable, cross-exhaustion, leakage and other complex formations that must be sealed; () to meet the special requirements of the drilling project for your pipe protection. For example: improve the casing anti-collision, anti-internal pressure or avoid the casing from breaking due to scratches and damage, etc.;
) The degree of fullness is the requirement for resisting the harsh environment of the sea and protecting the environment; ) should meet 5.1 Balanced force surrounding well principle
7.3.2 Design requirements
7.3.2.1 Riser
The water slurry is returned to the mud surface.
7.3.2.2 Surface pipe
According to the safety requirements of the drilling and development project or development project, the cement slurry height should be determined. 7.3.2.3 Technical casing cementing
It includes the following operation methods:
a) Single-stage cementing
It is required that the cement slurry return to the section 300m~500m above the casing shoe, and the lead slurry return to the position required by the drilling project. For the design pipe with a safety factor of less than or equal to 1, the cement slurry return height shall meet the requirement of the anti-extrusion safety factor of 1.125. h) Grading cementing
The first-stage cementing of the graded cementing shall return at least 300m above the casing shoe, and the lead slurry return height shall be in accordance with the requirements of the single-stage cementing: The use of graded cementing shall comply with the requirements of 7.4: The second-stage cement slurry return height shall meet the requirements of the drilling project, 7.3.2.4 Oil layer casing cementing includes the following operation methods: a) Single-stage horizontal rise Normal formation: tail slurry should be returned to the top of the oil and gas layer at least 150m, leading slurry should be returned to the height required by the drilling engineering design Small formation: fast-setting cement slurry should be returned to the top of the oil and gas layer at least 100m150m, slow-setting cement slurry should be returned to the height required by the drilling engineering design: and it is required to meet the following pressure relationship; p, P+PiaP+Pa
h) Graded consolidation
includes one of the following situations:
1) Normally, no matter whether it is grade or level: the tail slurry of grade or level shall be returned to the top of the gas layer at least 150m, and the leading slurry shall be returned to the height required by the drilling process design: the graded hoop shall be used to meet the requirements of 7.4 2) High-rise ground
The return height of graded cement slurry shall meet the height required by a) high-rise formation, and the following repulsive force relationship shall be met: P++P++ p++ p2P. +pp.
The secondary cement slurry shall be returned to the height required by the drilling and lifting project design, and the following pressure relationship shall be met! P+ P,+ PaP + F
3) In the formation prone to vibration, according to the principle of pressure balance, the cement slurry return height of the first-level vertical well is: the first-level cement slurry returns to the height required by the drilling and lifting engineering design: 7.3.2.5 The cement slurry should return to the top of the tail pipe hanger. In general, the length of the tail pipe and the upper layer should be 100m~200m high and the tail pipe cementing of the oil and gas layer should meet the following pressure relationship: SY/T10022.2—2000
P+P, + Ps+ Pr≥P+ Ppr
7.4 Design principles for the position of cementing and grading collars
Mainly include:
a) The setting of grading collars in oil and gas layers should meet the requirements of balanced pressure cementing in 7.1 of this standard; b) The setting of grading collars in high-pressure oil and gas layers or low-pressure oil and gas layers should be calculated and determined according to formula (7) or (9); c) The capacity of cementing equipment and construction safety should be considered in the design; d) The well inclination is less than or equal to 30%. Gravity opening grading collars should be used. When the well inclination is greater than 30°, it is advisable to use hydraulically opened grading collars; e) Grading collars should be placed in well sections with dense lithology, no collapse, and relatively regular holes; f) For cementing of leaky layers, in order to ensure good cement sealing above the production layer, the placement position of the grading collar can be calculated according to the following formula: ePa
7.5 The design principles for the location of the external cement expansion packer mainly include:
a) According to the needs of stratified development, the external cement expansion packer should be placed between adjacent production layers, oil-water layers or oil and gas layers in stratified development. b) The cement expansion packer outside the high-pressure well should be set at the top of the annulus tail slurry and at a relatively regular position with a relatively regular hole, but the construction pressure should be accurately calculated and the pressure of the shear pin should be reasonably selected: c) The external cement expansion packer of the leaking well should be placed according to formula (9): 8 Flushing fluid and isolation fluid design
8.1 Flushing fluid and isolation fluid performance
8.1.1 Flushing fluid and isolation fluid should be compatible with the selected cementing slurry system and drilling fluid system. The compatibility test should comply with the provisions of Appendix B of ST/T5374.
8.1.2 Flushing fluid and isolation fluid performance should comply with the provisions of Chapter 3 of SY/T5374. Under eccentric annulus conditions, the rheological properties should also comply with the requirements of Appendix B6.3 of this standard
8.2 Flushing fluid and isolation fluid usage
The amount of flushing fluid and isolation fluid used should comply with the requirements of 5.1 and 5.3 of this standard. 8.2.1 Under normal circumstances, the use of flushing fluid and turbulent spacer fluid shall meet the following requirements: a) The turbulent contact time with the main sealing formation shall be 10 minutes; b) For normal pressure formations, the amount of flushing fluid and spacer fluid used can be appropriately increased under the conditions of cementing pressure balance, open-eye formation stability and 10 minutes turbulent contact time;
c) When flushing fluid and turbulent spacer fluid are used at the same time, the usage ratio should be 2:1: Under the conditions of pressure balance and wellbore stability, the usage ratio can be expanded to 3:1 to 4:1;
d) When flushing fluid and plug flow spacer fluid are used at the same time, the usage ratio should be 4:1 to 5:1. 8.2.2 If only plug flow spacer fluid is used, its total dynamic liquid column pressure should be less than the formation fracture pressure; the usage amount should be controlled within the annulus volume range of 150m~200m.
8.2.3Under special circumstances, the amount of flushing fluid and spacer fluid used should meet the following requirements: a) Under the condition of small gap cement slurry injection, the amount of flushing fluid and spacer fluid used should at least reach the annular volume of the 400m well section; h) Under the condition of large gap cement slurry injection, the amount of flushing fluid and spacer fluid used should at least reach the annular volume of the 350m well section. 6
9 Design of cement slurry addition
Riser
SY/T10022.22000
The designed cement slurry addition should reach 150%~200% of the wellbore annular volume 9.2 Surface casing
The designed cement slurry addition should reach 80%~150% of the riser annular volume. Wells that concentrate on drilling the surface should add 150%~200% of the wellbore annular volume.
9.3 Technical casing
The designed cement slurry addition amount should reach 20%~40% of the open hole annulus volume. For open holes without well diameter data, 60%~80% of the annulus volume should be added according to the drill bit diameter.
9.4 The cement slurry addition amount of oil and gas layer casing and tail pipe
should be determined according to the open hole diameter and drilling operation conditions, and the additional amount is 20%~40% of the annulus volume. 9.5 Open hole cement plug
30%~50% of the cement plug section volume should be added9.6 Cementing operation
20%-50% of the cementing operation section volume should be added
9.7 Others
The additional amount of cement slurry can be appropriately increased or decreased according to the actual drilling conditions. 10. Process design for improving cement slurry annulus displacement efficiency 10.1 Casing eccentricity
The eccentricity of the casing in the main sealing section should be ≤30% 10.2 Drilling fluid performance adjustment
In order to meet the requirements of cementing operations, the drilling fluid performance should be fully circulated and adjusted before cementing, and the following relationship should be met as much as possible: 2YPe
Or meet:
Power law mode
Bingham mode
Bart mode
10.3 When the rheological properties of drilling fluid and cement slurry cannot meet the requirements YP
Pe, YPm
When the rheological properties of drilling fluid and cement slurry are difficult to meet the requirements of 10.2 of this standard, the casing eccentricity should be adjusted to make it as centered as possible. 10.4 Flushing fluid and spacer fluid performance and dosage Flushing fluid and spacer fluid performance and dosage should meet the requirements of Chapter 8 of this standard. 10.5 Use of cementing plugs
Double plugs should be used for single-stage cementing, and triple plugs should be used for deep wells, large displacement wells, and horizontal wells; double plugs should be used for the first stage of staged cementing. 10.6 U-tube effect
Technical casing and oil and gas layer casing (tail) pipe cementing should take into account the effect of U-tube effect, and the ratio of the maximum displacement of annular cement slurry to the designed displacement should be less than 1.25
10.7 Non-liquid time before cementing
SY/T 10022.2—2000
Under normal conditions, after the casing is lowered and before the cement slurry is injected, the drilling fluid should be circulated for more than two weeks to achieve the goal of wellbore cleaning, normal circulation pressure accumulation and stable drilling fluid performance.
10.8 Circulation and adjustment of drilling fluid performance before cementing The drilling fluid performance should be fully circulated and adjusted before the cementing slurry is injected to meet the requirements of cementing design. For high-pressure wells, the total gas volume at the wellbore outlet should be reduced by 15%.
10.9 Technical casing and oil and gas exhibition casing (tail) pipe cementing should be designed according to the rheological parameters. 10.9.1 The rheological mode should be determined based on the measured rheological parameters, and the critical flow rate or plug flow critical displacement of the flushing and isolation fluid in the main sealing section of the annulus should be calculated:
The critical flow rate of the flushing fluid and isolation fluid should be lower than the critical flow rate of the cement slurry: The allowable plug flow critical flow rate of the isolation fluid should be greater than the plug flow critical flow rate of the cement slurry.
10.9.2 According to the determined rheological model (power law, Beam, Hertz, etc.), calculate the critical displacement of turbulent flow or plug flow of cement slurry in the main sealing section of the annulus, including the following two situations: 1) For well inclination angle less than 30°, the cement slurry rheology design shall be carried out in accordance with SY/5480; 2) For well inclination angle greater than 30°, the cement slurry rheology design shall be carried out in accordance with Appendix B. 10.9.3 When low return rate cementing is used, the annular return rate of the key sealing section shall meet the requirements of the calculation results of Appendix B6.2c of this standard. 10.9.4 In order to improve the displacement efficiency, the return rate of cement slurry in the annulus of different sealing sections shall be determined according to factors such as well diameter, formation stability and cement slurry rheological parameters.P+PiaP+Pa
h) Graded consolidation
includes one of the following situations:
1) Normally, no matter whether it is grade or level: the tail slurry of grade or level shall be returned to the top of the gas layer at least 150m, and the leading slurry shall be returned to the height required by the drilling process design: the graded hoop shall be used to meet the requirements of 7.4 2) High-rise ground
The return height of graded cement slurry shall meet the height required by a) high-rise formation, and the following repulsive force relationship shall be met: P++P++ p++ p2P. +pp.
The secondary cement slurry shall be returned to the height required by the drilling and lifting project design, and the following pressure relationship shall be met! P+ P,+ PaP + F
3) In the formation prone to vibration, according to the principle of pressure balance, the cement slurry return height of the first-level vertical well is: the first-level cement slurry returns to the height required by the drilling and lifting engineering design: 7.3.2.5 The cement slurry should return to the top of the tail pipe hanger. In general, the length of the tail pipe and the upper layer should be 100m~200m high and the tail pipe cementing of the oil and gas layer should meet the following pressure relationship: SY/T10022.2—2000
P+P, + Ps+ Pr≥P+ Ppr
7.4 Design principles for the position of cementing and grading collars
Mainly include:
a) The setting of grading collars in oil and gas layers should meet the requirements of balanced pressure cementing in 7.1 of this standard; b) The setting of grading collars in high-pressure oil and gas layers or low-pressure oil and gas layers should be calculated and determined according to formula (7) or (9); c) The capacity of cementing equipment and construction safety should be considered in the design; d) The well inclination is less than or equal to 30%. Gravity opening grading collars should be used. When the well inclination is greater than 30°, it is advisable to use hydraulically opened grading collars; e) Grading collars should be placed in well sections with dense lithology, no collapse, and relatively regular holes; f) For cementing of leaky layers, in order to ensure good cement sealing above the production layer, the placement position of the grading collar can be calculated according to the following formula: ePa
7.5 The design principles for the location of the external cement expansion packer mainly include:
a) According to the needs of stratified development, the external cement expansion packer should be placed between adjacent production layers, oil-water layers or oil and gas layers in stratified development. b) The cement expansion packer outside the high-pressure well should be set at the top of the annulus tail slurry and at a relatively regular position with a relatively regular hole, but the construction pressure should be accurately calculated and the pressure of the shear pin should be reasonably selected: c) The external cement expansion packer of the leaking well should be placed according to formula (9): 8 Flushing fluid and isolation fluid design
8.1 Flushing fluid and isolation fluid performance
8.1.1 Flushing fluid and isolation fluid should be compatible with the selected cementing slurry system and drilling fluid system. The compatibility test should comply with the provisions of Appendix B of ST/T5374.
8.1.2 Flushing fluid and isolation fluid performance should comply with the provisions of Chapter 3 of SY/T5374. Under eccentric annulus conditions, the rheological properties should also comply with the requirements of Appendix B6.3 of this standard
8.2 Flushing fluid and isolation fluid usage
The amount of flushing fluid and isolation fluid used should comply with the requirements of 5.1 and 5.3 of this standard. 8.2.1 Under normal circumstances, the use of flushing fluid and turbulent spacer fluid shall meet the following requirements: a) The turbulent contact time with the main sealing formation shall be 10 minutes; b) For normal pressure formations, the amount of flushing fluid and spacer fluid used can be appropriately increased under the conditions of cementing pressure balance, open-eye formation stability and 10 minutes turbulent contact time;
c) When flushing fluid and turbulent spacer fluid are used at the same time, the usage ratio should be 2:1: Under the conditions of pressure balance and wellbore stability, the usage ratio can be expanded to 3:1 to 4:1;
d) When flushing fluid and plug flow spacer fluid are used at the same time, the usage ratio should be 4:1 to 5:1. 8.2.2 If only plug flow spacer fluid is used, its total dynamic liquid column pressure should be less than the formation fracture pressure; the usage amount should be controlled within the annulus volume range of 150m~200m.
8.2.3Under special circumstances, the amount of flushing fluid and spacer fluid used should meet the following requirements: a) Under the condition of small gap cement slurry injection, the amount of flushing fluid and spacer fluid used should at least reach the annular volume of the 400m well section; h) Under the condition of large gap cement slurry injection, the amount of flushing fluid and spacer fluid used should at least reach the annular volume of the 350m well section. 6
9 Design of cement slurry addition
Riser
SY/T10022.22000
The designed cement slurry addition should reach 150%~200% of the wellbore annular volume 9.2 Surface casing
The designed cement slurry addition should reach 80%~150% of the riser annular volume. Wells that concentrate on drilling the surface should add 150%~200% of the wellbore annular volume.
9.3 Technical casing
The designed cement slurry addition amount should reach 20%~40% of the open hole annulus volume. For open holes without well diameter data, 60%~80% of the annulus volume should be added according to the drill bit diameter.
9.4 The cement slurry addition amount of oil and gas layer casing and tail pipe
should be determined according to the open hole diameter and drilling operation conditions, and the additional amount is 20%~40% of the annulus volume. 9.5 Open hole cement plug
30%~50% of the cement plug section volume should be added9.6 Cementing operation
20%-50% of the cementing operation section volume should be added
9.7 Others
The additional amount of cement slurry can be appropriately increased or decreased according to the actual drilling conditions. 10. Process design for improving cement slurry annulus displacement efficiency 10.1 Casing eccentricity
The eccentricity of the casing in the main sealing section should be ≤30% 10.2 Drilling fluid performance adjustment
In order to meet the requirements of cementing operations, the drilling fluid performance should be fully circulated and adjusted before cementing, and the following relationship should be met as much as possible: 2YPe
Or meet:
Power law mode
Bingham mode
Bart mode
10.3 When the rheological properties of drilling fluid and cement slurry cannot meet the requirements YP
Pe, YPm
When the rheological properties of drilling fluid and cement slurry are difficult to meet the requirements of 10.2 of this standard, the casing eccentricity should be adjusted to make it as centered as possible. 10.4 Flushing fluid and spacer fluid performance and dosage Flushing fluid and spacer fluid performance and dosage should meet the requirements of Chapter 8 of this standard. 10.5 Use of cementing plugs
Double plugs should be used for single-stage cementing, and triple plugs should be used for deep wells, large displacement wells, and horizontal wells; double plugs should be used for the first stage of staged cementing. 10.6 U-tube effect
Technical casing and oil and gas layer casing (tail) pipe cementing should take into account the effect of U-tube effect, and the ratio of the maximum displacement of annular cement slurry to the designed displacement should be less than 1.25
10.7 Non-liquid time before cementing
SY/T 10022.2—2000
Under normal conditions, after the casing is lowered and before the cement slurry is injected, the drilling fluid should be circulated for more than two weeks to achieve the goal of wellbore cleaning, normal circulation pressure accumulation and stable drilling fluid performance.
10.8 Circulation and adjustment of drilling fluid performance before cementing The drilling fluid performance should be fully circulated and adjusted before the cementing slurry is injected to meet the requirements of cementing design. For high-pressure wells, the total gas volume at the wellbore outlet should be reduced by 15%.
10.9 Technical casing and oil and gas exhibition casing (tail) pipe cementing should be designed according to the rheological parameters. 10.9.1 The rheological mode should be determined based on the measured rheological parameters, and the critical flow rate or plug flow critical displacement of the flushing and isolation fluid in the main sealing section of the annulus should be calculated:
The critical flow rate of the flushing fluid and isolation fluid should be lower than the critical flow rate of the cement slurry: The allowable plug flow critical flow rate of the isolation fluid should be greater than the plug flow critical flow rate of the cement slurry.
10.9.2 According to the determined rheological model (power law, Beam, Hertz, etc.), calculate the critical displacement of turbulent flow or plug flow of cement slurry in the main sealing section of the annulus, including the following two situations: 1) For well inclination angle less than 30°, the cement slurry rheology design shall be carried out in accordance with SY/5480; 2) For well inclination angle greater than 30°, the cement slurry rheology design shall be carried out in accordance with Appendix B. 10.9.3 When low return rate cementing is used, the annular return rate of the key sealing section shall meet the requirements of the calculation results of Appendix B6.2c of this standard. 10.9.4 In order to improve the displacement efficiency, the return rate of cement slurry in the annulus of different sealing sections shall be determined according to factors such as well diameter, formation stability and cement slurry rheological parameters.P+PiaP+Pa
h) Graded consolidation
includes one of the following situations:
1) Normally, no matter whether it is grade or level: the tail slurry of grade or level shall be returned to the top of the gas layer at least 150m, and the leading slurry shall be returned to the height required by the drilling process design: the graded hoop shall be used to meet the requirements of 7.4 2) High-rise ground
The return height of graded cement slurry shall meet the height required by a) high-rise formation, and the following repulsive force relationship shall be met: P++P++ p++ p2P. +pp.
The secondary cement slurry shall be returned to the height required by the drilling and lifting project design, and the following pressure relationship shall be met! P+ P,+ PaP + F
3) In the formation prone to vibration, according to the principle of pressure balance, the cement slurry return height of the first-level vertical well is: the first-level cement slurry returns to the height required by the drilling and lifting engineering design: 7.3.2.5 The cement slurry should return to the top of the tail pipe hanger. In general, the length of the tail pipe and the upper layer should be 100m~200m high and the tail pipe cementing of the oil and gas layer should meet the following pressure relationship: SY/T10022.2—2000
P+P, + Ps+ Pr≥P+ Ppr
7.4 Design principles for the position of cementing and grading collars
Mainly include:
a) The setting of grading collars in oil and gas layers should meet the requirements of balanced pressure cementing in 7.1 of this standard; b) The setting of grading collars in high-pressure oil and gas layers or low-pressure oil and gas layers should be calculated and determined according to formula (7) or (9); c) The capacity of cementing equipment and construction safety should be considered in the design; d) The well inclination is less than or equal to 30%. Gravity opening grading collars should be used. When the well inclination is greater than 30°, it is advisable to use hydraulically opened grading collars; e) Grading collars should be placed in well sections with dense lithology, no collapse, and relatively regular holes; f) For cementing of leaky layers, in order to ensure good cement sealing above the production layer, the placement position of the grading collar can be calculated according to the following formula: ePa
7.5 The design principles for the location of the external cement expansion packer mainly include:
a) According to the needs of stratified development, the external cement expansion packer should be placed between adjacent production layers, oil-water layers or oil and gas layers in stratified development. b) The cement expansion packer outside the high-pressure well should be set at the top of the annulus tail slurry and at a relatively regular position with a relatively regular hole, but the construction pressure should be accurately calculated and the pressure of the shear pin should be reasonably selected: c) The external cement expansion packer of the leaking well should be placed according to formula (9): 8 Flushing fluid and isolation fluid design
8.1 Flushing fluid and isolation fluid performance
8.1.1 Flushing fluid and isolation fluid should be compatible with the selected cementing slurry system and drilling fluid system. The compatibility test should comply with the provisions of Appendix B of ST/T5374.
8.1.2 Flushing fluid and isolation fluid performance should comply with the provisions of Chapter 3 of SY/T5374. Under eccentric annulus conditions, the rheological properties should also comply with the requirements of Appendix B6.3 of this standard
8.2 Flushing fluid and isolation fluid usage
The amount of flushing fluid and isolation fluid used should comply with the requirements of 5.1 and 5.3 of this standard. 8.2.1 Under normal circumstances, the use of flushing fluid and turbulent spacer fluid shall meet the following requirements: a) The turbulent contact time with the main sealing formation shall be 10 minutes; b) For normal pressure formations, the amount of flushing fluid and spacer fluid used can be appropriately increased under the conditions of cementing pressure balance, open-eye formation stability and 10 minutes turbulent contact time;
c) When flushing fluid and turbulent spacer fluid are used at the same time, the usage ratio should be 2:1: Under the conditions of pressure balance and wellbore stability, the usage ratio can be expanded to 3:1 to 4:1;
d) When flushing fluid and plug flow spacer fluid are used at the same time, the usage ratio should be 4:1 to 5:1. 8.2.2 If only plug flow spacer fluid is used, its total dynamic liquid column pressure should be less than the formation fracture pressure; the usage amount should be controlled within the annulus volume range of 150m~200m.
8.2.3Under special circumstances, the amount of flushing fluid and spacer fluid used should meet the following requirements: a) Under the condition of small gap cement slurry injection, the amount of flushing fluid and spacer fluid used should at least reach the annular volume of the 400m well section; h) Under the condition of large gap cement slurry injection, the amount of flushing fluid and spacer fluid used should at least reach the annular volume of the 350m well section. 6
9 Design of cement slurry addition
Riser
SY/T10022.22000
The designed cement slurry addition should reach 150%~200% of the wellbore annular volume 9.2 Surface casing
The designed cement slurry addition should reach 80%~150% of the riser annular volume. Wells that concentrate on drilling the surface should add 150%~200% of the wellbore annular volume.
9.3 Technical casing
The designed cement slurry addition amount should reach 20%~40% of the open hole annulus volume. For open holes without well diameter data, 60%~80% of the annulus volume should be added according to the drill bit diameter.
9.4 The cement slurry addition amount of oil and gas layer casing and tail pipe
should be determined according to the open hole diameter and drilling operation conditions, and the additional amount is 20%~40% of the annulus volume. 9.5 Open hole cement plug
30%~50% of the cement plug section volume should be added9.6 Cementing operation
20%-50% of the cementing operation section volume should be added
9.7 Others
The additional amount of cement slurry can be appropriately increased or decreased according to the actual drilling conditions. 10. Process design for improving cement slurry annulus displacement efficiency 10.1 Casing eccentricity
The eccentricity of the casing in the main sealing section should be ≤30% 10.2 Drilling fluid performance adjustment
In order to meet the requirements of cementing operations, the drilling fluid performance should be fully circulated and adjusted before cementing, and the following relationship should be met as much as possible: 2YPe
Or meet:
Power law mode
Bingham mode
Bart mode
10.3 When the rheological properties of drilling fluid and cement slurry cannot meet the requirements YP
Pe, YPm
When the rheological properties of drilling fluid and cement slurry are difficult to meet the requirements of 10.2 of this standard, the casing eccentricity should be adjusted to make it as centered as possible. 10.4 Flushing fluid and spacer fluid performance and dosage Flushing fluid and spacer fluid performance and dosage should meet the requirements of Chapter 8 of this standard. 10.5 Use of cementing plugs
Double plugs should be used for single-stage cementing, and triple plugs should be used for deep wells, large displacement wells, and horizontal wells; double plugs should be used for the first stage of staged cementing. 10.6 U-tube effect
Technical casing and oil and gas layer casing (tail) pipe cementing should take into account the effect of U-tube effect, and the ratio of the maximum displacement of annular cement slurry to the designed displacement should be less than 1.25
10.7 Non-liquid time before cementing
SY/T 10022.2—2000
Under normal conditions, after the casing is lowered and before the cement slurry is injected, the drilling fluid should be circulated for more than two weeks to achieve the goal of wellbore cleaning, normal circulation pressure accumulation and stable drilling fluid performance.
10.8 Circulation and adjustment of drilling fluid performance before cementing The drilling fluid performance should be fully circulated and adjusted before the cementing slurry is injected to meet the requirements of cementing design. For high-pressure wells, the total gas volume at the wellbore outlet should be reduced by 15%.
10.9 Technical casing and oil and gas exhibition casing (tail) pipe cementing should be designed according to the rheological parameters. 10.9.1 The rheological mode should be determined based on the measured rheological parameters, and the critical flow rate or plug flow critical displacement of the flushing and isolation fluid in the main sealing section of the annulus should be calculated:
The critical flow rate of the flushing fluid and isolation fluid should be lower than the critical flow rate of the cement slurry: The allowable plug flow critical flow rate of the isolation fluid should be greater than the plug flow critical flow rate of the cement slurry.
10.9.2 According to the determined rheological model (power law, Beam, Hertz, etc.), calculate the critical displacement of turbulent flow or plug flow of cement slurry in the main sealing section of the annulus, including the following two situations: 1) For well inclination angle less than 30°, the cement slurry rheology design shall be carried out in accordance with SY/5480; 2) For well inclination angle greater than 30°, the cement slurry rheology design shall be carried out in accordance with Appendix B. 10.9.3 When low return rate cementing is used, the annular return rate of the key sealing section shall meet the requirements of the calculation results of Appendix B6.2c of this standard. 10.9.4 In order to improve the displacement efficiency, the return rate of cement slurry in the annulus of different sealing sections shall be determined according to factors such as well diameter, formation stability and cement slurry rheological parameters.
The secondary cement slurry shall return to the height required by the drilling and lifting engineering design, and shall meet the following pressure relationship: P+ P,+ PaP + F
3) The secondary cement slurry shall return to the height required by the drilling and lifting engineering design: 7.3.2.5 Ni tube solid opening
The cement slurry shall return to the top of the tail pipe hanger. In general, the length of the tail pipe and the upper layer should be 100m~200m high and the tail pipe cementing of the oil and gas layer should meet the following pressure relationship: SY/T10022.2—2000
P+P, + Ps+ Pr≥P+ Ppr
7.4 Design principles for the position of cementing and grading collars
Mainly include:
a) The setting of grading collars in oil and gas layers should meet the requirements of balanced pressure cementing in 7.1 of this standard; b) The setting of grading collars in high-pressure oil and gas layers or low-pressure oil and gas layers should be calculated and determined according to formula (7) or (9); c) The capacity of cementing equipment and construction safety should be considered in the design; d) The well inclination is less than or equal to 30%. Gravity opening grading collars should be used. When the well inclination is greater than 30°, it is advisable to use hydraulically opened grading collars; e) Grading collars should be placed in well sections with dense lithology, no collapse, and relatively regular holes; f) For cementing of leaky layers, in order to ensure good cement sealing above the production layer, the placement position of the grading collar can be calculated according to the following formula: ePa
7.5 The design principles for the location of the external cement expansion packer mainly include:
a) According to the needs of stratified development, the external cement expansion packer should be placed between adjacent production layers, oil-water layers or oil and gas layers in stratified development. b) The cement expansion packer outside the high-pressure well should be set at the top of the annulus tail slurry and at a relatively regular position with a relatively regular hole, but the construction pressure should be accurately calculated and the pressure of the shear pin should be reasonably selected: c) The external cement expansion packer of the leaking well should be placed according to formula (9): 8 Flushing fluid and isolation fluid design
8.1 Flushing fluid and isolation fluid performance
8.1.1 Flushing fluid and isolation fluid should be compatible with the selected cementing slurry system and drilling fluid system. The compatibility test should comply with the provisions of Appendix B of ST/T5374.
8.1.2 Flushing fluid and isolation fluid performance should comply with the provisions of Chapter 3 of SY/T5374. Under eccentric annulus conditions, the rheological properties should also comply with the requirements of Appendix B6.3 of this standard
8.2 Flushing fluid and isolation fluid usage
The amount of flushing fluid and isolation fluid used should comply with the requirements of 5.1 and 5.3 of this standard. 8.2.1 Under normal circumstances, the use of flushing fluid and turbulent spacer fluid shall meet the following requirements: a) The turbulent contact time with the main sealing formation shall be 10 minutes; b) For normal pressure formations, the amount of flushing fluid and spacer fluid used can be appropriately increased under the conditions of cementing pressure balance, open-eye formation stability and 10 minutes turbulent contact time; bzxz.net
c) When flushing fluid and turbulent spacer fluid are used at the same time, the usage ratio should be 2:1: Under the conditions of pressure balance and wellbore stability, the usage ratio can be expanded to 3:1 to 4:1;
d) When flushing fluid and plug flow spacer fluid are used at the same time, the usage ratio should be 4:1 to 5:1. 8.2.2 If only plug flow spacer fluid is used, its total dynamic liquid column pressure should be less than the formation fracture pressure; the usage amount should be controlled within the annulus volume range of 150m~200m.
8.2.3Under special circumstances, the amount of flushing fluid and spacer fluid used should meet the following requirements: a) Under the condition of small gap cement slurry injection, the amount of flushing fluid and spacer fluid used should at least reach the annular volume of the 400m well section; h) Under the condition of large gap cement slurry injection, the amount of flushing fluid and spacer fluid used should at least reach the annular volume of the 350m well section. 6
9 Design of cement slurry addition
Riser
SY/T10022.22000
The designed cement slurry addition should reach 150%~200% of the wellbore annular volume 9.2 Surface casing
The designed cement slurry addition should reach 80%~150% of the riser annular volume. Wells that concentrate on drilling the surface should add 150%~200% of the wellbore annular volume.
9.3 Technical casing
The designed cement slurry addition amount should reach 20%~40% of the open hole annulus volume. For open holes without well diameter data, 60%~80% of the annulus volume should be added according to the drill bit diameter.
9.4 The cement slurry addition amount of oil and gas layer casing and tail pipe
should be determined according to the open hole diameter and drilling operation conditions, and the additional amount is 20%~40% of the annulus volume. 9.5 Open hole cement plug
30%~50% of the cement plug section volume should be added9.6 Cementing operation
20%-50% of the cementing operation section volume should be added
9.7 Others
The additional amount of cement slurry can be appropriately increased or decreased according to the actual drilling conditions. 10. Process design for improving cement slurry annulus displacement efficiency 10.1 Casing eccentricity
The eccentricity of the casing in the main sealing section should be ≤30% 10.2 Drilling fluid performance adjustment
In order to meet the requirements of cementing operations, the drilling fluid performance should be fully circulated and adjusted before cementing, and the following relationship should be met as much as possible: 2YPe
Or meet:
Power law mode
Bingham mode
Bart mode
10.3 When the rheological properties of drilling fluid and cement slurry cannot meet the requirements YP
Pe, YPm
When the rheological properties of drilling fluid and cement slurry are difficult to meet the requirements of 10.2 of this standard, the casing eccentricity should be adjusted to make it as centered as possible. 10.4 Flushing fluid and spacer fluid performance and dosage Flushing fluid and spacer fluid performance and dosage should meet the requirements of Chapter 8 of this standard. 10.5 Use of cementing plugs
Double plugs should be used for single-stage cementing, and triple plugs should be used for deep wells, large displacement wells, and horizontal wells; double plugs should be used for the first stage of staged cementing. 10.6 U-tube effect
Technical casing and oil and gas layer casing (tail) pipe cementing should take into account the effect of U-tube effect, and the ratio of the maximum displacement of annular cement slurry to the designed displacement should be less than 1.25
10.7 Non-liquid time before cementing
SY/T 10022.2—2000
Under normal conditions, after the casing is lowered and before the cement slurry is injected, the drilling fluid should be circulated for more than two weeks to achieve the goal of wellbore cleaning, normal circulation pressure accumulation and stable drilling fluid performance.
10.8 Circulation and adjustment of drilling fluid performance before cementing The drilling fluid performance should be fully circulated and adjusted before the cementing slurry is injected to meet the requirements of cementing design. For high-pressure wells, the total gas volume at the wellbore outlet should be reduced by 15%.
10.9 Technical casing and oil and gas exhibition casing (tail) pipe cementing should be designed according to the rheological parameters. 10.9.1 The rheological mode should be determined based on the measured rheological parameters, and the critical flow rate or plug flow critical displacement of the flushing and isolation fluid in the main sealing section of the annulus should be calculated:
The critical flow rate of the flushing fluid and isolation fluid should be lower than the critical flow rate of the cement slurry: The allowable plug flow critical flow rate of the isolation fluid should be greater than the plug flow critical flow rate of the cement slurry.
10.9.2 According to the determined rheological model (power law, Beam, Hertz, etc.), calculate the critical displacement of turbulent flow or plug flow of cement slurry in the main sealing section of the annulus, including the following two situations: 1) For well inclination angle less than 30°, the cement slurry rheology design shall be carried out in accordance with SY/5480; 2) For well inclination angle greater than 30°, the cement slurry rheology design shall be carried out in accordance with Appendix B. 10.9.3 When low return rate cementing is used, the annular return rate of the key sealing section shall meet the requirements of the calculation results of Appendix B6.2c of this standard. 10.9.4 In order to improve the displacement efficiency, the return rate of cement slurry in the annulus of different sealing sections shall be determined according to factors such as well diameter, formation stability and cement slurry rheological parameters.
The secondary cement slurry shall return to the height required by the drilling and lifting engineering design, and shall meet the following pressure relationship: P+ P,+ PaP + F
3) The secondary cement slurry shall return to the height required by the drilling and lifting engineering design: 7.3.2.5 Ni tube solid opening
The cement slurry shall return to the top of the tail pipe hanger. In general, the length of the tail pipe and the upper layer should be 100m~200m high and the tail pipe cementing of the oil and gas layer should meet the following pressure relationship: SY/T10022.2—2000
P+P, + Ps+ Pr≥P+ Ppr
7.4 Design principles for the position of cementing and grading collars
Mainly include:
a) The setting of grading collars in oil and gas layers should meet the requirements of balanced pressure cementing in 7.1 of this standard; b) The setting of grading collars in high-pressure oil and gas layers or low-pressure oil and gas layers should be calculated and determined according to formula (7) or (9); c) The capacity of cementing equipment and construction safety should be considered in the design; d) The well inclination is less than or equal to 30%. Gravity opening grading collars should be used. When the well inclination is greater than 30°, it is advisable to use hydraulically opened grading collars; e) Grading collars should be placed in well sections with dense lithology, no collapse, and relatively regular holes; f) For cementing of leaky layers, in order to ensure good cement sealing above the production layer, the placement position of the grading collar can be calculated according to the following formula: ePa
7.5 The design principles for the location of the external cement expansion packer mainly include:
a) According to the needs of stratified development, the external cement expansion packer should be placed between adjacent production layers, oil-water layers or oil and gas layers in stratified development. b) The cement expansion packer outside the high-pressure well should be set at the top of the annulus tail slurry and at a relatively regular position with a relatively regular hole, but the construction pressure should be accurately calculated and the pressure of the shear pin should be reasonably selected: c) The external cement expansion packer of the leaking well should be placed according to formula (9): 8 Flushing fluid and isolation fluid design
8.1 Flushing fluid and isolation fluid performance
8.1.1 Flushing fluid and isolation fluid should be compatible with the selected cementing slurry system and drilling fluid system. The compatibility test should comply with the provisions of Appendix B of ST/T5374.
8.1.2 Flushing fluid and isolation fluid performance should comply with the provisions of Chapter 3 of SY/T5374. Under eccentric annulus conditions, the rheological properties should also comply with the requirements of Appendix B6.3 of this standard
8.2 Flushing fluid and isolation fluid usage
The amount of flushing fluid and isolation fluid used should comply with the requirements of 5.1 and 5.3 of this standard. 8.2.1 Under normal circumstances, the use of flushing fluid and turbulent spacer fluid shall meet the following requirements: a) The turbulent contact time with the main sealing formation shall be 10 minutes; b) For normal pressure formations, the amount of flushing fluid and spacer fluid used can be appropriately increased under the conditions of cementing pressure balance, open-eye formation stability and 10 minutes turbulent contact time;
c) When flushing fluid and turbulent spacer fluid are used at the same time, the usage ratio should be 2:1: Under the conditions of pressure balance and wellbore stability, the usage ratio can be expanded to 3:1 to 4:1;
d) When flushing fluid and plug flow spacer fluid are used at the same time, the usage ratio should be 4:1 to 5:1. 8.2.2 If only plug flow spacer fluid is used, its total dynamic liquid column pressure should be less than the formation fracture pressure; the usage amount should be controlled within the annulus volume range of 150m~200m.
8.2.3Under special circumstances, the amount of flushing fluid and spacer fluid used should meet the following requirements: a) Under the condition of small gap cement slurry injection, the amount of flushing fluid and spacer fluid used should at least reach the annular volume of the 400m well section; h) Under the condition of large gap cement slurry injection, the amount of flushing fluid and spacer fluid used should at least reach the annular volume of the 350m well section. 6
9 Design of cement slurry addition
Riser
SY/T10022.22000
The designed cement slurry addition should reach 150%~200% of the wellbore annular volume 9.2 Surface casing
The designed cement slurry addition should reach 80%~150% of the riser annular volume. Wells that concentrate on drilling the surface should add 150%~200% of the wellbore annular volume.
9.3 Technical casing
The designed cement slurry addition amount should reach 20%~40% of the open hole annulus volume. For open holes without well diameter data, 60%~80% of the annulus volume should be added according to the drill bit diameter.
9.4 The cement slurry addition amount of oil and gas layer casing and tail pipe
should be determined according to the open hole diameter and drilling operation conditions, and the additional amount is 20%~40% of the annulus volume. 9.5 Open hole cement plug
30%~50% of the cement plug section volume should be added9.6 Cementing operation
20%-50% of the cementing operation section volume should be added
9.7 Others
The additional amount of cement slurry can be appropriately increased or decreased according to the actual drilling conditions. 10. Process design for improving cement slurry an
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