CN108359421A - A kind of sea bed gas hydrate stratum Compositional type drilling fluid - Google Patents
A kind of sea bed gas hydrate stratum Compositional type drilling fluid Download PDFInfo
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- CN108359421A CN108359421A CN201810249645.7A CN201810249645A CN108359421A CN 108359421 A CN108359421 A CN 108359421A CN 201810249645 A CN201810249645 A CN 201810249645A CN 108359421 A CN108359421 A CN 108359421A
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/02—Well-drilling compositions
- C09K8/04—Aqueous well-drilling compositions
- C09K8/06—Clay-free compositions
- C09K8/12—Clay-free compositions containing synthetic organic macromolecular compounds or their precursors
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
- C09K2208/12—Swell inhibition, i.e. using additives to drilling or well treatment fluids for inhibiting clay or shale swelling or disintegrating
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
- C09K2208/22—Hydrates inhibition by using well treatment fluids containing inhibitors of hydrate formers
Abstract
A kind of sea bed gas hydrate stratum Compositional type drilling fluid, is related to exploitation of gas hydrates field.Drilling fluid of the present invention includes following components：Polyethylene glycol, sodium chloride, ethylene glycol, low viscosity carboxymethyl cellulose LV CMC, polyacrylic acid potassium, xanthans, Vinylcaprolactam homopolymer, propylene glycol phenylate, tetra-n-butyl ammonium phosphate and preparation water, it can be used for sea bed gas hydrate storage drilling well to use, has the function of Solid Free, low temperature resistant, it is compounded with synergist in drilling fluid by the way that kinetic inhibitor is added, inhibition is generated with stronger hydrate, and components of drilling liquid is small to environmental hazard, has many advantages, such as that efficient, environmental protection, raw material are cheap and easy to get.
Description
Technical field
The present invention relates to a kind of sea bed gas hydrate stratum Compositional type drilling fluids, and in particular to gas hydrates are opened
Adopt field.
Background technology
Gas hydrates in nature are mainly distributed on epeiric ocean deepwater area and land permafrost area, preceding
Person accounts for oneself and finds the overwhelming majority of quantity.Gas hydrates are one of very promising alternative energy sources, to gas hydrates
Research be contemporary geoscience and energy industry developmental research a big hot spot.Submarine sedimentary strata, which is contained, a large amount of natural gas
Hydrate will be explored and be developed to the gas hydrates for assigning the plant certain depths in underground, and drilling well is essential heavy
Want means.The phase equilibrium properties of gas hydrates determine that such strata drilling and general hydrocarbon formations drilling well have very very much not
Together, this kind of strata drilling is also caused to face more complicated well inner question, at present the main problem of gas hydrates drilling fluid
There is the following：
(1) when being crept into natural gas hydrate stratum, since reservoir stress can discharge near the reservoir borehole wall and shaft bottom, stratum
Pressure reduction；And the friction of bit cutting rock, bottomhole and the borehole wall and rock core can all generate a large amount of thermal energy, make hydration
The temperature, pressure condition that object is stabilized is destroyed；To cause the decomposition of hydrate, borehole well instability is caused, drillng operation is made
At adverse effect.
(2) decomposition of mud filtrate invasion and hydrate can cause formation pore pressure to increase in various degree, pore pressure
Increase so that drilling fluid density needed for wellbore stability is kept also accordingly to increase, this not only seriously affects drilling speed, but also increases the borehole wall
Infiltration, makes the pore pressure in well week increase, and to further decrease the stability of the borehole wall, forms vicious circle.
(3) due to entering the water that decomposition of hydrate generates in drilling fluid filtrate and stratum in stratum in drilling process,
Stratum water content is caused gradually to increase.When stratum water content is excessively high, hydrate formation skeleton aquation can be made to aggravate, lead to the borehole wall
It is more unstable.Also, decomposition of hydrate can also be such that the permeability on stratum increases, and drilling fluid is permeated to the borehole wall generates osmotic pressure,
The caving pressure on stratum is set to improve, fracture pressure reduces, and makes the borehole wall be more easy to cave in and pressure break, reduces borehole wall stability.
(4) sea bed gas hydrate is stored, gas hydrates are stored in drilling process, the decomposition of hydrate
The super quiet pore pressure in the storage soil body is set to increase rapidly, so as to cause submarine landslide or foundation of sea floor unstability, in turn
It may cause the destruction of the facilities such as drilling, drilling platforms, submarine pipeline.
Chinese patent literature publication number CN103146364B, patent name are《A kind of high inhibition water-base drilling fluid》, by water
100 parts, 0.2-4 parts of polyamine inhibitor, 0.1-1 parts of inhibitor of coating, 10-25 parts of hydrate inhibitor, 0.1-1 parts of tackifier,
0.5-3 parts of compositions of 0.5-5 parts of fluid loss additive and fluid lubricant.The drilling fluid can inhibit deep water shallow stratum borehole well instability, can
The generation for solving the problems, such as hydrate in deepwater drilling is applicable in the drillng operation of the 3000m depth of waters.Chinese patent literature discloses
Number CN104531106A, patent name are《A kind of efficient hydrate inhibition environmental protection drilling fluid》, by water, bentonite, quaternary amine
Type Gemini surface active agent, inorganic salts, sodium carboxymethyl starch, cationic polyacrylamide, solid anti sinking lubricant GFRH compositions,
The petroleum resources exploitation that can be used for land or ocean, effectively inhibits the generation of hydrate, and components of drilling liquid is to environmental hazard
It is small, have many advantages, such as efficient, environmental protection.Chinese patent literature publication number CN105018052A, patent name are《A kind of low solid phase is low
Warm polymer drilling fluid》, including basal liquid and inorganic agent, wherein basal liquid are answered with sodium bentonite and sodium chloride solution
Match；Inorganic agent is that sulfonated bodies cation exchange resin is compounded with polysaccharide as flow pattern regulator.The drilling fluid is in low temperature
Under the conditions of to decompose strong inhibition capability, good rheological property, fluid loss low.Above-mentioned drilling fluid has one to gas hydrates storage drilling well
Fixed effect, but do not consider to use Compositional type hydrate inhibitor.
Ensure that natural gas hydrate stratum drilling safety successfully carries out, must just take measures to well temperature and pressure
Power is strictly controlled, and controls and reduce the degree of decomposition of hydrate as far as possible using the drilling fluid with good low temperature properties,
To keep wellbore stability and shaft safety, therefore on the basis of the above, the present invention proposes a kind of sea bed gas hydrate stratum
Compositional type drilling fluid.
Invention content
The purpose of the present invention is to provide a kind of sea bed gas hydrate stratum Compositional type drilling fluid, drilling fluids of the present invention
Including following components：Polyethylene glycol, sodium chloride, ethylene glycol, low viscosity carboxymethyl cellulose LV-CMC, polyacrylic acid potassium, xanthan
Glue, Vinylcaprolactam homopolymer, propylene glycol phenylate, tetra-n-butyl ammonium phosphate and preparation water, can be used for sea-bottom natural gas hydration
Object is stored drilling well and is used, and has the function of Solid Free, low temperature resistant, is answered with synergist in drilling fluid by the way that kinetic inhibitor is added
Match, there is stronger hydrate to generate inhibition, and components of drilling liquid is small to environmental hazard, there is efficient, environmental protection, raw material
The advantages that cheap and easy to get.
In order to achieve the above object, the present invention adopts the following technical scheme that.
A kind of sea bed gas hydrate stratum Compositional type drilling fluid, which is characterized in that the drilling fluid includes with the following group
Point：Polyethylene glycol mass ratio is 5%-7%, sodium chloride mass ratio is 14%-16%, quality of glycol ratio is 14%-16%, low
Viscosity carboxymethyl cellulose LV-CMC mass ratioes are 1.8%-2.2%, polyacrylic acid potassium mass ratio is 1.8%-2.2%, xanthan
Glue mass ratio is 0.4%-0.6%, Vinylcaprolactam homopolymer mass ratio is 0.8%-1.2%, propylene glycol phenylate mass ratio is
0.8%-1.2%, tetra-n-butyl ammonium phosphate mass ratio are 0.8%-1.2%, and remaining components are to prepare water.
Preferably, the drilling fluid includes following components：Polyethylene glycol mass ratio is 6%, sodium chloride mass ratio is 15%,
Quality of glycol ratio is 15%, low viscosity carboxymethyl cellulose LV-CMC mass ratioes are 2%, polyacrylic acid potassium mass ratio is 2%,
Xanthans mass ratio is 0.5%, Vinylcaprolactam homopolymer mass ratio is 1%, propylene glycol phenylate mass ratio is 1%, four positive fourths
Base ammonium phosphate mass ratio is 1%, and remaining components are to prepare water.
In above-mentioned drilling fluid, host agent of the polyethylene glycol as drilling fluid can increase drilling fluid density, increase drilling fluid
Low temperature resistivity increases to the shale stability in drilling process, and can mitigate the degree of stratum leakage, moderately prevents leakage, and
And can have powerful " memory effect " after gas hydrate synthesis, the residual structurals such as pentahedron ring of water can keep steady at 315K
Fixed, the presence of " memory effect " at this time causes the generation of hydrate to be more prone to.Kinetic inhibitor is added can be to a certain degree
The upper influence for weakening " memory effect ", and the synergistic effect of polyethylene glycol can further decrease " memory effect "；The present invention uses
Peg molecule quality be 4000.
In above-mentioned drilling fluid, the sodium chloride reduces the solidifying of drilling fluid as thermodynamic inhibitor, and as low-temperature resistance agent
Solid temperature degree.
In above-mentioned drilling fluid, the ethylene glycol is as low-temperature resistance agent, kinetic inhibitor synergist；Ethylene glycol is one kind two
First alcohol has stronger hydrogen bond Forming ability, after being mixed with water, can form firm hydrogen bond with water, can be greatly lowered
The freezing point of solution.
In above-mentioned drilling fluid, the low viscosity carboxymethyl cellulose LV-CMC is used as thickener, anti-sloughing agent.
In above-mentioned drilling fluid, the polyacrylic acid potassium is used as anti-sloughing agent.
In above-mentioned drilling fluid, the xanthans is used as creeping agent, the flow pattern of adjusting drilling well liquid.
In above-mentioned drilling fluid, the Vinylcaprolactam homopolymer is used as kinetic inhibitor, and propylene glycol phenylate,
For tetra-n-butyl ammonium phosphate as kinetic inhibitor synergist, power is relatively used alone in the inhibition for compounding kinetic inhibitor
It is significantly improved when learning inhibitor；The Vinylcaprolactam homopolymer with N- caprolactams (VCL) be monomer, azo two
Isobutyronitrile is initiator, is synthesized by solution polymerization process, and synthetic method is known technology, and not this patent protects content, wherein
N- caprolactams (VCL) produce for BASF AG, purity 100%；Azodiisobutyronitrile is Tianjin
Zhi Yuan chemical reagent Co., Ltd produces, and analysis is pure.
In above-mentioned drilling fluid, the preparation water is conventional source water water, such as river water, well water and filtered seawater etc.；It bores
Well liquid preparation method is conventional drilling liquid making method.
The drilling fluid cools down equipment in use, corresponding drilling fluid can be equipped in drilling platforms, for controlling drilling fluid
Low temperature；It can be equipped with corresponding solid control equipment in drilling platforms, the clay particle for that will be distributed in drilling fluid removes, and reaches drop
Low-soild effect.
The drilling fluid in use, make a trip, more bit change and well logging when, can as needed into drilling fluid be added weight
Spar improves drilling fluid density, for inhibiting decomposition of hydrate, prevents blowout, drilling fluid density is adjusted to 1.2-2.0g/
cm3, when subsequent well taken out barite by ground recycle unit, and drilling fluid is made to restore initial density.
Chlorination can be added in use, in case of saline bed, mud shale easily collapse stratum in the drilling fluid into drilling fluid system
Calcium solution.
The drilling fluid in use, can be needed according to practical storage alkalinity control agent is added adjust pH value 9-10 it
Between.
The present invention the advantage is that compared with the existing technology：
1, the present invention uses polyethylene glycol as host agent, and is clay-free drilling fluid, has good rheological characteristic, and can
It more fully carries and outstanding gang drill is considered to be worth doing, can effectively reduce and prevent the repetition of drilling cuttings broken.
2, drilling fluid of the present invention can solve the problems, such as that hydrate generates in gas hydrates storage drilling process, can prevent
Bit freezing caused by forming hydrate in drilling process, the safety accidents such as preventer and catheter blockage.
3, drilling fluid of the present invention has good low-temperature stability, keeps low-temperature condition by controlling drilling fluid, can prevent
Gas hydrates store drilling process in foot of hole position hydrate a large amount of decomposition, can avoid cause aperture seriously expand,
The accidents such as blowout, well slough, casing deformation and surface subsidence.
4, drilling fluid of the present invention damages small caused by reservoir, is conducive to that gas water is found and protected in drilling process
Close produce layer.The drilling fluid has the characteristics that Solid Free, low-density, therefore, nearly balance can be achieved in drilling process even
Underbalance pressure drilling can effectively reduce intrusion of the solid phase to stratum, to advantageously reduce to gas hydrates reservoir
Damage.
5, drilling fluid of the present invention uses Compositional type hydrate inhibitor, is compounded by kinetic inhibitor and synergist,
Hydrate generates inhibition relatively exclusive use kinetic inhibitor and is obviously improved, and sea bed gas hydrate is stored up
It hides, the decomposition of hydrate can be reduced, to reduce the probability for causing submarine landslide or foundation of sea floor unstability.
Specific implementation mode
Experimental method used in following embodiments is conventional method unless otherwise specified.
The polyethylene glycol used in following embodiments is the sub- safe joint Chemical Co., Ltd. production of Wuxi City, and analysis is pure, point
Son amount 4000；Sodium chloride is the prosperous prosperous Chemical Co., Ltd.'s production in Tianjin, and analysis is pure；Ethylene glycol is that Tianjin causes remote chemistry examination
Agent Co., Ltd produces, and analysis is pure；Low viscosity carboxymethyl cellulose LV-CMC is the sincere hundred million Chemical Co., Ltd.s production of Renqiu City；It is poly-
Potassium acrylate produces for Hebei Yan Xing Chemical Co., Ltd.s；Xanthans is the sincere hundred million Chemical Co., Ltd.s production of Renqiu City；Propylene glycol
Phenylate produces for Dow Chemical company, and analysis is pure；Tetra-n-butyl ammonium phosphate is Henan Longhua chemical product Co., Ltd of Zhengzhou section
Production, content 97%；Methane gas comes from Wuhan Huaxing Ind ＆ Tech Co., Ltd., purity 99.9%.
In the following embodiments, each noun dummy suffix notation, unit correspondence are as follows：Temperature, is abbreviated as T, and unit is Celsius
Degree；Apparent viscosity writes a Chinese character in simplified form AV, unit mPa.s；Plastic viscosity is abbreviated as PV, unit mPa.s；Yield value is abbreviated as YP, unit
Pa；Filter loss is abbreviated as FL, unit ml.
Embodiment one, each component content is in drilling fluid：Polyethylene glycol mass ratio is 5%, sodium chloride mass ratio is 14%,
Quality of glycol ratio is 14%, low viscosity carboxymethyl cellulose LV-CMC mass ratioes are 1.8%, polyacrylic acid potassium mass ratio is
1.8%, xanthans mass ratio is 0.4%, Vinylcaprolactam homopolymer mass ratio is 0.8%, propylene glycol phenylate mass ratio is
0.8%, tetra-n-butyl ammonium phosphate mass ratio is 0.8%, and remaining components are to prepare water.
Embodiment two, each component content is in drilling fluid：Polyethylene glycol mass ratio is 6%, sodium chloride mass ratio is 15%,
Quality of glycol ratio is 15%, low viscosity carboxymethyl cellulose LV-CMC mass ratioes are 2%, polyacrylic acid potassium mass ratio is 2%,
Xanthans mass ratio is 0.5%, Vinylcaprolactam homopolymer mass ratio is 1%, propylene glycol phenylate mass ratio is 1%, four positive fourths
Base ammonium phosphate mass ratio is 1%, and remaining components are to prepare water.
Embodiment three, each component content is in drilling fluid：Polyethylene glycol mass ratio is 7%, sodium chloride mass ratio is 16%,
Quality of glycol ratio is 16%, low viscosity carboxymethyl cellulose LV-CMC mass ratioes are 2.2%, polyacrylic acid potassium mass ratio is
2.2%, xanthans mass ratio is 0.6%, Vinylcaprolactam homopolymer mass ratio is 1.2%, propylene glycol phenylate mass ratio is
1.2%, tetra-n-butyl ammonium phosphate mass ratio is 1.2%, and remaining components are to prepare water.
One, two, three drilling fluid allocation method of above-described embodiment is conventional drilling liquid configuration method, passes through following experimental method
It is evaluated：
1 drilling fluid Shale Hydration inhibition is evaluated
When carrying out the Lab-evaluation of correlated performance to drilling fluid, inhibition evaluation experimental is one of important composition portion
Point, the present invention is tested using mud shale expansion Inhibition test, and specific experiment data are as shown in table 1.
1 aquation inhibition of table evaluates data
As can be seen from Table 1, under the same conditions, inhibition energy of one, two, three drilling fluid system of embodiment to shale expansion
Power is clearly.Wherein, initial 2 hour line percent expansion is only 3.3%, 3.2%, 3.1%, and at the end of testing, 16 is small
When line percent expansion be only 8.5%, 7.9%, 7.5%, and the clear water to compare mutually be 40.3%；In experimentation, clearly
Shale expansion percentage in water is in over time the trend to increase substantially, and shale is swollen in embodiment drilling fluid
The variation of swollen percentage is but relatively steady, and when experiment proceeds to 16h, the expansion rate variation of shale is smaller, expansion rate variation by
Gradually tend towards stability.It can be seen that the drilling fluid system can significantly reduce the hydration swelling amount of mud shale, it can be effectively prevented ground
Layer hole instability caused by due to aquation.
2 drilling fluid low temperature rheological behaviours are evaluated
Seabed formation temperature containing hydrate is generally 0 DEG C -4 DEG C, creeps into hydrate formation to decompose inhibition method, often passes through drop
The temperature of low drilling fluid inhibits the decomposition of hydrate, it requires that drilling fluid temperature is less than formation temperature, and with good
Cryogenic property.
In the experiment of drilling fluid low temperature rheological behaviour, cooling drilling fluid is to a certain constant first in high-low temperature test chamber
Temperature.When the temperature of drilling fluid, which is reduced to, tests required a certain steady temperature, continue at this temperature 1 hour
It is cooling.Period at the uniform velocity stirs drilling fluid with glass bar two minutes in every 15 minutes, and the temperature inside drilling fluid is made to keep uniformly dividing
Then cloth tests the rheological parameter of drilling fluid by six fast electronic rotation viscosimeters at this temperature.Wait for that rheological characteristic is tested
After finishing, the density of drilling fluid is tested with densimeter rapidly, tests the filter loss of drilling fluid immediately later.It finally measures and includes
The situation of change of drilling fluid rheology under the conditions of 10 DEG C, 5 DEG C, 0 DEG C, -5 DEG C, -10 DEG C.
Experiment test property of the drilling fluid in 5 different temperatures, experimental result such as following table.
The rheological characteristic of 2 embodiment of table, one drilling fluid at different temperatures
| T(℃) | ρ(g/cm3) | Gel(Pa/Pa) | PV(mPa.s) | YP(Pa) | Fl(ml) |
| 10 | 1.11 | 1.5/2 | 19.6 | 7.5 | 6.8 |
| 5 | 1.13 | 1.5/2 | 21.8 | 7.9 | 6.6 |
| 0 | 1.14 | 2/2.5 | 23.9 | 8.5 | 6.4 |
| -5 | 1.14 | 2/2.5 | 25.9 | 8.8 | 5.9 |
| -10 | 1.14 | 2/2.5 | 26.5 | 9.1 | 5.7 |
The rheological characteristic of 3 embodiment of table, two drilling fluid at different temperatures
| T(℃) | ρ(g/cm3) | Gel(Pa/Pa) | PV(mPa.s) | YP(Pa) | Fl(ml) |
| 10 | 1.13 | 1.5/2 | 20.5 | 7.7 | 6.7 |
| 5 | 1.14 | 1.5/2 | 22.3 | 7.8 | 6.5 |
| 0 | 1.16 | 2/2.5 | 23.1 | 8.6 | 6.2 |
| -5 | 1.16 | 2/2.5 | 24.4 | 8.9 | 5.7 |
| -10 | 1.16 | 2/2.5 | 27.8 | 9.3 | 5.3 |
The rheological characteristic of 4 embodiment of table, three drilling fluid at different temperatures
| T(℃) | ρ(g/cm3) | Gel(Pa/Pa) | PV(mPa.s) | YP(Pa) | Fl(ml) |
| 10 | 1.15 | 1.5/2 | 21.3 | 7.9 | 6.6 |
| 5 | 1.16 | 1.5/2 | 23.5 | 8.3 | 6.4 |
| 0 | 1.17 | 2/2.5 | 24.7 | 8.8 | 5.9 |
| -5 | 1.17 | 2/2.5 | 25.4 | 9.0 | 5.7 |
| -10 | 1.17 | 2/2.5 | 28.3 | 9.5 | 5.3 |
From table 2-4 it is found that as temperature reduces, the plastic viscosity and shear force of drilling fluid increase, but change it is little, all can
In the range of receiving.In addition, drilling fluid ratio of dynamic shear force/yield value to plastic viscosity is higher, be conducive to cutting carring, clean wellbore, filter loss reduce with temperature and
It reduces.Rheological characteristic and stability are preferable under cryogenic for the drilling fluid configured.
3 methane hydrates, which generate, inhibits evaluation
In terms of the hydrate of drilling fluid generates rejection evaluation, the present invention is tested in autoclave by acquiring
The variation of temperature, pressure and other parameters in the process, and the directly observation of visualization window is combined to carry out；Experimental test procedures are：It is first
First the drilling fluid of prepared certain volume is put into reaction kettle, methane gas is passed through, sets high pressure low temperature experimental enviroment,
Air source is cut off, data acquisition software is opened, collected temperature, pressure data are protected in the temperature and pressure variation in observing response kettle
It deposits, during the experiment, in order to simulate drill string rotation, control mixing speed is 200r/min, is surveyed under conditions of there is disturbance
The hydrate inhibition effect of examination drilling fluid of the present invention.
During deepwater drilling, drilling fluid is about 2-4h from shaft bottom to drilling platforms cycle period, according to API standard with
And General Experimental Procedures, under the conditions of the certain water of simulation bathybic temperature and pressure, the drilling fluid containing hydrate inhibitor
It is generated without hydrate in 16h, that is, illustrates that the drilling fluid can meet requirement of the deepwater drilling to hydrate inhibition, experimental temperature
2 DEG C, -5 DEG C, -10 DEG C of selection, pressure select 5mPa, 10mPa, 15mPa, mixing speed 200r/min, experimental period selection
16h。
Comparative example 1
Deionized water is fitted into the reaction kettle of gas hydrates inhibition evaluation experimental device, simulation 500m depth is bored
Well environment, i.e. experimental pressure are 5mPa, and experimental temperature is 2 DEG C, mixing speed 200r/min, the generation of hydrate in reaction kettle
Time is 1.7h.
Comparative example 2
Sodium chloride is configured to the aqueous solution that mass percent is 10%, is packed into gas hydrates inhibition evaluation experimental
In the reaction kettle of device, 1500m depth drilling environments are simulated, i.e. experimental pressure is 15MPa, and experimental temperature is 2 DEG C, mixing speed
200r/min, the generated time of hydrate is 3.2h in reaction kettle.
5 hydrate of table, which generates, inhibits tables of data
| Number | Initial pressure (MPa) | Final pressure (MPa) | Pressure drop (MPa) | Temperature (DEG C) |
| Embodiment one | 5 | 4.83 | 0.17 | 2 |
| Embodiment one | 10 | 9.73 | 0.27 | -5 |
| Embodiment one | 15 | 14.64 | 0.36 | -10 |
| Embodiment two | 5 | 4.84 | 0.16 | 2 |
| Embodiment two | 10 | 9.74 | 0.26 | -5 |
| Embodiment two | 15 | 14.65 | 0.35 | -10 |
| Embodiment three | 5 | 4.85 | 0.15 | 2 |
| Embodiment three | 10 | 9.75 | 0.25 | -5 |
| Embodiment three | 15 | 14.68 | 0.32 | -10 |
The result shows that：In one, two, three drilling fluid system experimentation of embodiment, reacting kettle inner pressure and temperature are 16
That apparent variation does not occur in the reaction time of hour, pressure curve more steadily, is dissolved in interior gas always after uncapping
Body is released in seconds, does not observe the generation of hydrate, accordingly it is found that drilling fluid system of the present invention can be in dynamic environment very
Inhibit the generation of hydrate well.
4 contamination resistances are evaluated
Test drilling fluid contamination resistance：It is surveyed after a certain amount of bentonite (4%, 8%) maintenance 72h is added in drilling fluid
Its performance is tried, contamination resistance is evaluated, test temperature is 5 DEG C, as a result be see the table below.
6 embodiment of table, one drilling fluid system contamination resistance is evaluated
| Formula | ρ(g/cm3) | Gel(Pa/Pa) | PV(mPa.s) | YP(Pa) | Fl(ml) |
| Embodiment one | 1.13 | 1.5/2 | 21.8 | 7.9 | 6.6 |
| One+4% bentonite of embodiment | 1.17 | 2/2.5 | 23.5 | 8.5 | 5.6 |
| One+8% bentonite of embodiment | 1.2 | 2.5/3 | 24.7 | 9.7 | 4.9 |
7 embodiment of table, two drilling fluid system contamination resistance is evaluated
8 embodiment of table, three drilling fluid system contamination resistance is evaluated
| Formula | ρ(g/cm3) | Gel(Pa/Pa) | PV(mPa.s) | YP(Pa) | Fl(ml) |
| Embodiment three | 1.16 | 1.5/2 | 23.5 | 8.3 | 6.4 |
| Three+4% bentonite of embodiment | 1.20 | 2/2.5 | 25.3 | 8.7 | 5.4 |
| Three+8% bentonite of embodiment | 1.22 | 2.5/3 | 27.7 | 9.9 | 4.6 |
After 4% and 8% bentonite is added in drilling fluid it can be seen from table 6-8, the viscosity and shear force of drilling fluid on
It rises, but amplitude of variation is little, shows that the drilling fluid contamination resistance is stronger.
5 rate of recovery are evaluated
The rate of recovery that drilling fluid is tested by rolling dispersion experiment, using certain block seabed landwaste as test object, 80
Heat rolling 16h at DEG C, the sieve for being 0.45mm with aperture recycle, and the experimental data are shown in the following table.
The different system rolling rate of recovery comparisons of table 9
| System | Primary recovery (%) | Secondary returning yield (%) |
| Embodiment one | 90.6 | 89.0 |
| Embodiment two | 91.2 | 89.1 |
| Embodiment three | 92.3 | 90.3 |
As can be seen from Table 9, the rate of recovery of drilling fluid system is higher, and the primary and secondary rate of recovery reaches 90% or so,
Landwaste primary recovery reacts drilling fluid chemistry inhibition power, and landwaste of the secondary returning yield reaction after mud soak exists
Dispersibility in clear water, dispersibility is smaller to illustrate that the suppressed effect of landwaste is stronger, and the borehole wall more they tends to stablize.
6 lubricities are tested
Using drilling fluid extreme boundary lubrication instrument, the extreme boundary lubrication coefficient of drilling fluid of the present invention is tested, the results showed that three realities
The extreme boundary lubrication coefficient for applying example is respectively 0.0878,0.0899,0.0913, within 0.1, shows that drilling fluid of the present invention has
Good lubricity.
Claims (2)
1. a kind of sea bed gas hydrate stratum Compositional type drilling fluid, which is characterized in that the drilling fluid includes following components：
Polyethylene glycol mass ratio is 5%-7%, sodium chloride mass ratio is 14%-16%, quality of glycol ratio is 14%-16%, low viscous
Degree carboxymethyl cellulose LV-CMC mass ratioes are 1.8%-2.2%, polyacrylic acid potassium mass ratio is 1.8%-2.2%, xanthans
Mass ratio is 0.4%-0.6%, Vinylcaprolactam homopolymer mass ratio is 0.8%-1.2%, propylene glycol phenylate mass ratio is
0.8%-1.2%, tetra-n-butyl ammonium phosphate mass ratio are 0.8%-1.2%, and remaining components are to prepare water.
2. a kind of sea bed gas hydrate stratum Compositional type drilling fluid as described in claim 1, which is characterized in that the brill
Well liquid includes following components：Polyethylene glycol mass ratio is 6%, sodium chloride mass ratio is 15%, quality of glycol ratio is 15%, low
Viscosity carboxymethyl cellulose LV-CMC mass ratioes are 2%, polyacrylic acid potassium mass ratio is 2%, xanthans mass ratio is 0.5%,
Vinylcaprolactam homopolymer mass ratio is 1%, propylene glycol phenylate mass ratio is 1%, tetra-n-butyl ammonium phosphate mass ratio is 1%,
Remaining components are to prepare water.
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|---|---|---|---|
| CN201810249645.7A Withdrawn CN108359421A (en) | 2018-03-28 | 2018-03-28 | A kind of sea bed gas hydrate stratum Compositional type drilling fluid |
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| Country | Link |
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| CN (1) | CN108359421A (en) |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN111548777A (en) * | 2020-04-20 | 2020-08-18 | 天津中油渤星工程科技有限公司 | Sea area natural gas hydrate drilling fluid and preparation method and application thereof |
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2018
- 2018-03-28 CN CN201810249645.7A patent/CN108359421A/en not_active Withdrawn
Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN111548777A (en) * | 2020-04-20 | 2020-08-18 | 天津中油渤星工程科技有限公司 | Sea area natural gas hydrate drilling fluid and preparation method and application thereof |
| CN111548777B (en) * | 2020-04-20 | 2022-11-01 | 天津中油渤星工程科技有限公司 | Sea area natural gas hydrate drilling fluid and preparation method and application thereof |
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Application publication date: 20180803 |