CN110984907A - Well repairing method based on low-leakage temporary plugging process - Google Patents
Well repairing method based on low-leakage temporary plugging process Download PDFInfo
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- 125000002496 methyl group Chemical group [H]C([H])([H])* 0.000 claims description 2
- ZBVQEUUTPTVMHY-UHFFFAOYSA-N phenyl-(2-phenylphenyl)methanone Chemical compound C=1C=CC=C(C=2C=CC=CC=2)C=1C(=O)C1=CC=CC=C1 ZBVQEUUTPTVMHY-UHFFFAOYSA-N 0.000 claims description 2
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- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 description 1
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical compound S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 description 1
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like
-
- 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
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/504—Compositions based on water or polar solvents
- C09K8/506—Compositions based on water or polar solvents containing organic compounds
- C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
- C09K8/5086—Compositions based on water or polar solvents containing organic compounds macromolecular compounds obtained otherwise than by reactions only involving carbon-to-carbon unsaturated bonds
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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
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/504—Compositions based on water or polar solvents
- C09K8/506—Compositions based on water or polar solvents containing organic compounds
- C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
- C09K8/514—Compositions based on water or polar solvents containing organic compounds macromolecular compounds of natural origin, e.g. polysaccharides, cellulose
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- Life Sciences & Earth Sciences (AREA)
- Chemical & Material Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Organic Chemistry (AREA)
- Materials Engineering (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Geochemistry & Mineralogy (AREA)
- Sealing Material Composition (AREA)
Abstract
The invention discloses a well repairing method based on a low-leakage temporary plugging process, which comprises the following steps of: preparing temporary plugging type well killing fluid, wherein the temporary plugging type well killing fluid is formed by uniformly dispersing temporary plugging polymer particles in solidified saline water, and the solidified saline water is prepared by dissolving or uniformly dispersing a curing agent, a curing initiator, a colloid protective agent and a saline water regulator in fresh water or saline water or slurry; pumping a solid-free completion hydraulic well into the oil gas well, and detecting loss; pumping the temporary plugging type well killing fluid into an oil-gas well, and detecting loss by follow-up; and step four, performing workover operation when no loss exists underground. The invention has the beneficial effects that the super absorbent temporary plugging polymer in the temporary plugging control fluid forms a colloid temporary plugging layer on the holes or the well wall through physical dehydration and chemical reaction, thereby effectively blocking leakage and having good stability; in addition, the temporary plugging polymer is easy to acidify and degrade, no residue is left after degradation, the subsequent production is not influenced, and the degradation product is environment-friendly.
Description
Technical Field
The invention belongs to the technical field of oil and gas well reconstruction, and particularly relates to a well repairing method based on a low-leakage temporary plugging process.
Background
After long-term exploitation of part of oil and gas wells in most oil and gas fields, the formation pressure is greatly reduced, and most of the wells are lower than the hydrostatic column pressure at present. According to previous operation conditions in some areas, if a conventional brine workover fluid or kill fluid system is used, a large amount of loss can occur, and meanwhile, the fluid in the well is difficult to remove completely. The water saturation around the well bore can be greatly changed due to the loss of a large amount of killing fluid, and the relative permeability of gas phase is reduced, so that the yield of the gas well after well workover is greatly reduced; meanwhile, the well killing and the recovery period are longer, and the well repairing benefit is influenced.
In some low-pressure high-yield high-sulfur-content wells, oil pipes are perforated, seriously corroded and even broken, if a hydraulic well is repaired by high-density saline water, the leakage of a low-pressure layer can be caused, meanwhile, the high-pressure layer causes well overflow and well kick, the well is repeatedly pressed, the complex condition under the well is easily caused, and the difficulty and unsafe factors of operation are increased. And the traditional temporary plugging agent is not tight in plugging, air leakage, poor sealing effect and the like occur, so that the pressure in the sealing channel cannot achieve the expected effect, and the yield can be reduced during later-stage collection. Meanwhile, repeated leakage and well killing can damage the water trap of the atmosphere, so that the productivity of the gas well is greatly reduced after well repair, the operation period is greatly prolonged, and the economic loss is large. The gas well with high hydrogen sulfide content has great safety and environmental protection risks, the current well killing technology, well killing fluid system technology and field construction operation are in bottleneck states, the best purpose of workover operation cannot be realized, the development benefit of the oil field is greatly reduced, and the safety risks exist in real time.
Disclosure of Invention
In view of the above, the invention provides a workover method based on a low-leakage temporary plugging process, which has a good temporary plugging effect, can effectively block the leakage of workover fluid in a medium-low-permeability reservoir, and the temporary plugging agent is easy to decompose and discharge under appropriate conditions.
The technical scheme is as follows:
a well repairing method based on a low-leakage temporary plugging process is characterized by comprising the following steps:
preparing temporary plugging type well killing fluid, wherein the temporary plugging type well killing fluid comprises solidified brine and temporary plugging polymer particles, and the temporary plugging polymer particles are uniformly dispersed in the solidified brine;
the solidified saline is prepared by dissolving or uniformly dispersing a curing agent, a curing initiator, a colloid protective agent and a saline regulator in fresh water or saline or slurry;
pumping a solid-free completion hydraulic well into the oil gas well, and detecting loss;
pumping the temporary plugging type well killing fluid into an oil-gas well, and detecting the leakage of the solidified brine;
and step four, performing workover operation when no loss exists underground.
As a preferred technical scheme, in the third step, after the temporary plugging type well killing fluid is pumped in, the well killing distance is 10m3And the temporary plugging type well killing fluid is used for detecting the leakage condition.
Preferably, the solid-free completion fluid is SW-1 type solid-free completion fluid.
According to a preferable technical scheme, in the curing saline, the content of the curing agent is 1.0-2.0%, the content of the curing initiator is 0.2-1.5%, the content of the colloid protective agent is 0.1-0.5%, and the content of the saline regulator is 0.8-1.5% by weight.
According to a preferable technical scheme, in the curing saline, the content of the curing agent is 1.0-2.0%, the content of the curing initiator is 0.2-0.5%, the content of the colloid protective agent is 0.1-0.2%, and the content of the saline regulator is 0.8% by weight.
Preferably, the curing agent is any one of ethylenediamine modified products, dicyandiamide and N-aminoethyl piperazine.
Preferably, the curing initiator is any one of chlorobenzophenone, phenylbenzophenone, benzoin dimethyl ether and methyl o-benzoylformate.
As a preferred technical scheme, the colloid protective agent is any one of polyvinyl alcohol, magnesium aluminum silicate and starch.
As a preferred technical scheme, the temporary plugging polymer particles are polyester compounds formed by dihydric alcohol and dicarboxylic acid.
Preferably, in the first step, the temporary plugging polymer particles in a short rod shape or a ball shape are uniformly dispersed in the solidified brine to obtain the temporary plugging type well killing fluid, and the content of the temporary plugging polymer is 0.2-2.0%.
Drawings
FIG. 1 is a photograph of a polymer particle in the form of a short rod;
FIG. 2 is a picture of spherical polymer particles of different sizes;
FIG. 3 is a picture of polymer powder;
FIG. 4 is a schematic diagram of temporary plugging of kill fluid flow and initial temporary plugging into a fracture;
FIG. 5 is a schematic diagram of temporary plugging of a temporary plugging layer formed by temporary plugging of a kill fluid, wherein 5(a) is a physical temporary plugging layer, and 5(b) is a schematic diagram of a colloidal temporary plugging layer formed after a high-temperature reaction;
FIG. 6 is a graph of the pressure and consistency of the temporary plugging kill fluid over time;
FIG. 7 is a schematic illustration of polymer particles forming a temporary plugging layer on a borehole or borehole wall by physical dehydration.
Detailed Description
The present invention is further illustrated by the following examples.
1. Preparation of temporary plugging well killing fluid
The reservoir of a certain well is biological reef, dolomite or macroporous reservoir, the formation pressure coefficient is 0.75, the temperature is 120 ℃, and the base fluid for preparing the non-leakage workover fluid is fresh water, salt water or slurry. Meanwhile, due to the high well temperature, a proper amount of colloid protective agent is used in the formula, so that the temperature resistance of the system is improved. In addition, curing initiators are used to improve the ability of the non- (low) leaking workover fluid to bind water and to speed up the mud-making process. Therefore, the preparation process of the temporary plugging control fluid without (low) leakage, which is suitable for the biological reef, the dolomite and the macroporous reservoir stratum, is as follows:
adding 1.0-2.0% of curing agent, 0.2-0.5% of curing initiator, 0.1-0.2% of colloid protective agent and 0.8% of saline regulator into fresh water or saline to obtain cured saline; and adding 0.2-2.0% of temporary plugging polymer particles into the solidified brine and uniformly dispersing to obtain the temporary plugging well killing fluid. Table 1 shows several formulations of temporary plugging kill fluids.
TABLE 1 formulation of series temporary plugging kill fluid
The temporary plugging polymer particles are made of polyester compounds formed by polycondensation of dihydric alcohol and dicarboxylic acid. The synthesis reaction formula is as follows:
nHOO-CR1-COOH+nHO-R2-OH→HO-[OCR1-COOR2-]n-OH+nH2O，
wherein R is1、R2At least one of which may be a hydrocarbon group having a hydrophilic substituent.
Due to the existence of ester bonds, the polyester compound can be slowly and naturally degraded in the presence of water at a certain temperature, and can be quickly degraded under an acidic condition. The degradation reaction is the reversible reaction of the polymerization reaction:
HO-[OCR1-COOR2-]n-OH+nH2O→nHOO-CR1-COOH+nHO-R2-OH。
the degraded products are dihydric alcohol and dicarboxylic acid monomers which are all easily soluble in water, no solid residue is left after degradation, and the monomers can further react with other substances under natural conditions, so that the environment is not polluted.
The molecular weight of the polymer is controlled, and the obtained polymer has different hydrolysis difficulty degrees and can be suitable for different well temperature conditions.
Due to the existence of hydrophilic groups in molecular chains, the hydrophilic polymer has strong hydrophilicity, and can bind clear water or saline water far higher than the self weight of the hydrophilic polymer, so that the bound water cannot participate in free flow.
The temporary plugging polymer particles may be in the form of short rods of 3 to 5mm in length as shown in FIG. 1, or in the form of spheres of 5 to 15mm in diameter as shown in FIG. 2, or in the form of powders as shown in FIG. 3.
2. Physicochemical property of temporary plugging well killing fluid
According to the existing detection method, important physicochemical parameters of the temporary plugging control fluid, including viscosity, stability and corrosivity, are detected.
The viscosity of the temporary plugging well killing fluid is adjustable within the range of 25-110 mPa & S; the temporary plugging well killing fluid is stored at 120 ℃ in a heat preservation mode, the viscosity of the temporary plugging well killing fluid is measured after 10 days, and the viscosity reduction value measured in an experiment is less than or equal to 40%, which indicates that the system has better stability; the temporary plugging kill fluid prepared from fresh water has no corrosion to N80 pipe test pieces basically, and the corrosion prepared from saturated brine is very small, so that the normal service life of the pipe is not influenced.
The temporary plugging polymer particles are easy to deform and enter the corresponding channels through accumulation and deformation, so that temporary plugging is formed. And (4) gradually raising the temperature and observing and recording experimental data by means of a conventional sand bed leak stopping experiment.
Under the condition that the temperature is lower than 100 ℃, the polyester compound material is physically dehydrated under positive pressure difference to form a temporary plugging layer, the leakage of the well control fluid is blocked, the flowing and temporary plugging process is shown in figure 4, and the temporary plugging layer formed at the moment is shown in figure 5 (a).
When the temperature is higher than 120 ℃, the temporary blocking layer formed by the polyester compound material can be gradually or instantaneously chemically transformed into a colloidal temporary blocking layer, and the colloidal temporary blocking layer has higher strength and lower permeability, as shown in fig. 5 (b).
And recording the changes of the pressure, the consistency and the temperature of the temporary plugging control fluid system along with the time, as shown in fig. 6, and as can be seen, after 80 minutes, the pressure, the consistency and the temperature of the temporary plugging control fluid system are good in stability, and the time requirement of well repairing operation is met.
3. Effect of temporary plugging kill fluid on recovery characteristics of producing formation
After the temporary plugging control fluid is mixed with the formation water, no precipitation, delamination and flocculation exist, which indicates that the compatibility with the formation water is good.
And (3) simulating the stratum leakage and blockage removal conditions in a core flow experiment mode by using the core dynamic damage evaluation device. The temporary plugging control fluid system does not break gel and depends on natural drainage, and the permeability recovery value of the core is 84.88%; after the system breaks the gel, the permeability recovery value of the core reaches 92.23%; after the core is cut off by 2mm, the damage rate of the permeability is only 0.25%, which indicates that the temporary plugging layer is only within 2mm, and the permeability of the core is not substantially damaged.
The temporary plugging well killing fluid system utilizes the characteristic of high water absorption of the molecular chain of the polyester compound, the temporary plugging polymer particles formed by the polyester compound control the free water in the temporary plugging well killing fluid system, and a temporary plugging layer is formed on the hole or the well wall through physical dehydration, and the plugging schematic diagram is shown in fig. 7. The temporary plugging layer is subjected to chemical reaction caused by high temperature (above 120 ℃) in the well, the temporary plugging layer forms a colloid artificial well wall, the leakage of the workover fluid in the medium-low permeability reservoir is effectively blocked, the technical problem of the leakage of the workover fluid is solved, and the technical breakthrough is provided. Once the temporary plugging layer of the temporary plugging well killing fluid is formed, the temporary plugging layer can bear the pressure difference of more than 11MPa without cracking, and the temporary plugging effect is good.
4. In situ kill job
Example 1
The construction process of temporary blocking of the cured brine of the well A of the Chuandong fractured stratum comprises the following steps:
step one, dissolving 68 tons of sodium chloride in fresh water to prepare the sodium chloride with the density of 1.17g/cm3Adding curing agent, colloid protective agent and initiator to prepare cured brine with the volume of 200;
preparing a temporary plugging type well killing fluid 40, wherein the temporary plugging type well killing fluid is formed by adding the temporary plugging polymer particles into the solidified brine and dispersing;
step three, killing the well, namely firstly using the material with the density of 1.15g/cm3The SW-1 type solid-free completion hydraulic well is tested for loss, and the loss is 3.8m3/h；
Step three, injecting the temporary plugging type well killing fluid with a reverse 10m3The well killing fluid is followed to detect the loss of the solidified saline water, and the loss is found to be 3.8m3The/h is gradually reduced to 2.3m3H, then reduced to 0.5m3H until there is substantially no loss (pressure drop)<0.5 MPa); at this time, the plugging is proved to be good;
and step four, carrying out various designed operations.
Acidification is carried out after 45 days, and the yield is 7.5 multiplied by 104m3/d。
Example 2
Construction conditions of a Chuandong fractured stratum B well:
the pressure difference between the Yangxing stratum and the coke system of the well is about 13MPa, the pressure difference between the well killing fluid and the stratum is about 18MPa, and the well temperature is 107 ℃.
The construction process in the embodiment 1 is adopted for temporary plugging, the brine solidification operation is approximately two months, and the construction is safe. The well is a typical carbonate fracture formation, and in order to ensure the temporary plugging reliability, the temporary plugging polymer particles are added into the solidified saline water to serve as bridging particles. And finally, the acidification productivity is recovered to be normal.
Has the advantages that: the temporary plugging polymer particles prepared from the high-water-absorptivity degradable polyester compound, a proper curing agent, a curing initiator, a colloid protective agent, a saline water regulator and fresh water or saline water form temporary plugging kill fluid, a temporary plugging layer is formed on an eyelet or a well wall through physical dehydration, and chemical reaction of the temporary plugging layer is caused by underground high temperature, so that the temporary plugging layer forms a colloid artificial well wall, the leakage of the kill fluid in a medium-low permeability reservoir is effectively blocked, the stability is good, and the technical problem of the leakage of the kill fluid is solved; in addition, the temporary plugging polymer is easy to acidify and degrade, has no residue after degradation, is easy to discharge, does not influence subsequent production, has no pollution to degradation products, and is environment-friendly.
Finally, it should be noted that the above-mentioned description is only a preferred embodiment of the present invention, and those skilled in the art can make various similar representations without departing from the spirit and scope of the present invention.
Claims (10)
1. A well repairing method based on a low-leakage temporary plugging process is characterized by comprising the following steps:
preparing temporary plugging type well killing fluid, wherein the temporary plugging type well killing fluid comprises solidified brine and temporary plugging polymer particles, and the temporary plugging polymer particles are uniformly dispersed in the solidified brine;
the solidified saline is prepared by dissolving or uniformly dispersing a curing agent, a curing initiator, a colloid protective agent and a saline regulator in fresh water or saline or slurry;
pumping a solid-free completion hydraulic well into the oil gas well, and detecting loss;
pumping the temporary plugging type well killing fluid into an oil-gas well, and detecting the leakage of the solidified brine;
and step four, performing workover operation when no loss exists underground.
2. The well intervention method based on a low-leakage temporary plugging process of claim 1, wherein: in the third step, after the temporary plugging type well killing fluid is pumped in, the well killing fluid is held back for 10m3And the temporary plugging type well killing fluid is used for detecting the leakage condition.
3. The well intervention method based on a low-leakage temporary plugging process of claim 1, wherein: the solid-free completion fluid is SW-1 type solid-free completion fluid.
4. The well intervention method based on a low-leakage temporary plugging process of claim 1, wherein: in the cured saline, the content of the curing agent is 1.0-2.0%, the content of the curing initiator is 0.2-1.5%, the content of the colloid protective agent is 0.1-0.5%, and the content of the saline regulator is 0.8-1.5% by weight.
5. The well intervention method based on a low-leakage temporary plugging process of claim 1, wherein: in the cured saline, the content of the curing agent is 1.0-2.0%, the content of the curing initiator is 0.2-0.5%, the content of the colloid protective agent is 0.1-0.2%, and the content of the saline regulator is 0.8% by weight.
6. A well intervention method based on a low leakage temporary plugging process according to claim 4 or 5, wherein: the curing agent is any one of ethylenediamine modifier, dicyandiamide and N-aminoethyl piperazine.
7. A well intervention method based on a low leakage temporary plugging process according to claim 4 or 5, wherein: the curing initiator is any one of chlorobenzophenone, phenyl benzophenone, benzoin dimethyl ether and methyl o-benzoylformate.
8. A well intervention method based on a low leakage temporary plugging process according to claim 4 or 5, wherein: the colloid protective agent is any one of polyvinyl alcohol, magnesium aluminum silicate and starch.
9. The well intervention method based on a low-leakage temporary plugging process of claim 1, wherein: the temporary plugging polymer particles are polyester compounds formed by dihydric alcohol and dicarboxylic acid.
10. The well intervention method based on a low-leakage temporary plugging process of claim 1, wherein: in the first step, the short rod-shaped or spherical temporary plugging polymer particles are uniformly dispersed in the solidified brine to obtain the temporary plugging type well killing fluid, wherein the content of the temporary plugging polymer particles is 0.2-2.0%.
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| CN116696279A (en) * | 2023-08-07 | 2023-09-05 | 新疆斐德莱布能源科技有限公司 | Temporary blocking operation method of long straight well section gas storage |
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| CN116696279A (en) * | 2023-08-07 | 2023-09-05 | 新疆斐德莱布能源科技有限公司 | Temporary blocking operation method of long straight well section gas storage |
| CN116696279B (en) * | 2023-08-07 | 2024-01-26 | 新疆斐德莱布能源科技有限公司 | Temporary blocking operation method of long straight well section gas storage |
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