CN117209657A - Polymer gel plugging agent suitable for tight fractured reservoir and preparation method thereof - Google Patents
Polymer gel plugging agent suitable for tight fractured reservoir and preparation method thereof Download PDFInfo
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- CN117209657A CN117209657A CN202311175741.9A CN202311175741A CN117209657A CN 117209657 A CN117209657 A CN 117209657A CN 202311175741 A CN202311175741 A CN 202311175741A CN 117209657 A CN117209657 A CN 117209657A
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- 238000002360 preparation method Methods 0.000 title claims abstract description 16
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 121
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Chemical compound O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 63
- 239000000178 monomer Substances 0.000 claims abstract description 37
- 238000006116 polymerization reaction Methods 0.000 claims abstract description 32
- 239000003431 cross linking reagent Substances 0.000 claims abstract description 18
- 239000003999 initiator Substances 0.000 claims abstract description 13
- HRPVXLWXLXDGHG-UHFFFAOYSA-N Acrylamide Chemical compound NC(=O)C=C HRPVXLWXLXDGHG-UHFFFAOYSA-N 0.000 claims abstract description 11
- 229940047670 sodium acrylate Drugs 0.000 claims abstract description 10
- PQUXFUBNSYCQAL-UHFFFAOYSA-N 1-(2,3-difluorophenyl)ethanone Chemical compound CC(=O)C1=CC=CC(F)=C1F PQUXFUBNSYCQAL-UHFFFAOYSA-N 0.000 claims abstract description 9
- 239000008367 deionised water Substances 0.000 claims abstract description 9
- 229910021641 deionized water Inorganic materials 0.000 claims abstract description 9
- 239000003112 inhibitor Substances 0.000 claims abstract description 9
- DZSVIVLGBJKQAP-UHFFFAOYSA-N 1-(2-methyl-5-propan-2-ylcyclohex-2-en-1-yl)propan-1-one Chemical compound CCC(=O)C1CC(C(C)C)CC=C1C DZSVIVLGBJKQAP-UHFFFAOYSA-N 0.000 claims abstract description 7
- 238000007865 diluting Methods 0.000 claims abstract description 5
- NFTADESQVWCREX-UHFFFAOYSA-L chromium(3+);carbonate Chemical compound [Cr+3].[O-]C([O-])=O NFTADESQVWCREX-UHFFFAOYSA-L 0.000 claims description 12
- JVTAAEKCZFNVCJ-UHFFFAOYSA-N lactic acid Chemical compound CC(O)C(O)=O JVTAAEKCZFNVCJ-UHFFFAOYSA-N 0.000 claims description 10
- KRKNYBCHXYNGOX-UHFFFAOYSA-N citric acid Chemical compound OC(=O)CC(O)(C(O)=O)CC(O)=O KRKNYBCHXYNGOX-UHFFFAOYSA-N 0.000 claims description 9
- 239000002981 blocking agent Substances 0.000 claims description 8
- 229940064958 chromium citrate Drugs 0.000 claims description 7
- SWXXYWDHQDTFSU-UHFFFAOYSA-K chromium(3+);2-hydroxypropane-1,2,3-tricarboxylate Chemical compound [Cr+3].[O-]C(=O)CC(O)(CC([O-])=O)C([O-])=O SWXXYWDHQDTFSU-UHFFFAOYSA-K 0.000 claims description 7
- QIGBRXMKCJKVMJ-UHFFFAOYSA-N 1,4-Benzenediol Natural products OC1=CC=C(O)C=C1 QIGBRXMKCJKVMJ-UHFFFAOYSA-N 0.000 claims description 6
- QTBSBXVTEAMEQO-UHFFFAOYSA-N Acetic acid Chemical compound CC(O)=O QTBSBXVTEAMEQO-UHFFFAOYSA-N 0.000 claims description 6
- PAYRUJLWNCNPSJ-UHFFFAOYSA-N N-phenyl amine Natural products NC1=CC=CC=C1 PAYRUJLWNCNPSJ-UHFFFAOYSA-N 0.000 claims description 6
- MUBZPKHOEPUJKR-UHFFFAOYSA-N Oxalic acid Chemical compound OC(=O)C(O)=O MUBZPKHOEPUJKR-UHFFFAOYSA-N 0.000 claims description 6
- 238000006243 chemical reaction Methods 0.000 claims description 6
- 239000004310 lactic acid Substances 0.000 claims description 5
- 235000014655 lactic acid Nutrition 0.000 claims description 5
- ROOXNKNUYICQNP-UHFFFAOYSA-N ammonium persulfate Chemical compound [NH4+].[NH4+].[O-]S(=O)(=O)OOS([O-])(=O)=O ROOXNKNUYICQNP-UHFFFAOYSA-N 0.000 claims description 4
- XBDQKXXYIPTUBI-UHFFFAOYSA-N dimethylselenoniopropionate Natural products CCC(O)=O XBDQKXXYIPTUBI-UHFFFAOYSA-N 0.000 claims description 4
- USHAGKDGDHPEEY-UHFFFAOYSA-L potassium persulfate Chemical compound [K+].[K+].[O-]S(=O)(=O)OOS([O-])(=O)=O USHAGKDGDHPEEY-UHFFFAOYSA-L 0.000 claims description 4
- 239000000203 mixture Substances 0.000 claims description 3
- LCPVQAHEFVXVKT-UHFFFAOYSA-N 2-(2,4-difluorophenoxy)pyridin-3-amine Chemical compound NC1=CC=CN=C1OC1=CC=C(F)C=C1F LCPVQAHEFVXVKT-UHFFFAOYSA-N 0.000 claims description 2
- 235000011054 acetic acid Nutrition 0.000 claims description 2
- 229910001870 ammonium persulfate Inorganic materials 0.000 claims description 2
- 125000002490 anilino group Chemical group [H]N(*)C1=C([H])C([H])=C([H])C([H])=C1[H] 0.000 claims description 2
- 235000015165 citric acid Nutrition 0.000 claims description 2
- 238000001879 gelation Methods 0.000 claims description 2
- 238000010438 heat treatment Methods 0.000 claims description 2
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- IUVKMZGDUIUOCP-BTNSXGMBSA-N quinbolone Chemical compound O([C@H]1CC[C@H]2[C@H]3[C@@H]([C@]4(C=CC(=O)C=C4CC3)C)CC[C@@]21C)C1=CCCC1 IUVKMZGDUIUOCP-BTNSXGMBSA-N 0.000 claims description 2
- CHQMHPLRPQMAMX-UHFFFAOYSA-L sodium persulfate Substances [Na+].[Na+].[O-]S(=O)(=O)OOS([O-])(=O)=O CHQMHPLRPQMAMX-UHFFFAOYSA-L 0.000 claims description 2
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- KXGFMDJXCMQABM-UHFFFAOYSA-N 2-methoxy-6-methylphenol Chemical compound [CH]OC1=CC=CC([CH])=C1O KXGFMDJXCMQABM-UHFFFAOYSA-N 0.000 description 3
- 229920001807 Urea-formaldehyde Polymers 0.000 description 3
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- ISWSIDIOOBJBQZ-UHFFFAOYSA-N Phenol Chemical compound OC1=CC=CC=C1 ISWSIDIOOBJBQZ-UHFFFAOYSA-N 0.000 description 2
- 229920002873 Polyethylenimine Polymers 0.000 description 2
- XFJRTXJMYXFAEE-UHFFFAOYSA-K [Cr+3].CC(O)C([O-])=O.CC(O)C([O-])=O.CC(O)C([O-])=O Chemical compound [Cr+3].CC(O)C([O-])=O.CC(O)C([O-])=O.CC(O)C([O-])=O XFJRTXJMYXFAEE-UHFFFAOYSA-K 0.000 description 2
- 239000002253 acid Substances 0.000 description 2
- GZCGUPFRVQAUEE-SLPGGIOYSA-N aldehydo-D-glucose Chemical compound OC[C@@H](O)[C@@H](O)[C@H](O)[C@@H](O)C=O GZCGUPFRVQAUEE-SLPGGIOYSA-N 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 2
- UBFMILMLANTYEU-UHFFFAOYSA-H chromium(3+);oxalate Chemical compound [Cr+3].[Cr+3].[O-]C(=O)C([O-])=O.[O-]C(=O)C([O-])=O.[O-]C(=O)C([O-])=O UBFMILMLANTYEU-UHFFFAOYSA-H 0.000 description 2
- QWWLTGUEZNQHMO-UHFFFAOYSA-H chromium(3+);propanedioate Chemical compound [Cr+3].[Cr+3].[O-]C(=O)CC([O-])=O.[O-]C(=O)CC([O-])=O.[O-]C(=O)CC([O-])=O QWWLTGUEZNQHMO-UHFFFAOYSA-H 0.000 description 2
- PYXSPTLIBJZHQW-UHFFFAOYSA-K chromium(3+);propanoate Chemical compound [Cr+3].CCC([O-])=O.CCC([O-])=O.CCC([O-])=O PYXSPTLIBJZHQW-UHFFFAOYSA-K 0.000 description 2
- WYYQVWLEPYFFLP-UHFFFAOYSA-K chromium(3+);triacetate Chemical compound [Cr+3].CC([O-])=O.CC([O-])=O.CC([O-])=O WYYQVWLEPYFFLP-UHFFFAOYSA-K 0.000 description 2
- 238000010586 diagram Methods 0.000 description 2
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- 230000006641 stabilisation Effects 0.000 description 2
- 238000011105 stabilization Methods 0.000 description 2
- SMZOUWXMTYCWNB-UHFFFAOYSA-N 2-(2-methoxy-5-methylphenyl)ethanamine Chemical compound COC1=CC=C(C)C=C1CCN SMZOUWXMTYCWNB-UHFFFAOYSA-N 0.000 description 1
- NIXOWILDQLNWCW-UHFFFAOYSA-N 2-Propenoic acid Natural products OC(=O)C=C NIXOWILDQLNWCW-UHFFFAOYSA-N 0.000 description 1
- RNIHAPSVIGPAFF-UHFFFAOYSA-N Acrylamide-acrylic acid resin Chemical compound NC(=O)C=C.OC(=O)C=C RNIHAPSVIGPAFF-UHFFFAOYSA-N 0.000 description 1
- 229920002126 Acrylic acid copolymer Polymers 0.000 description 1
- JIGUQPWFLRLWPJ-UHFFFAOYSA-N Ethyl acrylate Chemical compound CCOC(=O)C=C JIGUQPWFLRLWPJ-UHFFFAOYSA-N 0.000 description 1
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- Addition Polymer Or Copolymer, Post-Treatments, Or Chemical Modifications (AREA)
Abstract
The invention discloses a polymer gel plugging agent suitable for a tight and fractured reservoir and a preparation method thereof, wherein the gel plugging agent comprises 3-10% of monomer main agent base solution, 0.2-0.5% of cross-linking agent, 0.5-0.7% of retarder, 0.1-0.8% of initiator and the balance of deionized water according to mass fraction; the monomer main agent base solution consists of 20-25% of three water-soluble monomers (the mass ratio of the three monomers of acrylamide, 2-acrylamide-2-methylpropanesulfonic acid and sodium acrylate is 68-78:10-12:12-20), 0.05-0.2% of polymerization inhibitor, 0.05-0.2% of retarder and the balance of deionized water. Diluting a monomer main agent base solution, adding a cross-linking agent and a retarder, finally adding an initiator to prepare a plugging agent monomer solution, and after injecting a fractured rock core, polymerizing and gelling to form a plugging agent, wherein the plugging agent has extremely low initial viscosity, is easy to inject, has adjustable gel forming time, extremely short initial coagulation and final coagulation time, has right-angle thickening characteristics, has high plugging rate and breakthrough pressure gradient, has strong action with a fracture interface, and has stable and durable action on a dense fractured oil reservoir plugging zone.
Description
Technical Field
The invention relates to the technical field of oilfield chemistry, in particular to a polymer gel plugging agent suitable for a tight fractured reservoir and a preparation method thereof.
Background
In order to solve the problems of low yield, low efficiency, low permeability and the like of oil fields, the water shutoff profile control technology in China is continuously advanced along with the actual needs, and the research and the application of the water shutoff profile control technology can be traced to the end of the 50 th century of 20 th. Because of the complexity of various bottom conditions, the oil well water shutoff is mainly used in 60 to 70 years, and the water injection well profile control technology rapidly develops along with the appearance of polymers and crosslinked gel thereof in the early 80 years. The high-strength plugging agent is mainly used for plugging water or regulating profile, and the action mechanism is mainly physical barrier type plugging. In the 90 s, the oil field enters a high water content period, and the profile control and water shutoff technology also enters a developed tripod period. The single well treatment is developed to the comprehensive treatment of blocks mainly adopting profile control and water shutoff measures. After 21 st century, the oil field is generally high in water content, primary heterogeneity of the oil reservoir and long-term water drive the heterogeneity to be further aggravated, and a hypertonic channel or a large pore canal is gradually formed in the oil layer, so that a stratum pressure field and a streamline field form a constant potential. And a water flow dominant channel is formed between the oil-water wells, so that water flooding short circuit is caused, and the water flooding development effect of the oil reservoir is seriously affected. In addition, the limitation of the current situation awareness of the high water-bearing oil reservoir is that the conventional profile control and water shutoff technology cannot meet the oil reservoir development requirement.
With the increasing difficulty of new oil field exploration and development, how to select scientific plugging materials to improve the recovery ratio of the old oil field is still a target of important attack in the future of oil field developers. In the oilfield field, fractured reservoirs are most widely distributed and most widespread. In all fractured reservoir plugging materials, gel plugging can solve the problems of rapid increase of water content and rapid reduction of well production. Therefore, the organogel has important position in the water control and oil stabilization of the old oil field as the oil field chemical profile control and water shutoff technology. At present, a plurality of polymer gels are applied in various profile control and water shutoff systems at home and abroad. In recent years, the research of polymer gel profile control and water shutoff technology has been developed, on one hand, the research and development of new products of various functional profile control and shutoff agents can be guided, and on the other hand, the on-site application can be effectively guided, so that a better application effect is achieved. In particular, the technology has important significance for realizing yield increase and stable yield of the tight fractured reservoir.
Lost circulation of fractured formations has been a troublesome problem when drilling. Particularly, the method provides higher challenges for the organogel plugging technology for improving the recovery ratio under the condition of unconventional oil reservoirs such as tight oil reservoirs. In dense oil reservoir plugging, the problems of poor injectability, slow gel forming, long gel forming time, difficult standing, easy running, uncontrollable crosslinking time, difficult plugging at a target position and the like exist. According to the invention patent CN202011022748.3, the molecular weight of the used polymer is high, the injectability in a compact fractured reservoir is difficult to meet, the concentration of the polymer is too low, the polymer skeleton molecules are less compared with the polymer with low molecular weight and high concentration under the same volume after the gel is formed at a target position, the compactness of the skeleton forming gel is poor, the stability is poor, the blocking of the target position is difficult to realize, and the embodiment shows that the breakthrough pressure is very low and the practicability is not strong. The invention patent CN201910620042.8 'a low-viscosity gel water shutoff agent resistant to high temperature and high salt' is prepared from an acrylamide-acrylic acid copolymer initial polymer and inorganic minerals, wherein the molecular weight of the copolymer initial polymer is not clear, the crosslinking component in the patent has weak crosslinking effect under the condition, so that an effective crosslinking structure is difficult to form, the viscosity is very low at a high temperature of 80 ℃, and only the added inorganic mineral powder can properly enhance the viscosity of the polymer, so that the gel after gel formation is difficult to stand to a stratum target position and is easy to be washed away by subsequent water. The invention patent ZL201811238465.5 ' polyacrylamide gel plugging agent, a preparation method and application thereof ' prepared from polyacrylamide polymer, water-soluble urea-formaldehyde resin, deoxidizer and urea compound '. The urea resin has strong rigidity, good temperature resistance, but poor flexibility, and the gel material obtained as the cross-linking agent has strong brittleness; formaldehyde is used in the gel, so that the gel has high toxicity and is not friendly to the environment; the molecular weight of the polyacrylamide polymer reaches 800-3500 ten thousand g/mol, the molecular weight is too high, and the injectability in a compact fractured reservoir is difficult to meet. The invention patent ZL201811238450.9 'high-temperature-resistant composite gel plugging agent, a preparation method and application thereof' prepares the high-temperature-resistant composite gel plugging agent, and the high-temperature-resistant composite gel plugging agent is prepared from acrylamide polymers, water-soluble phenolic resin, organic chromium, deoxidizers and urea compounds. The organic chromium is one or more of chromium acetate, chromium oxalate, chromium lactate, chromium propionate, chromium malonate and chromium citrate, and the basic chromium carbonate is not used, so that the effect of right-angle thickening is not achieved, the equipment is difficult to stand, and the equipment is easy to wash away by subsequent water. The water-soluble phenolic resin is obtained by polymerizing phenol and formaldehyde, and has high formaldehyde toxicity and is not friendly to the environment. The invention patent ZL201911249988.4 'an acid-resistant strong gel plugging agent and a preparation method thereof' is prepared from main agent acrylamide, acrylic acid, acid-resistant monomer fluorohexyl ethyl acrylate, initiator persulfate and cross-linking agent N, N-methylene bisacrylamide or (and) polyethyleneimine. The gel polymerization and the crosslinking are stepped, the gel forming performance is difficult to control, the shaft is easy to be plugged when the temperature is high, and meanwhile, the polymer is difficult to degrade due to the introduction of the fluorinated monomer unit, so that the method is not friendly to the environment. The invention patent CN202310000156.9 'a plugging agent suitable for low-permeability ultra-low-permeability fractured reservoir gel and a preparation method thereof' prepares cross-linked polymer gel from polyacrylamide polymer and cross-linking agent. Because the polymer base fluid has higher viscosity and larger injection friction resistance, the polymer can meet the injection property of medium-low permeability oil reservoirs, and can not meet the plugging requirement of dense fractured oil reservoirs for dense oil reservoirs due to the characteristics of difficult injection property, weak fluidity and the like.
In summary, how to provide a plugging agent with low initial viscosity, excellent injection capability, strong slow crosslinking capability, controllable crosslinking time, short initial setting and final setting time, and capable of more effectively preventing gas channeling and water channeling of a fractured compact oil reservoir, and the crosslinked gel plugging agent has good high pressure bearing capability, so that the plugging belt has stable and durable effect, is environment-friendly, and is a problem to be solved urgently by those skilled in the art.
Disclosure of Invention
In view of the above, the invention provides a polymer gel plugging agent suitable for a tight fractured reservoir and a preparation method thereof, which have excellent injection capability, controllable crosslinking speed and good pressure resistance, and can effectively plug water channeling, thereby improving the primary plugging success rate and the pressure bearing capability.
In order to achieve the above purpose, the invention adopts the following technical scheme:
a polymer gel plugging agent suitable for a tight fractured reservoir and a preparation method thereof are characterized in that: the gel blocking agent comprises the following components in percentage by mass:
3-10% of monomer main agent base solution; 0.2 to 0.5 percent of cross-linking agent; retarder 0.5-0.7%; initiator 0.1-0.8%; the balance of deionized water.
Preferably, the polymer gel plugging agent suitable for the tight fractured reservoir and the preparation method thereof comprise the following steps: deionized water is firstly added into a beaker, and then 20-25% of acrylamide, 2-acrylamide-2-methylpropanesulfonic acid and sodium acrylate are added, so that the mass ratio of the acrylamide to the 2-acrylamide-2-methylpropanesulfonic acid to the sodium acrylate is kept at 68-78: 10 to 12: 12-20, adding polymerization inhibitor with mass fraction of 0.05-0.2% and retarder with mass fraction of 0.05-0.2%, and fully dissolving at normal temperature to obtain monomer main agent base solution.
Preferably, the polymer gel plugging agent suitable for the tight fractured oil reservoir is characterized in that the cross-linking agent is basic chromium carbonate.
Preferably, the polymer gel plugging agent suitable for the tight fractured reservoir is characterized in that the retarder is one or more of lactic acid, citric acid, acetic acid, propionic acid and oxalic acid.
Preferably, the polymer gel plugging agent suitable for the tight fracture oil reservoir is characterized in that the initiator is one or two of ammonium persulfate, sodium persulfate and potassium persulfate.
Preferably, the monomer main agent base solution of the polymer gel plugging agent suitable for the tight and fractured oil reservoir is characterized in that the polymerization inhibitor is hydroquinone and the retarder is aniline.
The preferable technical proposal has the advantages that the gel plugging agent has excellent injection capability when not crosslinked, and is convenient for permeation to a compact fracture target stratum; AMPS contained in the monomer can not only improve the temperature resistance of the polymer, so that the base solution has a longer-lasting effect, but also enhance the adsorption performance of the polymer and rock, so that the plugging agent is standing up and is not easy to be washed away by subsequent water, and the plugging property of the polymer is improved; the cross-linking agent adopts a mixture of basic chromium carbonate and chromium citrate, so that the polymer is cross-linked more rapidly, namely, after the base solution enters a target position for cross-linking, the effective plugging of a fracture stratum is realized, and the success rate of one-time plugging and the bearing capacity are improved.
The invention also provides a preparation method of the polymer gel plugging agent suitable for the tight fractured reservoir, which comprises the following steps:
(1) Diluting the uniformly dissolved monomer main agent solution to a required mass fraction by using clear water;
(2) Then adding a cross-linking agent and a retarder in sequence to prepare a dense fractured reservoir plugging agent base solution;
(3) Heating the base solution of the plugging agent to 60-80 ℃, and finally adding an initiator, wherein the base solution undergoes polymerization reaction and gelation reaction to form the gel plugging agent.
The gel blocking agent has two sections of viscosity increasing sections, wherein the first viscosity increasing section mainly comprises the copolymerization reaction of acrylamide, AMPS and sodium acrylate monomers, the solution viscosity is increased to obtain a blocking agent polymer sol, the second viscosity increasing section mainly comprises the crosslinking reaction, namely, the crosslinking reaction of chromium ions in a mixture of basic chromium carbonate and chromium citrate and carboxyl groups in a copolymer to obtain a blocking agent polymer gel, and the static gel forming time and static gel forming strength are determined. The basic chromium carbonate adopted by the invention is completely different from organic chromium such as chromium acetate, chromium oxalate, chromium lactate, chromium propionate, chromium malonate and the like in the invention patent ZL201811238450.9 in terms of gel formation performance, and the basic chromium ions formed by the basic chromium carbonate have the effect of releasing a large amount of active chromium ions in a short time, so that the initial setting time and the final setting time are short, the basic chromium carbonate can stand fast in a short time and is not easy to be washed away by subsequent water, and the basic chromium carbonate is not provided by other invention patents such as organic chromium described in ZL201811238450.9, and is also not provided by other crosslinking agents such as phenolic resin, urea-formaldehyde resin, polyethyleneimine and the like.
And measuring the permeability of the core before plugging the core with different crack widths at a certain oil reservoir temperature, then injecting 1PV plugging agent polymeric sol into the core with different artificial crack widths, closing the inlet and outlet valves of the core, simulating Guan Jingbie pressure, waiting for a period of time, wherein the waiting time is longer than the static gel forming time, and ensuring enough time for crosslinking, so that the plugging agent polymeric sol before injection is changed into the plugging agent polymeric gel with stable viscosity. And then the stratum water is injected subsequently, when the shearing stress of the plugging agent is larger than the friction force of the plugging agent in the rock core, the plugging agent starts to flow, and a breakthrough pressure gradient is obtained at the moment to reflect the strength of the plugging agent. And finally, injecting 1PV stratum water after gel breakthrough, measuring the permeability of the water after plugging, and determining the plugging rate of the plugging agent.
The plugging agent has low viscosity in the early stage of gel formation, is favorable for meeting injectability in a tight oil reservoir, and reduces friction of the plugging agent in a shaft. The viscosity of the plugging agent is increased to 50-150mPa.s to be stable in the gelling medium period, which is favorable for reducing the penetration of the plugging agent into the rock matrix and ensuring the migration of the plugging agent in cracks. And the gel is permeated into the boundary layer of the crack and the rock, which is favorable for firm interface combination of the gel and the matrix after gel formation and improves the plugging strength. The viscosity of the plugging agent is increased to 7000-10000 Pa.s in the later gelling period, and finally, the plugging agent is stable and approaches to the strength of rigid gel, thereby being beneficial to bearing stronger pressure.
Compared with the prior art, the gel plugging agent is suitable for compact fractured reservoirs, and firstly, the gel liquid is prepared into a pure liquid phase, and the gel plugging agent is formed into four processes of polymerization delay, crosslinking delay and rapid crosslinking. The gel liquid in the early injection stage is not polymerized on the ground and a shaft, the viscosity is low, and the injectability is good; the polymerization reaction occurs in the middle period, the viscosity is increased when the temperature condition is unchanged, but when the gel liquid continuously enters the deep part of the stratum, the viscosity of the gel liquid continuously heated is reduced, so that a dynamic balance is achieved, the viscosity is lower, and the injectability can be ensured; then delayed crosslinking occurs to ensure that the glue solution can flow into the target layer; the low viscosity becomes very high in a very short time, and stands up quickly at the target position, so that the plugging capability is strong.
The gel liquid has excellent slow crosslinking capability and controllable crosslinking time, so that the gel liquid has excellent injection capability, short initial setting and final setting time, and can more effectively press and stabilize stratum to prevent oil, gas and water channeling; the gel after crosslinking has good high pressure bearing capacity, so that the plugging band has stable and durable action and high practical value.
The invention also provides a preparation method of the polymer gel plugging agent for the tight fractured reservoir, which is characterized in that the concentration of the retarder can effectively control the initial setting time of the gel plugging agent, the concentration of the cross-linking agent can enable the initial setting time to change within 5-15min, and the gel plugging agent has the characteristic of right-angle thickening.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings that are required to be used in the embodiments or the description of the prior art will be briefly described below, and it is obvious that the drawings in the following description are only embodiments of the present invention, and that other drawings can be obtained according to the provided drawings without inventive effort for a person skilled in the art.
FIG. 1 is a static gel-forming chart of a gel plugging agent prepared in examples 01-05 of the present invention
FIG. 2 is a static gel-forming chart of the gel plugging agent prepared in examples 06-10 of the invention
Detailed Description
The technical solutions of the embodiments of the present invention will be clearly and completely described below in conjunction with the embodiments of the present invention, and it is apparent that the described embodiments are only some embodiments of the present invention, not all embodiments. All other embodiments, which can be made by those skilled in the art based on the embodiments of the invention without making any inventive effort, are intended to be within the scope of the invention.
And (5) breaking through the measurement of the pressure gradient. The breakthrough pressure gradient reflects the plugging strength of the plugging agent, and the larger the value is, the higher the strength of the plugging agent is. The breakthrough pressure gradient is related to the crosslinking degree of the plugging agent and the capability of the plugging agent to adhere to the rock, and is an important parameter for calculating the dosage of the plugging agent and determining the length of a plug of the plugging agent. In the core filled with the plugging agent, the plugging agent in the core is pressurized by the formation water of the pressure transmission medium, and when the shear stress of the plugging agent is greater than the friction force of the plugging agent in the core, the plugging agent starts to flow. The breakthrough pressure gradient refers to the maximum breakthrough pressure in a porous medium of unit length, and the magnitude of the breakthrough pressure gradient that can reflect the strength of the plugging agent can be calculated from formula (1):
wherein: p (P) L Breaking through the pressure gradient, MPa/m;
P max -maximum bearing pressure, MPa;
l is the length of the plug and m;
and (5) measuring the plugging rate. The plugging rate can reflect the plugging capability of the plugging agent, and the plugging performance of the plugging agent is better as the plugging rate is higher. After the plugging agent is measured to break through the pressure gradient, stratum water 1PV is continuously injected into the rock core according to the same direction and flow. The plugging rate of the plugging agent is calculated by combining the formula (2), and the specific operation is as follows:
1) The diameter d and the effective length L of the core were measured at different positions on the core with a vernier caliper.
2) According to the instrument operation rules, the rock core is correctly filled, the confining pressure of the rock core holder is slowly increased to 5MPa, then a valve of a stratum water intermediate container is opened to continuously inject simulated stratum water into the rock core, and the injection rate is kept at 0.5mL/min; recording the pressure difference delta P at two ends of the core after stabilization, and calculating the water permeability K of the core according to the Darcy seepage formula (3) w1 。
K in the formula w Core water permeability, μm 2 ；
Q-flow of displacement fluid through core at displacement pressure, cm 3 /s；
L is the length of the core, cm;
mu-viscosity of the displacement fluid, mPa.s;
a-cross-sectional area of core, cm 2 ；
Δ p -pressure difference of displacement fluid before and after passing through the rock core, and MPa;
3) And (3) injecting a certain amount of polymer gel plugging agent into the core holder at the same speed, and preserving the temperature for a period of time at a certain temperature to completely gel.
4) After stratum water is injected subsequently and the pressure is stabilized again, the permeability K after water flooding is calculated through a Darcy seepage formula w2 And finally, calculating the change rate of the permeability before and after the water flooding through a formula (3) to obtain the plugging rate.
η in the formula-blocking rate,%;
k w1 water permeability of core after initial water flooding, μm 2 ；
k w2 Water permeability of core after water flooding again, μm 2 ；
Examples 01 to 05
Firstly, 15.6 g of acrylamide, 2g of 2-acrylamide-2-methylpropanesulfonic acid and 2.4 g of sodium acrylate (the mass ratio of the three is 78:10:12) are added into a beaker containing 79.4 g of deionized water, and after the components are completely dissolved at normal temperature, 0.05 g of polymerization inhibitor hydroquinone and 0.05 g of retarder aniline are respectively obtained to obtain a monomer main agent base solution. Diluting the uniformly dissolved monomer main agent base solution to a solution with the mass fraction of 8% of the monomer by using deionized water, respectively adding 0.3g of cross-linking agent basic chromium carbonate, 0.2g of cross-linking agent chromium citrate and 0.7g of retarder lactic acid after complete dissolution to prepare a plugging agent monomer solution, adding 0.5g of initiator potassium persulfate, standing at the oil reservoir temperature of 60 ℃ for 10 hours, and monitoring the change condition of the viscosity of the plugging agent along with time on line in real time, wherein the situation is shown in an attached figure 1. The first stage is a polymerization inhibition stage, and polymerization inhibitor inhibits polymerization reaction, the polymerization inhibition time reaches 1 hour, and the viscosity is not increased. The second section is a polymerization section, which is a copolymerization reaction of acrylamide and sodium acrylate monomer, the polymerization section is carried out for 2 hours, the viscosity is slowly increased to 10.3mPa.s in the first 1 hour, and the retarder plays a key role; after the last 1 hour, the viscosity rapidly increased from 10.3mPa.s to 115mPa.s, which is a key role of the initiator, resulting in a plugging agent polymer sol. The third section is a retarding section, the viscosity is not increased, and mainly retarder lactic acid plays a key role, so that the crosslinking reaction is inhibited. The fourth section is a quick setting section, the viscosity is rapidly increased from 115mPa.s to 8276mPa.s in 18min, the state of motionless gel is achieved in a very short time, the right-angle thickening effect is achieved, and the crack is easy to stand. The main reason is that the carboxyl groups in the basic chromium ions and the chromium citrate and copolymer are rapidly crosslinked to obtain the plugging agent polymer gel. The static gel forming time reaches 8 hours and 18 minutes, the initial setting time is only 18 minutes, the initial setting time and the final setting time are very short, the gel forming strength reaches 8276mPa.s, the gel forming strength is high, and the capability of plugging cracks is strong.
FIG. 1 static gel-forming diagram of gel blocking agent prepared in examples 01-05 of the present invention
( Fig. 1 illustrates: the gel blocking agent reaction time is a polymerization inhibition section within 0-1h, no polymerization reaction occurs, and the viscosity is not increased; the reaction time is a polymerization section when 1-3 hours, the monomer undergoes polymerization reaction, and the viscosity is increased; the reaction time is a retarding section when 3-8 hours, the crosslinking is inhibited, the crosslinking is very weak, and the viscosity is slightly increased; the reaction time is a quick setting section when 8-8.25 hours, and after the polymer is crosslinked within 15 minutes, the viscosity is increased to the maximum value, thereby being beneficial to effective plugging of cracks. )
The permeability of the original core (diameter 2.52cm, length 4.99 cm) was measured at 60℃and was 0.08mD, and the water permeability before plugging of cores with crack widths of 100 μm, 200 μm, 400 μm, 800 μm and 1600 μm, respectively, are shown in Table 1. And then the prepared 1PV plugging agent monomer solution is injected into cores with crack widths of 100 mu m, 200 mu m, 400 mu m, 800 mu m and 1600 mu m respectively, the inlet and outlet valves of the cores are closed, guan Jingbie pressure is simulated, the plugging agent monomer solution is cured for 8.5 hours, and the plugging agent monomer solution becomes a plugging agent polymer gel. And then the stratum water is injected subsequently, when the shear stress of the plugging agent is larger than the viscous resistance of the plugging agent in the rock core, the plugging agent starts to flow, and a breakthrough pressure gradient is obtained. And finally, injecting 1PV stratum water after gel breakthrough, and measuring the permeability of the water after plugging. The breakthrough pressure gradient and the plugging rate were calculated by formulas (1) and (3), and the results are shown in table 1.
TABLE 1 breakthrough pressure gradient and blocking Rate for examples 01-05
Examples 06 to 10
13.6 g of acrylamide, 2.4 g of 2-acrylamide-2-methylpropanesulfonic acid and 4 g of sodium acrylate (the mass ratio of the three is 68:12:20) are added into a beaker containing 78.3 g of deionized water, and after the components are completely dissolved at normal temperature, 0.2g of polymerization inhibitor hydroquinone and 0.05 g of retarder aniline are respectively obtained to obtain a monomer main agent. Diluting the uniformly dissolved monomer main agent base solution to a solution with the mass fraction of 6% of the monomer by using deionized water, adding 0.2g of cross-linking agent basic chromium carbonate, 0.1g of cross-linking agent chromium citrate and 0.5g of retarder citric acid respectively after complete dissolution to prepare a plugging agent monomer solution, adding 0.6 g of initiator potassium persulfate, standing at the oil reservoir temperature of 80 ℃ for 10 hours, and monitoring the change condition of the viscosity of the plugging agent with time on line in real time, as shown in figure 2. The first stage is a polymerization inhibition stage, and polymerization inhibitor inhibits polymerization reaction, the polymerization inhibition time reaches 2 hours, and the viscosity is not increased. The second stage is a polymerization stage, which is a copolymerization reaction of acrylamide and sodium acrylate monomer, the polymerization stage is carried out for 1.5 hours, the viscosity is linearly increased to 88.0 Pa.s, and the retarder and the initiator play a key role, so as to obtain a plugging agent solution. The third section is a retarding section, the viscosity is not increased, and mainly retarder lactic acid plays a key role, so that the crosslinking reaction is inhibited. The fourth section is that the viscosity is rapidly increased, the viscosity of the plugging agent is rapidly increased from 88.0 Pa.s to 7405mPa.s in 12min, the state of motionless gel is achieved in a very short time, the effect of right-angle thickening is achieved, and the plugging agent is easy to stand in cracks. The main reason is that the basic chromium ions released by the basic chromium carbonate are crosslinked with carboxyl groups in the copolymer to obtain the plugging agent polymer gel, the static gel forming time is up to 5 hours and 42 minutes, the initial setting time to final setting time is only 12 minutes, the initial setting time to final setting time is very short, the gel forming strength is up to 7405mPa.s, the gel forming strength is high, and the capability of plugging cracks is strong.
FIG. 2 static gel-forming diagram of gel plugging agent prepared in examples 06-10 of the invention
( Fig. 2 illustrates: the gel blocking agent reaction time is a polymerization inhibition section within 0-2h, no polymerization reaction occurs, and the viscosity is not increased; the reaction time is 2-3.5h, the polymerization section is adopted, the monomer is subjected to polymerization reaction, and the viscosity is increased; the reaction time is a retarding section when 3.5-5.5 hours, the crosslinking is inhibited, the crosslinking is very weak, and the viscosity is slightly increased; the reaction time is a quick setting section when 5.5-5.7 hours, and the polymer is crosslinked within 12 minutes, so that the viscosity is increased to the maximum value, and the effective plugging of cracks is facilitated. )
The permeability of the original core was measured at 70℃to 0.05mD (diameter: 2.50cm, length: 5.0 cm), the pre-plugging water permeabilities of cores with crack widths of 100 μm, 200 μm, 400 μm, 800 μm and 1600 μm, respectively, were shown in Table 2, and then the prepared 1PV plugging agent monomer solution was injected into cores with different artificial crack widths, the inlet and outlet valves of the cores were closed, the pressure was simulated for Guan Jingbie, and the plugging agent monomer solution was weathered for 6.5 hours to become a plugging agent polymer gel. And then the stratum water is injected subsequently, when the shearing stress of the plugging agent is larger than the friction force of the plugging agent in the rock core, the plugging agent starts to flow, and a breakthrough pressure gradient is obtained. And finally, injecting 1PV stratum water after gel breakthrough, and measuring the permeability of the water after plugging. The breakthrough pressure gradient and the plugging rate were calculated by formulas (1) and (3), and the results are shown in table 2.
TABLE 2 breakthrough pressure gradients and blocking Rate for examples 06-10
Claims (7)
1. A polymer gel plugging agent suitable for a tight fractured reservoir and a preparation method thereof are characterized in that: the gel blocking agent comprises the following components in percentage by mass:
3-10% of monomer main agent base solution;
0.2 to 0.5 percent of cross-linking agent;
retarder 0.5-0.7%;
initiator 0.1-0.8%;
the balance being ionized water.
2. The gel plugging agent suitable for tight fracture oil reservoirs according to claim l, wherein the monomer main agent base solution and the preparation method are as follows: deionized water is firstly added into a beaker, and then 20-25% of acrylamide, 2-acrylamide-2-methylpropanesulfonic acid and sodium acrylate vinyl monomer are added, so that the mass ratio of the acrylamide to the 2-acrylamide-2-methylpropanesulfonic acid to the sodium acrylate is kept at 68-78: 10 to 12: 12-20, adding polymerization inhibitor with mass fraction of 0.05-0.2% and retarder with mass fraction of 0.05-0.2%, and fully dissolving at normal temperature to obtain monomer main agent base solution.
3. The gel plugging agent for tight fracture reservoirs of claim 1, wherein the cross-linking agent is a mixture of basic chromium carbonate and chromium citrate.
4. The gel plugging agent suitable for tight fracture oil reservoirs according to claim 1, wherein the retarder is one or more of lactic acid, citric acid, acetic acid, propionic acid and oxalic acid.
5. The monomer main agent suitable for a gel plugging agent for a tight fracture oil reservoir according to claim 1, wherein the initiator is one or two of ammonium persulfate, sodium persulfate and potassium persulfate.
6. The gel plugging agent for tight fracture oil reservoirs according to claim 2, wherein the polymerization inhibitor is hydroquinone and the retarder is aniline.
7. The tight fracture oil reservoir gel plugging agent of any one of claims 1-6, wherein the preparation method comprises the following steps:
(1) Diluting the uniformly dissolved monomer main agent solution to a required mass fraction by using clear water;
(2) Then adding a cross-linking agent and a retarder in sequence to prepare a dense fractured reservoir plugging agent base solution;
(3) Heating the base solution of the plugging agent to 60-80 ℃, and finally adding an initiator, wherein the base solution undergoes polymerization reaction and gelation reaction to form the gel plugging agent.
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