CN105443104B - Polymer flooding blocks method for removing blockage after well acidizing - Google Patents
Polymer flooding blocks method for removing blockage after well acidizing Download PDFInfo
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Abstract
The present invention provides a kind of polymer flooding and blocks method for removing blockage after well acidizing, and methods described is carried out as follows：A. blocked to the polymer flooding after acidifying in well and inject detergent, the stratum around pit shaft is pre-processed, disposes the crude oil not soluble in water on tamper surface, is easy to the water-soluble inorganic agent in subsequent step to be had an effect with tamper；Described detergent is the compound system of a variety of surfactant compositions, and it is 20 30m that weight concentration, which is generally 0.1 0.5%, usage amount,3；B. the cross-linked gel degradation agent aqueous solution that the weight concentration to the sour equivalent injected when blocking injection in well and being previously acidified is 5~10%, injection terminate, and closing well drives a well after one day；C. to the compound depolymerizing agent aqueous solution that injection weight concentration is 6~10% in well is blocked, tamper de-plugging efficiency high, de-plugging is thorough, and it is invalid using other method for removing blockage to solve the problems, such as, is easily prepared on various chemical solution mining sites, with high safety reliable, convenient.
Description
Technical field：
The present invention relates to polymer flooding to block well method for removing blockage, more particularly to a kind of polymer flooding blocks de-plugging after well acidizing
Method.
Background technology：
During water flooding, the anisotropism of oil reservoir and unfavorable mobility ratio cause water drive sweep efficiency compared with
It is low.Polymer can significantly increase the viscosity of injection fluid, the mobility for improving injection fluid, improve water drive sweep efficiency, from
And finally improve oil recovery factor.Because the main component of reservoir minerals is oxide, silicate etc., these mineral surfaces are present
Substantial amounts of epoxide, hydroxy and metal group, have stronger attraction so that polymer occurs in porous media with polymer
Adsorption And Retention；Denaturation can also occur in ground environment for the polymer of injection；It is also attached in pit shaft to dissolve bad polymer
Nearly accumulation.These, can all cause the blocking of injection well, often result in follow-up polymer because injection pressure improves rapidly and notes not
Enter.In order that polymer injection rate reach design requirement, using acid solution corrosion and to stratum squeeze sour when waterpower make
With, release oil-gas Layer and block, expand and connect oil reservoir hole, recovery and the permeability for improving oil-gas Layer near wellbore zone；It is but big
Measure mining site practice have shown that：The poly- blocking well of note that injection acid is acidified, acidifying can not release polymer flooding and block the stifled of well at all
Plug, acidifying are invalid.Therefore, inventing a kind of polymer flooding blocks method for removing blockage after well acidizing.
Acidifying be using acid solution to rock cement dissolving and corrosion, recover or improve formation pore permeability,
But for the blocking well for polymer flooding, the acid solution on stratum is injected, it can not only be reacted with the cement of rock, moreover,
Under formation temperature, by certain time, moreover it is possible to had an effect with polymer and generate precipitation, cause stratum to generate tamper again.
The sediment is extremely stable in the earth formation, and the depolymerizing agent of degradation polymer can not cause it to degrade.What polymer flooding used
Partially hydrolyzed polyacrylamide (PHPA) or hydrophobic associated polymer, contain amide groups in macromolecular chain, amide groups is sent out under the action of an acid
Intermolecular imidization reaction easily occurs for unboiled water solution, hydrolysate, generates stable cross-linked gel not soluble in water, easily makes
Into formation blockage.After polymer flooding blocks well acidizing, formation blockage species are not reduced not only, also add a kind of cross-linked gel
Tamper.
The content of the invention：
The purpose of the present invention is intended to overcome the deficiencies in the prior art, there is provided a kind of polymer flooding that effectively releases blocks well acidizing
Blocking afterwards, and de-plugging efficiency high, thoroughly, easily prepared on various chemical solution mining sites, the polymer flooding of safe operation blocks up
Method for removing blockage after plug well acidizing.
The purpose of the present invention can be achieved by the following technical measures：
Method for removing blockage is carried out as follows after polymer flooding of the present invention blocks well acidizing：
A. blocked to the polymer flooding after acidifying in well and inject detergent, the stratum around pit shaft pre-processed, clearly
The crude oil not soluble in water on tamper surface is removed, is easy to the water-soluble inorganic agent in subsequent step to be had an effect with tamper；
Described detergent is the compound system of a variety of surfactant compositions, and weight concentration is generally 0.1-0.5%, usage amount is
20-30m3；
B. the cross-linked gel that the weight concentration to the sour equivalent injected when blocking injection in well and being previously acidified is 5~10%
The degradation agent aqueous solution, injection terminate, and closing well drives a well after one day；
C. it is 6~10% compound depolymerizing agent aqueous solution, the compound depolymerizing agent aqueous solution to injection weight concentration in well is blocked
Dosage is according to formula W=π r2H Φ η are calculated,
In formula：W --- compound depolymerizing agent solution usage (m)3；
R --- treatment radius (m), usually 2-5 rice；
H --- processing core intersection (m)；
Φ --- formation porosity (%)；
η --- compound depolymerizing agent use level coefficient, generally take 1~2；
Injection terminates, after closing well reacts 1 day, opening well and making production.
The purpose of the present invention can be also achieved by the following technical measures：
Further, the detergent described in a steps takes lauryl sodium sulfate, neopelex, dodecyl
Polyoxyethylene ether, trimethyl Nonyl pheno base ether, one kind in sorbitan monostearate or its two kinds and
The two or more mixtures arbitrarily matched are dissolved in clear water, and manufactured weight concentration is 0.1~0.5% aqueous solution.
Further, the detergent described in a steps is first according to lauryl sodium sulfate：Neopelex：
Dodecyl polyoxyethylene ether：Trimethyl Nonyl pheno base ether：Sorbitan monostearate=0.2~1：
0.2~1：0.2~1：0.2~1：0.2~1 weight is mixed, and then the mixture is dissolved in clear water again, manufactured
Weight concentration is 0.1~0.5% aqueous solution.
Further, the detergent described in a steps is first according to lauryl sodium sulfate：Neopelex：
Dodecyl polyoxyethylene ether：Trimethyl Nonyl pheno base ether：Sorbitan monostearate=0.7~0.9：
0.7~0.9：0.7~0.9：0.7~0.9：0.7~0.9 weight is mixed, and the mixture then is dissolved in into clear water again
In, manufactured weight concentration is 0.3~0.4% aqueous solution.
Further, the cross-linked gel degradation agent described in b step include sodium phosphate, sodium pyrophosphate, one kind in ammoniacal liquor or
Its two kinds and three kinds of mixtures arbitrarily matched.
Further, the cross-linked gel degradation agent described in b step is according to sodium phosphate：Sodium pyrophosphate：Ammoniacal liquor=1:0.2
~1.1:The mixture that 0.2~3 weight mixes.
Further, the cross-linked gel degradation agent described in b step is according to sodium phosphate：Sodium pyrophosphate：Ammoniacal liquor=1:0.8
~1.0:The mixture that 2.0~2.3 weights mix.
Injection described in step c is carried out in the case of no more than maximum injection pressure 20MPa, and use is as big as possible
Discharge capacity.
Compound depolymerizing agent of the present invention is current city's pin product, as Sinopec Group wins
The compound depolymerizing agents of DJD-A of oilfield branch petroleum works Institute for Research and Technology production.
Using the present invention, it is invalid to tamper de-plugging using other method for removing blockage thoroughly to solve the problems, such as, tamper solution
Stifled efficiency high, de-plugging is thorough, and various chemical solutions are easily prepared on production mining site, simple to operate, securely and reliably.
Applicant selects certain injection well of Shengli Oil Field to do ASP flooding test, well injection a period of time polymer solution
Afterwards, stop noting due to blocking, using acidifying de-plugging, this time acidizing effect is bad, and rear to carry out second of acidifying de-plugging again, effect is still
It is so bad, it is bad to illustrate that polymer flooding blocks the method plugging removal effect that well is acidified.
Polymer flooding after being acidified using the present invention in July, 2014 blocks the de-plugging of well:
The first step, 20m is injected into well30.4% surfactant solution, wherein surfactant is neopelex,
Solution is prepared with clear water；
Second step, 50m is then injected into well3(previous acidifying 50m3Acid solution), concentration be 8% cross-linked gel drop
Agent solution is solved, it is 1 that wherein cross-linked gel degradation agent, which is sodium phosphate, sodium pyrophosphate, weights of ammonia part matches:1:1 mixes；It is molten
Liquid is prepared with clear water, and closing well drives a well after one day, is carried out in next step；
3rd step, in the case of no more than maximum injection pressure 20MPa, use discharge capacity as big as possible is continuous into well
Inject the compound depolymerizing agent aqueous solution 70m that weight concentration is 8.5%3, allow compound depolymerization agent solution quickly to enter stratum and draw with underground
The material blocked is acted to react.Compound depolymerizing agent injection dosage design is as shown in table 1.After closing well reacts 1 day, drive a well and given birth to
Production.
The dosage design of 1 compound depolymerizing agent of table
It will be seen from figure 1 that after the completion of the well construction, in July, 2014 in April, 2015, opening well and making production 9 months, normally
During production, day fluence reach 80m3, using the method for the invention, de-plugging after polymer flooding well acidizing, effect highly significant, ensure that
The normal development of polymer flooding.
Brief description of the drawings：
Fig. 1 is certain injection well productive experiment curve map of Shengli Oil Field.
It will be seen from figure 1 that after the completion of the well construction, in July, 2014 in April, 2015, opening well and making production 9 months, normally
During production, day fluence reach 80m3, using the method for the invention, de-plugging after polymer flooding well acidizing, effect highly significant, ensure that
The normal development of polymer flooding.
Embodiment：
Embodiment 1：
The method for removing blockage is carried out as follows：
A. blocked to the polymer flooding after acidifying injected in well lauryl sodium sulfate weight concentration be 0.1% it is water-soluble
Liquid, the stratum around pit shaft is pre-processed, dispose the crude oil not soluble in water on tamper surface；
B. it is water-soluble for 5% sodium phosphate to the weight concentration for blocking sour equivalent of the injection with being injected during previously acidifying in well
Liquid, injection terminate, and closing well drives a well after one day；
C. in the case of no more than maximum injection pressure 20MPa, use discharge capacity as big as possible is injected into blocking well
Weight concentration is the 10% compound depolymerizing agent aqueous solution, and compound depolymerizing agent amount of aqueous solution used is according to formula W=π r2H Φ η are calculated,
In formula：W --- compound depolymerizing agent solution usage (m3)；
R --- treatment radius (m), take 2m；
H --- processing core intersection (m)；
Φ --- formation porosity (%)；
η --- compound depolymerizing agent use level coefficient, take 2；
Injection terminates, after closing well reacts 1 day, opening well and making production.
Embodiment 2：
The method for removing blockage is carried out as follows：
A. blocked to the polymer flooding after acidifying injected in well lauryl sodium sulfate weight concentration be 0.5% it is water-soluble
Liquid, the stratum around pit shaft is pre-processed, dispose the crude oil not soluble in water on tamper surface；
B. it is water-soluble for 10% sodium phosphate to the weight concentration for blocking sour equivalent of the injection with being injected during previously acidifying in well
Liquid, injection terminate, and closing well drives a well after one day；
C. in the case of no more than maximum injection pressure 20MPa, use discharge capacity as big as possible is injected into blocking well
Weight concentration is the 6% compound depolymerizing agent aqueous solution, and compound depolymerizing agent amount of aqueous solution used is according to formula W=π r2H Φ η are calculated,
In formula：W --- compound depolymerizing agent solution usage (m3)；
R --- treatment radius (m), take 5m；
H --- processing core intersection (m)；
Φ --- formation porosity (%)；
η --- compound depolymerizing agent use level coefficient, take 1；
Injection terminates, after closing well reacts 1 day, opening well and making production.
Embodiment 3：
The method for removing blockage is carried out as follows：
A. blocked to the polymer flooding after acidifying injected in well lauryl sodium sulfate weight concentration be 0.3% it is water-soluble
Liquid, the stratum around pit shaft is pre-processed, dispose the crude oil not soluble in water on tamper surface；
B. it is water-soluble for 7% sodium phosphate to the weight concentration for blocking sour equivalent of the injection with being injected during previously acidifying in well
Liquid, injection terminate, and closing well drives a well after one day；
C. in the case of no more than maximum injection pressure 20MPa, use discharge capacity as big as possible is injected into blocking well
Weight concentration is the 8% compound depolymerizing agent aqueous solution, and compound depolymerizing agent amount of aqueous solution used is according to formula W=π r2H Φ η are calculated,
In formula：W --- compound depolymerizing agent solution usage (m3)；
R --- treatment radius (m), take 3m；
H --- processing core intersection (m)；
Φ --- formation porosity (%)；
η --- compound depolymerizing agent use level coefficient, take 1.5；
Injection terminates, after closing well reacts 1 day, opening well and making production.
Embodiment 4：
Lauryl sodium sulfate is substituted with neopelex, it is other respectively with embodiment 1-3.
Embodiment 5：
Lauryl sodium sulfate is substituted with dodecyl polyoxyethylene ether, it is other respectively with embodiment 1-3.
Embodiment 6：
Lauryl sodium sulfate is substituted with trimethyl Nonyl pheno base ether, it is other respectively with embodiment 1-3.
Embodiment 7：
Lauryl sodium sulfate is substituted with sorbitan monostearate, it is other respectively with embodiment 1-3.
Embodiment 8：
Use lauryl sodium sulfate：Neopelex=0.2：The mixture that 1 weight mixes replaces
It is other respectively with embodiment 1-3 for lauryl sodium sulfate.
Embodiment 9：
Use lauryl sodium sulfate：Neopelex=1：The mixture that 0.2 weight mixes replaces
It is other respectively with embodiment 1-3 for lauryl sodium sulfate.
Embodiment 10：
With dodecyl polyoxyethylene ether：Trimethyl Nonyl pheno base ether=1：0.2 weight mixes
The mixture replacing lauryl sodium sulfate formed, it is other respectively with embodiment 1-3.
Embodiment 11：
With dodecyl polyoxyethylene ether：Trimethyl Nonyl pheno base ether=0.2：1 weight mixes
The mixture replacing lauryl sodium sulfate formed, it is other respectively with embodiment 1-3.
Embodiment 12：
With trimethyl Nonyl pheno base ether：Sorbitan monostearate=1：0.2 weight mixes
The mixture replacing lauryl sodium sulfate formed, it is other respectively with embodiment 1-3.
Embodiment 13：
With trimethyl Nonyl pheno base ether：Sorbitan monostearate=0.2：1 weight mixes
The mixture replacing lauryl sodium sulfate formed, it is other respectively with embodiment 1-3.
Embodiment 14：
With dodecyl polyoxyethylene ether：Sorbitan monostearate=1：0.2 weight mixes
Mixture replacing lauryl sodium sulfate, it is other respectively with embodiment 1-3.
Embodiment 15：
With dodecyl polyoxyethylene ether：Sorbitan monostearate=0.2：1 weight mixes
Mixture replacing lauryl sodium sulfate, it is other respectively with embodiment 1-3.
Embodiment 16：
Use neopelex：Trimethyl Nonyl pheno base ether：Sorbitan monostearate=1：
0.2：The mixture replacing lauryl sodium sulfate that 1 weight mixes, it is other respectively with embodiment 1-3.
Embodiment 17：
Use neopelex：Trimethyl Nonyl pheno base ether：Sorbitan monostearate=
0.2：1：The mixture replacing lauryl sodium sulfate that 0.2 weight mixes, it is other respectively with embodiment 1-3.
Embodiment 18：
Use neopelex：Dodecyl polyoxyethylene ether：Trimethyl Nonyl pheno base ether：Sorb
Sugar alcohol acid anhydride monostearate=1：0.2：1：The mixture replacing lauryl sodium sulfate that 0.2 weight mixes, its
It is respectively the same as embodiment 1-3.
Embodiment 19：
Use neopelex：Dodecyl polyoxyethylene ether：Trimethyl Nonyl pheno base ether：Sorb
Sugar alcohol acid anhydride monostearate=0.2：1：0.2：The mixture replacing lauryl sodium sulfate that 1 weight mixes, its
It is respectively the same as embodiment 1-3.
Embodiment 20：
Use lauryl sodium sulfate：Neopelex：Trimethyl Nonyl pheno base ether：Sorbitan
Monostearate=1：0.2：1：The mixture replacing lauryl sodium sulfate that 0.2 weight mixes, other difference
With embodiment 1-3.
Embodiment 21：
Use lauryl sodium sulfate：Neopelex：Trimethyl Nonyl pheno base ether：Sorbitan
Monostearate=0.2：1：0.2：The mixture replacing lauryl sodium sulfate that 1 weight mixes, other difference
With embodiment 1-3.
Embodiment 22：
Use lauryl sodium sulfate：Neopelex：Dodecyl polyoxyethylene ether：Trimethyl nonyl phenol gathers
Oxyethylene group ether：Sorbitan monostearate=1：0.2：1：0.2：The mixture replacing that 1 weight mixes
Lauryl sodium sulfate, it is other respectively with embodiment 1-3.
Embodiment 23：
Use lauryl sodium sulfate：Neopelex：Dodecyl polyoxyethylene ether：Trimethyl nonyl phenol gathers
Oxyethylene group ether：Sorbitan monostearate=0.2：1：0.2：1：The mixture that 0.2 weight mixes replaces
It is other respectively with embodiment 1-3 for lauryl sodium sulfate.
Embodiment 24：
Use lauryl sodium sulfate：Neopelex：Dodecyl polyoxyethylene ether：Trimethyl nonyl phenol gathers
Oxyethylene group ether：Sorbitan monostearate=0.7：0.9：0.7：0.9：The mixing that 0.7 weight mixes
Thing substitute lauryl sodium sulfate, then the mixture is dissolved in clear water again, manufactured weight concentration be 0.3% it is water-soluble
Liquid, it is other respectively with embodiment 1-3.
Embodiment 25：
Use lauryl sodium sulfate：Neopelex：Dodecyl polyoxyethylene ether：Trimethyl nonyl phenol gathers
Oxyethylene group ether：Sorbitan monostearate=0.9：0.7：0.9：0.7：The mixing that 0.9 weight mixes
Thing substitute lauryl sodium sulfate, then the mixture is dissolved in clear water again, manufactured weight concentration be 0.4% it is water-soluble
Liquid, it is other respectively with embodiment 1-3.
Embodiment 26：
Sodium phosphate is substituted with sodium pyrophosphate, it is other respectively with embodiment 1-25.
Embodiment 27：
Sodium phosphate is substituted with ammoniacal liquor, it is other respectively with embodiment 1-25.
Embodiment 28：
Use sodium phosphate：Sodium pyrophosphate：Ammoniacal liquor=1:0.2:The mixture replacing sodium phosphate that 3 weights mix,
It is other respectively with embodiment 1-25.
Embodiment 29：
Use sodium phosphate：Sodium pyrophosphate：Ammoniacal liquor=1:1.1:The mixture replacing phosphoric acid that 0.2 weight mixes
Sodium, it is other respectively with embodiment 1-25.
Embodiment 30：
Use sodium phosphate：Sodium pyrophosphate=1:The mixture replacing sodium phosphate that 0.2 weight mixes, other difference
With embodiment 1-25.
Use sodium phosphate：Sodium pyrophosphate=1:The mixture replacing sodium phosphate that 1.1 weights mix, other difference
With embodiment 1-25.
Embodiment 31：
Use sodium phosphate：Sodium pyrophosphate：Ammoniacal liquor=1.1:The mixture replacing sodium phosphate that 0.2 weight mixes,
It is other respectively with embodiment 1-25.
Embodiment 32：
Use sodium phosphate：Sodium pyrophosphate：Ammoniacal liquor=0.2:The mixture replacing sodium phosphate that 3 weights mix, its
It is respectively the same as embodiment 1-25.
Embodiment 33：
Use sodium phosphate：Sodium pyrophosphate：Ammoniacal liquor=1：0.:8:The mixture replacing phosphoric acid that 2.3 weights mix
Sodium, it is other respectively with embodiment 1-25.
Embodiment 34：
Use sodium phosphate：Sodium pyrophosphate：Ammoniacal liquor:1：1.0:The mixture replacing sodium phosphate that 2.0 weights mix,
It is other respectively with embodiment 1-25.
Above example is only the wherein way of example of the present invention, is not intended to limit the invention, although with reference to foregoing
The present invention is described in detail embodiment, and for those skilled in the art, it still can be to foregoing implementation
Technical scheme described in example is modified, or carries out equivalent substitution to which part technical characteristic.All essences in the present invention
God any modification, equivalent substitution and improvements done etc., should be included in the scope of the protection with principle.
Claims (7)
1. polymer flooding blocks method for removing blockage after well acidizing, it is characterised in that described method is carried out as follows：
A. blocked to the polymer flooding after acidifying in well and inject detergent, the stratum around pit shaft is pre-processed, disposed
The crude oil not soluble in water on tamper surface；
B. the cross-linked gel that the weight concentration to the sour equivalent injected when blocking injection in well and being previously acidified is 5~10% is degraded
The agent aqueous solution, injection terminate, and closing well drives a well after one day；
C. to the compound depolymerizing agent aqueous solution that injection weight concentration is 6~10% in well is blocked, compound depolymerizing agent amount of aqueous solution used is pressed
According to formula W=π r2H Φ η are calculated,
In formula：W --- compound depolymerizing agent amount of aqueous solution used（m3）；
R --- treatment radius（m）, take 2~5；
H --- processing core intersection（m）；
Φ --- formation porosity（%）；
η --- compound depolymerizing agent use level coefficient, take 1~2；
Injection terminates, after closing well reacts 1 day, opening well and making production；
Detergent described in a steps is with lauryl sodium sulfate, neopelex, dodecyl polyoxyethylene groups
Ether, trimethyl Nonyl pheno base ether, one kind in sorbitan monostearate, two or more arbitrarily matches somebody with somebody
The mixture of ratio is dissolved in clear water, and manufactured weight concentration is 0.1~0.5% aqueous solution.
2. polymer flooding according to claim 1 blocks method for removing blockage after well acidizing, it is characterised in that described in a steps
Detergent is first according to lauryl sodium sulfate：Neopelex：Dodecyl polyoxyethylene ether：Trimethyl nonyl
Phenol polyethenoxy base ether：Sorbitan monostearate=0.2~1：0.2~1：0.2~1：0.2~1：0.2~1 parts by weight
The mixture, is then dissolved in clear water by proportioning mixing again, and manufactured weight concentration is 0.1~0.5% aqueous solution.
3. polymer flooding according to claim 1 blocks method for removing blockage after well acidizing, it is characterised in that described in a steps
Detergent is first according to lauryl sodium sulfate：Neopelex：Dodecyl polyoxyethylene ether：Trimethyl nonyl
Phenol polyethenoxy base ether：Sorbitan monostearate=0.7~0.9：0.7~0.9：0.7~0.9：0.7~0.9：0.7
~0.9 weight is mixed, and then the mixture is dissolved in clear water again, and manufactured weight concentration is 0.3~0.4%
The aqueous solution.
4. polymer flooding according to claim 1 blocks method for removing blockage after well acidizing, it is characterised in that described in b step
Cross-linked gel degradation agent includes sodium phosphate, sodium pyrophosphate, one kind in ammoniacal liquor or its two kinds and three kinds of mixtures arbitrarily matched.
5. polymer flooding according to claim 1 blocks method for removing blockage after well acidizing, it is characterised in that described in b step
Cross-linked gel degradation agent is according to sodium phosphate：Sodium pyrophosphate：Ammoniacal liquor=1:0.2~1.1:0.2~3 weight mixes
Mixture.
6. polymer flooding according to claim 1 blocks method for removing blockage after well acidizing, it is characterised in that described in b step
Cross-linked gel degradation agent is according to sodium phosphate：Sodium pyrophosphate：Ammoniacal liquor=1:0.8~1.0:2.0~2.3 weights mix and
Into mixture.
7. polymer flooding according to claim 1 blocks method for removing blockage after well acidizing, it is characterised in that described in step c
Injection is carried out in the case of no more than maximum injection pressure 20MPa, use discharge capacity as big as possible.
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| CN110157398A (en) * | 2019-05-22 | 2019-08-23 | 成都能生材科技开发有限责任公司 | A kind of injection well environmental protection viscosity reduction drop resistance depolymerization increasing yield and injection agent |
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