CN101285378B - Activator composite plug removal technology - Google Patents
Activator composite plug removal technology Download PDFInfo
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- CN101285378B CN101285378B CN2008100644802A CN200810064480A CN101285378B CN 101285378 B CN101285378 B CN 101285378B CN 2008100644802 A CN2008100644802 A CN 2008100644802A CN 200810064480 A CN200810064480 A CN 200810064480A CN 101285378 B CN101285378 B CN 101285378B
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- 239000002131 composite material Substances 0.000 title claims abstract description 31
- 238000005516 engineering process Methods 0.000 title claims description 12
- 239000012190 activator Substances 0.000 title description 5
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 53
- 239000007924 injection Substances 0.000 claims abstract description 44
- 238000002347 injection Methods 0.000 claims abstract description 44
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 37
- 239000002253 acid Substances 0.000 claims abstract description 23
- 150000001875 compounds Chemical class 0.000 claims abstract description 18
- 238000000034 method Methods 0.000 claims abstract description 15
- 230000008569 process Effects 0.000 claims abstract description 13
- WSFSSNUMVMOOMR-UHFFFAOYSA-N Formaldehyde Chemical compound O=C WSFSSNUMVMOOMR-UHFFFAOYSA-N 0.000 claims abstract description 12
- KRKNYBCHXYNGOX-UHFFFAOYSA-N citric acid Chemical compound OC(=O)CC(O)(C(O)=O)CC(O)=O KRKNYBCHXYNGOX-UHFFFAOYSA-N 0.000 claims abstract description 12
- 238000005260 corrosion Methods 0.000 claims abstract description 11
- 230000007797 corrosion Effects 0.000 claims abstract description 11
- KRHYYFGTRYWZRS-UHFFFAOYSA-N Fluorane Chemical compound F KRHYYFGTRYWZRS-UHFFFAOYSA-N 0.000 claims abstract description 10
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 claims abstract description 9
- QTBSBXVTEAMEQO-UHFFFAOYSA-N Acetic acid Chemical compound CC(O)=O QTBSBXVTEAMEQO-UHFFFAOYSA-N 0.000 claims abstract description 8
- VEXZGXHMUGYJMC-UHFFFAOYSA-N Hydrochloric acid Chemical compound Cl VEXZGXHMUGYJMC-UHFFFAOYSA-N 0.000 claims abstract description 8
- VKYKSIONXSXAKP-UHFFFAOYSA-N hexamethylenetetramine Chemical compound C1N(C2)CN3CN1CN2C3 VKYKSIONXSXAKP-UHFFFAOYSA-N 0.000 claims abstract description 8
- ZXEKIIBDNHEJCQ-UHFFFAOYSA-N isobutanol Chemical compound CC(C)CO ZXEKIIBDNHEJCQ-UHFFFAOYSA-N 0.000 claims abstract description 8
- 239000002736 nonionic surfactant Substances 0.000 claims abstract description 8
- 229960000583 acetic acid Drugs 0.000 claims abstract description 4
- 235000014113 dietary fatty acids Nutrition 0.000 claims abstract description 4
- 229930195729 fatty acid Natural products 0.000 claims abstract description 4
- 239000000194 fatty acid Substances 0.000 claims abstract description 4
- 150000004665 fatty acids Chemical class 0.000 claims abstract description 4
- 239000012362 glacial acetic acid Substances 0.000 claims abstract description 4
- 239000004312 hexamethylene tetramine Substances 0.000 claims abstract description 4
- 235000010299 hexamethylene tetramine Nutrition 0.000 claims abstract description 4
- 239000011780 sodium chloride Substances 0.000 claims abstract description 4
- 230000003213 activating effect Effects 0.000 claims description 34
- 239000003945 anionic surfactant Substances 0.000 claims description 7
- 125000000129 anionic group Chemical group 0.000 claims description 6
- DGAQECJNVWCQMB-PUAWFVPOSA-M Ilexoside XXIX Chemical compound C[C@@H]1CC[C@@]2(CC[C@@]3(C(=CC[C@H]4[C@]3(CC[C@@H]5[C@@]4(CC[C@@H](C5(C)C)OS(=O)(=O)[O-])C)C)[C@@H]2[C@]1(C)O)C)C(=O)O[C@H]6[C@@H]([C@H]([C@@H]([C@H](O6)CO)O)O)O.[Na+] DGAQECJNVWCQMB-PUAWFVPOSA-M 0.000 claims description 3
- 150000001408 amides Chemical class 0.000 claims description 3
- 229910052708 sodium Inorganic materials 0.000 claims description 3
- 239000011734 sodium Substances 0.000 claims description 3
- BDHFUVZGWQCTTF-UHFFFAOYSA-M sulfonate Chemical compound [O-]S(=O)=O BDHFUVZGWQCTTF-UHFFFAOYSA-M 0.000 claims description 3
- 230000000694 effects Effects 0.000 abstract description 21
- 239000000203 mixture Substances 0.000 abstract description 3
- 239000013543 active substance Substances 0.000 abstract 3
- 239000003112 inhibitor Substances 0.000 abstract 2
- 229960004011 methenamine Drugs 0.000 abstract 1
- 239000003208 petroleum Substances 0.000 abstract 1
- MZSDGDXXBZSFTG-UHFFFAOYSA-M sodium;benzenesulfonate Chemical compound [Na+].[O-]S(=O)(=O)C1=CC=CC=C1 MZSDGDXXBZSFTG-UHFFFAOYSA-M 0.000 abstract 1
- 230000035699 permeability Effects 0.000 description 33
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- 235000020681 well water Nutrition 0.000 description 3
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- 238000010276 construction Methods 0.000 description 2
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- 239000008398 formation water Substances 0.000 description 2
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- 239000011229 interlayer Substances 0.000 description 2
- 239000010410 layer Substances 0.000 description 2
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- CWYNVVGOOAEACU-UHFFFAOYSA-N Fe2+ Chemical compound [Fe+2] CWYNVVGOOAEACU-UHFFFAOYSA-N 0.000 description 1
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- XEEYBQQBJWHFJM-UHFFFAOYSA-N iron Substances [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 description 1
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- -1 iron ion Chemical class 0.000 description 1
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Images
Abstract
The invention relates to a active agent composite plug removal process, comprising two parts that: firstly, compound acid is injected into a wellhead of a water injection well by adopting a high pressure pump; secondly, after the interval between 12 hours, an active agent is injected in by using an instillation device, wherein the compound acid is formed by the following composition in percentage by weight: 10 to12 percent of hydrochloric acid, 1 to 2 percent of hydrofluoric acid, 8 to 10 percent of fluoboric acid, 2 percent of glacial acetic acid, 2.0 percent of corrosion inhibitor, 0.1 to 0.2 percent of citric acid, 4.0 to 6.0 percent of isobutanol and 68 to 72 percent of water; the active agent is formed by the following composition in percentage by weight: 0.1to 0.2 percent of negative nonionic surfactant, 0.3 to 0.5 percent of sodium chloride, the balance being water; the corrosion inhibitor is formed by compositely preparing hexamethylene tetramine and formaldehyde in the proportion of 1 to 1; the negative nonionic surfactant is formed by compositely preparing petroleum benzene sulfonic acid sodium salt and fatty acid alkanolamide in the proportion of 1 to 1. The composite plug removal agent has the effect in the comprehensive plug removal for near bore zones and the deep parts of oil layers, which is long in valid period and obvious in plug removal effect.
Description
Technical field:
The present invention relates to a kind of water injection well de-plugging process in the oil recovery field, oil field, especially a kind of activating agent composite deblocking process.
Background technology:
It is poor that the low permeability oil field oil reservoir is grown, and the oil reservoir pore radius obviously diminishes, clay content and shale content significantly increases, median grain diameter obviously reduces.The slight obstruction in the waterflooding extraction process of such oil reservoir can cause injection pressure to raise, and injects difficulty.The direct fluid flow of characteristics such as the while duct is tiny, pore throat effect enhancing, high-ratio surface produce obviously influence, and permeability is low more, influences strong more.Constantly advance along with injecting water, filtrational resistance increases sharply, and injection pressure raises fast, and water injection rate successively decreases soon.Organic obstruction of obstruction and inorganic obstruction, inorganic obstruction mainly comprise the fast quick injury that mud contamination, clay mineral hydration swelling, endogenous and exogenous granula cause in the brill completion measure process etc.; Organic obstruction is meant and after organic (such as pitch, colloid etc.) are adsorbed in porous media, deposited in the crude oil part pore throat is stopped up; Rock permeability obviously descends; Also can make the inclined to one side oleophylic of rock surface wetability simultaneously, water phase permeability reduces, and the direct fluid flow of characteristics such as the while duct is tiny, pore throat effect enhancing, high-ratio surface produce obviously influence; And permeability is low more, influences strong more.Constantly advance along with injecting water, filtrational resistance increases sharply, and injection pressure raises fast, and water injection rate successively decreases soon.Method for removing blockage commonly used is an acidification to dispel block, but DeGrain and period of validity are short.
Summary of the invention:
In order to overcome disadvantages of background technology, the present invention provides a kind of activating agent composite deblocking process, and this technology has the effect of near wellbore zone and oil reservoir deep integrative blockage relieving, and period of validity is long, and plugging removal effect is obvious.
This activating agent composite deblocking process principle:
Generally, the relation of pressure reduction and flow is:
At Q, μ, h, R
e, R
wUnder the situation about remaining unchanged, Δ P and K
wBe inversely proportional to, even can improve K
w, just can reduce Δ P.And
k
w＝k×k
rw
K in the formula
wBe the effective permeability of stratum to injection water;
K is a formation absolute permeability;
K
RwBe the relative permeability of stratum to injection water.
Can find out from this formula, improve absolute permeability and relative permeability and can improve the effective permeability of injecting water.Obstructions such as mechanical admixture, dirt are removed in fracture in oil and water wells in the past, acidifying measure, the mediation duct, and its mechanism of action is to improve the absolute permeability on stratum; And desk research shows, interfacial tension is hanged down solution, can improve the relative permeability of injecting water, and the terminal point of hydrophilic rock (the highest) water has only about 0.15 permeability in theory, and if solution interface tension force is zero, then should reach 1.Promptly by changing interfacial tension, the relative permeability of water can improve 1/0.15=6.7 doubly in theory, injects pressure reduction and also should reduce by 6.7 times.
Technical scheme of the present invention is: this activating agent composite deblocking process comprises two parts; At first adopt high-pressure pump to inject compound acid at the water injection well well head; At interval after 12 hours; Adopt drop instillator to inject activating agent; Wherein compound acid is made up of hydrochloric acid 10～12%, hydrofluoric acid 1%-2%, fluoboric acid 8%-10%, glacial acetic acid 2%, corrosion inhibiter 2.0%, citric acid 0.1～0.2%, isobutanol 4.0～6.0% and water 68～72%; Activating agent is made up of anionic and nonionic surfactant 0.1～0.2%, sodium chloride 0.3～0.5% and excess water, above-mentioned corrosion inhibiter by hexamethylenetetramine and formaldehyde by 1: 1 composite forming, the anionic and nonionic surfactant by petrobenzene sodium sulfonate, fatty acid alkanol amides by 1: 1 composite forming.In whole injection process, can change according to injecting well injection pressure and injection rate, suitably adjust surfactant concentration and consumption.
This activating agent performance evaluation:
1. compound acid system
This system is made up of inorganic acid, organic acid, corrosion inhibiter and clay stabilizer etc., has de-plugging performance preferably.To growing relatively poor oil reservoir; To in certain depth and range scope, improve the degree of porosity and the permeability on stratum; The reaction speed of cement is fast in conventional acidifying solution and the stratum, sphere of action is little, does not reach the effect that improves in-place permeability, and the slow hydrolysis in the stratum of inorganic acid, organic acid generates hydrofluoric acid in the compound acid system that adopts; Reduce the acid liquid reaction vigor, thereby increased the operating radius of active acid.Clay stabilizer can form diaphragm on rock cement surface, prevents that the clay mineral in the cement shifts with flow behind stratum and the acid liquid reaction, plays the purpose on protection stratum.Corrosion inhibiter is a kind of ferrous stability, protects tubing and casing and equipment acid and alkali corrosion, and can prevent the deposition of iron ion in the stratum.Concrete performance sees the following form 1 and Fig. 3.
Compound sour combination property tables of data table 1
2. activating agent blockages relieving fluid:
Form by non-ionic surface active agent, anion surfactant and auxiliary agent etc. and to have certain surface living solution system.This system can reduce oil water interfacial tension, increases the crude oil flow ability; Can change the rock surface wetability, make rock wettability to hydrophilic side to transformation, performance capillary force effect; Increase water phase permeability, reduce injection pressure.Each item performance such as following table 2 and Fig. 4:
1. can reach 10 with the Daqing crude oil oil water interfacial tension
-2MN/m;
2. activator solution can reduce the contact angle of oleophylic dielectric surface and water;
3. activator solution increases water phase permeability, reduces injection pressure.
The wave carrier piece after the activating agent blockages relieving fluid is handled and the dynamic contact angle table 2 of distilled water
| Solution | Advancing angle (°) | Receding angle (°) |
| Mining site injects water | 92.98 | 90.39 |
| Active blockages relieving fluid | 67.75 | 60.43 |
Remarks: the wave carrier piece with methyl-silicone oil was handled is simulated the oleophylic oil reservoir.
The present invention has following beneficial effect: the present invention is through analyzing the reason that such oil-bearing stratum flooding is difficult, water injection pressure is high; And on the basis of summing up the augmented injection of water injection well step-down in the past work; Through a large amount of theoretical researches and experiment; Develop a kind of novel block releasing technique, that is: activating agent composite blockage relieving technology.Its applied de-plugging agent is a kind of compound system that is made up of compound acid, activating agent etc., has the effect of near wellbore zone and oil reservoir deep integrative blockage relieving, makes plugging removal effect obviously be superior to conventional acidification to dispel block, and period of validity is long.In addition, the with serious pollution oil reservoir of this technology centering hyposmosis has tangible plugging removal effect.Receive the formation condition restraining factors few.This activating agent composite blockage relieving technology is that compound acidifying technology and two kinds of different process of activating agent unblocking and injection increasing technology are organically combined; Not only improve the absolute permeability of injecting water but also improve its relative permeability; The comprehensive effective permeability of injecting water that improves further reduces injection pressure.At first inject compound sour acidifying solution, remove near wellbore zone oil reservoir inorganic matter and stop up to the stratum, the mediation duct, thus guarantee that follow-up active liquid injects smoothly.Reinject and have certain surface active active liquid and corresponding additive; Active liquid progressively pushes earth formation deep with injecting water; Activation retained oil, increase hollow billet number also change rock wettability, increase the effect of the relative permeability of water, reach the purpose that improves the oil reservoir injectability.Compound acid system effect is to remove the surrounding formation inorganic pollution, increases formation porosity and permeability, and follow-up activator solution is injected smoothly, the oil reservoir deep is sent out the effect of the displacement of reservoir oil, reduction oil water interfacial tension.This composite blockage relieving agent has the effect of near wellbore zone and oil reservoir deep integrative blockage relieving.
Description of drawings:
Fig. 1 is southern 5-31-626 well water flooding curve;
Fig. 2 is southern 6-20-626 well water flooding curve;
Fig. 3 activating agent system and crude oil interfacial tension stability curve;
Fig. 4 rock core permeability saturation curve;
Fig. 5 high-pressure pump is annotated process schematic representation;
Fig. 6 activating agent instillation process schematic representation.
The specific embodiment:
Below in conjunction with embodiment the present invention is described further:
Composite blockage relieving formula of liquid used among the following embodiment is: compound acid is made up of hydrochloric acid 12%, hydrofluoric acid 1%, fluoboric acid 8%, glacial acetic acid 2%, corrosion inhibiter 2.0%, citric acid 0.2%, isobutanol 4.0% and water 70.8%; Activating agent is made up of the water of anionic and nonionic surfactant 0.1%, sodium chloride 0.5% and 99.4; Wherein corrosion inhibiter by hexamethylenetetramine and formaldehyde by 1: 1 composite forming, the anionic and nonionic surfactant by petrobenzene sodium sulfonate, fatty acid alkanol amides by 1: 1 composite forming.
η＝(Kw-Kw
0)/Kw×100％
η in the formula-permeability raising rate, %
Kw
0The initial water of rock core is surveyed permeability, * 10 before the-notes blockages relieving fluid
-3μ m
2
The water of rock core is surveyed permeability, * 10 behind the Kw-notes blockages relieving fluid
-3μ m
2
Core physical simulation experimental data table 3
Core permeability raising rate average out to 100.81% behind the natural core employing HSA activating agent composite blockage relieving.
1. the test well geologic feature and the analysis of causes of suction situation difference
Based on the actual injection situation of test well, through the western piece in 6 districts, south is encrypted wellblock reservoir mineral and physical properties of fluids analysis three times, in conjunction with test well water uptake section well logging achievement, suction situation difference mainly contains following several respects reason:
(1) the reservoir homogenieity is poor, and water absorption is uneven, and interlayer contradiction is serious, and the part interval does not absorb water;
(2) this reservoir belongs to the dirty oil reservoir of thin difference, and is mobile poor, water absorbing capacity a little less than, middle constant speed is quick, in strong water-sensitive, in salt is quick by force, middle strong acid is quick, middle highly basic is quick, conventional acidifying measure can't solve this well contradiction;
(3) this reservoir shale content is higher, and formation water salinity is higher, when external liquid injects; Because the unfavourable balance of salinity is bigger, very easily causes electron drift between formation water and the external liquid, cause mineral clay to expand, migrate; Cause the interval of original suction or not; Overall permeability reduces, and reservoir is not only the near wellbore zone and is polluted, and deep-seated problems are more outstanding;
(4) this reservoir belongs to two, three types of reservoirs, and physical properties of fluids is relatively poor, and crude oil heavy composition is more, and absorption firmly;
(5) the most of apparent middle strong oil-wet property of this reservoir wetting conditions is not easy to fluid and flows.
2. activating agent composite blockage relieving liquid injection rate:
On the plugging reason analysis foundation, in conjunction with test well sound attitude creation data, comprehensively judge, confirm augmented injection layer position and plug removal radius, on this basis, calculate on-the-spot activating agent composite blockage relieving liquid injection rate.
Activating agent composite blockage relieving liquid is on-the-spot with scale 4
3. field trial situation and effect analysis:
(1) Nan5-31-626Jing
On December 2nd, 2006 was carried out the construction of HSA activating agent composite blockage relieving to this well Sa II1---Sa III2, the II4---II10 of Portugal, the high I4+5 of high I1---, high I6+ 7---I16+17; At first adopt high-pressure pump to inject compound acid (as shown in Figure 5); Injecting flow is 10 cubic metres of per half an hour, and injection pressure is 11.3～11.5Mpa, adopts the mode that instils to inject activating agent at interval after 12 hours; Injecting flow is 63 cubic metres of every days, and the accumulative total injection length is 30 days.After the measure full well diurnal injection by measure before 42m
3Be increased to 78m
3, diurnal injection increases 36m
3, seen the effect of step-down augmented injection preferably on the whole.
See that from the seperated layer water injection data the high I6+ 7---I16+17 that the suction ratio is low, the high I4+5 of high I1---, Sa II1---Sa III2 interval water absorbing capacity have obtained obvious improvement.
Water injection well south 5-31-626 well HSA activating agent composite blockage relieving field test data table 5
(2) southern 6-20-626 well 80
This well is in the construction of full well employing on December 24th, 2006 activating agent composite blockage relieving; At first adopt high-pressure pump to inject compound acid, injecting flow is 10 cubic metres of per half an hour, adopts the mode that instils to inject activating agent (as shown in Figure 6) at interval after 12 hours; The accumulative total injection length is 33 days, injects 1650m
3Activator solution, injection pressure are 8.6～11.2MPa.Injection pressure 12.1MPa before the measure, daily water-injection rate 46m
3, after the measure under injection pressure 8.82MPa, diurnal injection 80m
3, the 0.73m of injectivity index before by measure
3/ m.MPa has brought up to 1.74m
3/ m.MPa, amplification has reached 138%.
In October, 2007, this well carried out the injection profile test, and show with injection profile test data contrast before the measure: obvious change has taken place intake profile before and after adopting the activating agent composite blockage relieving, and water sucting thickness improves.
Absorption profile test data table 6 before and after the 6-20-626 well activating agent composite blockage relieving of south
The period of validity of present two mouthfuls of wells has all reached 10 months, and continuous and effective, has obtained the effect of step-down augmented injection preferably.
Activating agent composite blockage relieving technology can improve the absolute permeability of injecting water can improve its relative permeability again, and the two comprehensive effective permeability of injecting water that improves plays step-down augmented injection effect.The western piece in 6 districts three infill well field trials in south show: activating agent composite blockage relieving technology can make water injection pressure reduce, and water injection rate increases; And the water absorbing capacity of suction situation difference oil reservoir is improved, have the effect of adjustment interlayer suction difference.
Claims (1)
1. activating agent composite deblocking process; It is characterized in that: this technology comprises two parts; At first adopt high-pressure pump to inject compound acid at the water injection well well head; At interval after 12 hours; Adopt drop instillator to inject activating agent, wherein compound acid is made up of hydrochloric acid 10～12%, hydrofluoric acid 1%-2%, fluoboric acid 8%-10%, glacial acetic acid 2%, corrosion inhibiter 2.0%, citric acid 0.1～0.2%, isobutanol 4.0～6.0% and water 68～72%, and activating agent is made up of anionic and nonionic surfactant 0.1～0.2%, sodium chloride 0.3～0.5% and excess water; Above-mentioned corrosion inhibiter by hexamethylenetetramine and formaldehyde by 1: 1 composite forming, the anionic and nonionic surfactant by petrobenzene sodium sulfonate, fatty acid alkanol amides by 1: 1 composite forming.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN2008100644802A CN101285378B (en) | 2008-05-09 | 2008-05-09 | Activator composite plug removal technology |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN2008100644802A CN101285378B (en) | 2008-05-09 | 2008-05-09 | Activator composite plug removal technology |
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|---|---|
| CN101285378A CN101285378A (en) | 2008-10-15 |
| CN101285378B true CN101285378B (en) | 2012-02-01 |
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| CN2008100644802A Expired - Fee Related CN101285378B (en) | 2008-05-09 | 2008-05-09 | Activator composite plug removal technology |
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| CN102250602B (en) * | 2011-05-06 | 2013-06-26 | 河北科技大学 | Composite acid blockage removing agent for oil well |
| CN102505930B (en) * | 2011-11-22 | 2014-04-09 | 西安石油大学 | Water base fracturing and blocking-removing composite process |
| CN102536166B (en) * | 2012-02-14 | 2015-01-21 | 中国石油天然气股份有限公司 | Method for deep treatment of oil layer through self-generation foam acidification |
| CN102634332B (en) * | 2012-03-26 | 2014-02-19 | 中国石油天然气股份有限公司 | Blockage remover for decompression and steam injection in high clay content sandstone oil reservoir |
| CN102775974B (en) * | 2012-07-17 | 2014-05-14 | 大庆井升伟业油田技术服务有限公司 | Active mixed acid plugging removal solution applicable to low permeability reservoir |
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| CN109294550B (en) * | 2018-09-26 | 2021-06-01 | 中国石油天然气股份有限公司 | Main acid for sandstone reservoir composite acid fracturing and preparation method thereof |
| CN112922571B (en) * | 2021-03-15 | 2022-12-30 | 中国石油大学(华东) | Mud sand blocking prevention and control technology suitable for loose sandstone oil reservoir water injection |
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