CN102587858B - Method for blocking water for fracture and hole type reservoir - Google Patents
Method for blocking water for fracture and hole type reservoir Download PDFInfo
- Publication number
- CN102587858B CN102587858B CN201210061842.9A CN201210061842A CN102587858B CN 102587858 B CN102587858 B CN 102587858B CN 201210061842 A CN201210061842 A CN 201210061842A CN 102587858 B CN102587858 B CN 102587858B
- Authority
- CN
- China
- Prior art keywords
- blocking agent
- water
- fracture
- reservoir
- well
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Active
Links
Abstract
The invention provides a method for blocking water for a fracture and hole type reservoir, which is particularly applicable to high-mineralization fracture and hole type reservoirs. The method includes that blocking agent with following ingredients is selected, the ingredients of the blocking agent include, by mass percent, from 5.24 to 9.36% of cement, from 3.03 to 5.35% of microsilica, from 4.01 to 5.43% of sodium bentonite, from 0.52 to 0.55% of polymeric dispersant, from 0.17 to 0.40% of retarder, from 0.0008 to 0.0011% of sodium carbonate aqueous solution by sodium carbonate and the balance water, and water cement ratio of the blocking agent ranges from 4.07 to 6.28; the blocking agent is injected into an oil well according to output volume of 300-800L/min, and after soaking for 72 hours, the well is opened and begins production; and the use level of the blocking agent is equal to 1/2 to 2/3 of the use level of fracturing liquid during acid-fracturing of an analog crack or communication of reservoir bodies, and is calculated by 5-20m3/m of a blocking well section for a well without being in acid-fracturing. The density of the blocking agent ranges from 1.09g/cm3 to 1.14g/cm3 and is not changed before and after solidification, solidification strength ranges from 0.22 MPa to 0.43MPa, leakage of the blocking agent due to the density reason cannot be caused in a water blocking process of the fracture and hole type reservoir, and the blocking agent can effectively stay on an oil-water boundary, and selectively blocks a water outlet channel.
Description
Technical field
The present invention relates to oil reservoir chemical water shutoff field, be particularly a kind ofly applicable to the blocking agent of fracture-pore reservoir and use this blocking agent to carry out the method for oil reservoir water blockoff, effective improvement of high-water-cut oil-producing well can be realized.
Background technology
Carbonate Reservoir petroleum-in-place and output account for the 50%-60% of world oil oil in place and output, occupy an important position in oil-gas field development at home and abroad always.Carbonate Reservoir type is various, and mainly contain large-scale protuberance, organic reef, buried hill oil pool etc., its major reservoir spaces type comprises primary pore, secondary pore, dissolution porosity and crack, and large-scale corrosion seam, hole system are grown in part oil-gas reservoir.
Carbonate Reservoir Reservoir Body form determine this type of oil reservoir have build produce fast, end water electrode easily bore into feature, and particularly outstanding in fracture-pore reservoir.Along pit shaft output after oil well bottom water coning, suppress top reservoir produce oil, cause the too early High water cut of oil well, affect effect of reservoir development.Water blockoff effectively administers bottom water coning, and release top potentiality, recover one of Main Means of oil well productivity.
Water blockoff controls water-oil factor or water production control exactly, its essence is and changes water flow behavior in the earth formation, namely changes water Percolation Law in the earth formation.Water-blocking operation, according to the difference of construction object, is divided into oil well (producing well) water blockoff and well (Injection Well) profile control two class.Its objective is the cementing technology situation remedying oil well and the permeability (adjustment flow profile) reducing Water Flooding Layer, improve the recovery ratio of oil reservoir.
Blocking agent generally refers to the inorganic agent for the production of well water blockoff.The shutoff method adopted in oil field is divided into water pack off and chemical water shutoff two class, and chemical method water blockoff is that the chemical action of chemical plugging agent results in blockage to water-yielding stratum, Mechanical Method water blockoff be with separator by water exit at pit shaft Nei Kakai, flow in well to stop water.See with regard to current application and development situation, mainly applied chemistry water blockoff.According to the ponding of blocking agent to oil reservoir and water layer, chemical water shutoff can be divided into non-selective water blockoff and selective water plugging; Also have permanent stifled and stifled temporarily according to construction requirement.Non-selective water blockoff refers to that blocking agent can the chemical agent of simultaneously reservoir plugging and water layer in oil reservoir; Selective water plugging refers to that blocking agent only works with water, and does not work with oil, therefore only results in blockage at water layer and affect very micro-on oil reservoir.According to the difference of decentralized medium, selective water-plugging has water base blocking agent, oil base blocking agent and alcohol radical blocking agent, polymer gel blocking agent etc.; Non-selective blocking agent has cement, solid particle, thermosetting resin, inorganic salts precipitation etc.
Early stage mainly adopts the blocking agents such as cement, milk of lime, resin, gel, frozen glue for fracture-cavity type carbonate oilwell water shutoff, but water blockoff is efficient and oil increasing effect is not all very desirable.For Ordovician of Tahe oil fractured-cavernous carbonate reservoir, since water blockoff test is carried out from calendar year 2001 in this oil field, total water blockoff is efficient less than 60%, efficient low main cause comprises two aspects: one is, blocking agent density is large, very easily miss in plug water construction process, blocking agent is difficult to effectively resident, causes water blockoff invalid; Two are, the blocking agent that intensity is high is selective strong, selective strong blocking agent insufficient strength, cause that water blockoff is invalid or period of validity is short.Therefore, need to explore a kind of blocking agent and the water blockoff that are applicable to this type of oil well, to improve water plugging effect.
Summary of the invention
Technical problem to be solved by this invention be overcome that existing fracture-pore reservoir blocking agent density is large, intensity and selectively there is the defects such as contradiction, provide a kind of method of carrying out water blockoff to fracture-pore reservoir, in fracture-pore reservoir water blockoff process, blocking agent will be caused to miss because of density reasons, and blocking agent can effective resident shutoff exhalant canal; Oil in water blockoff, water selective and blocking agent intensity are high, achieve high strength selective water plugging.
Large for fracture-pore reservoir reservoir space, fluid is easily through the advantage of density phase double replacement, the present invention uses density between crude oil, formation water, and the blocking agent system that profit does not disperse, utilize the gravity between formation water, blocking agent, crude oil three, make blocking agent selective resident and automatically sprawl on oil-water interfaces, and on oil-water interfaces, form dividing plate after its solidification, stop end water too fast on invade.The present invention is applicable to formation water density at 1.09g/cm
3above high salt fracture and vug carbonate reservoir selective water plugging.
In order to solve the problems of the technologies described above, first technical scheme provided by the invention is, fracture-pore reservoir is carried out to the method for water blockoff, the method comprises: the blocking agent selecting following composition, by percentage to the quality, this blocking agent comprises: cement 5.24-9.36%, micro-silicon 3.03-5.35%, sodium bentonite 4.01-5.43%, polymeric dispersant 0.52-0.55%, retarding agent 0.17-0.40%, the aqueous sodium carbonate accounting for 0.0008-0.0011% in sodium carbonate and water surplus, wherein, the water/binder ratio of this blocking agent is 4.07-6.28; Described blocking agent is injected oil well, and vexed well is after at least 72 hours, opening well and making production.
Water/binder ratio of the present invention refers to the value of water quality in blocking agent/solid constituent quality.
Aforesaid method of fracture-pore reservoir being carried out to water blockoff, described plug agent amount is designed to: when acidizing simulation crevice volume or communication Reservoir Body, plug agent amount is the 1/2-2/3 of fracturing fluid consumption; Without during acid fracturing wells with plugged well section 5-20m
3/ m, preferred 6.182-8.547m
3/ m.
The present invention does not have particular/special requirement to fracturing fluid, and conventional commercial fracturing fluid all can be applicable to the present invention.Its main component of preferred fracturing fluid is: HPG melon glue, cleanup additive, demulsifier, bactericide, PH conditioning agent, friction reducer, organic borate cross-linker, temperature stability agent, clay stabilizer etc.It should be noted that, what every this area was conventional is used as pH value conditioning agent, demulsifier, bactericide, cleanup additive, temperature stability agent, clay stabilizer, those reagent of crosslinking agent all can be used in the application, such as, cleanup additive can be APES, demulsifier can be SYNPERONIC PE/F68, friction reducer can be polyacrylamide and derivative thereof, bactericide can be dodecyl benzyl dimethyl ammonium chloride or OIT, temperature stability agent can be monoethanolamine, triethanolamine or ethylenediamine, clay stabilizer can be that trimethyl tertiary amine and hydrochloric acid thereof and epichlorohydrin reaction synthesize the trimethyl hydroxypropyl quaternary ammonium salt generated.
Aforesaid method of fracture-pore reservoir being carried out to water blockoff, according to 300-800L/min discharge capacity, injects oil well by described blocking agent.
Aforesaid method of fracture-pore reservoir being carried out to water blockoff, by percentage to the quality, described blocking agent comprises: cement 5.74-8.25%, micro-silicon 3.28-4.72%, sodium bentonite 4.72-5.43%, polymeric dispersant 0.53-0.54%, retarding agent 0.19-0.33%, the aqueous sodium carbonate accounting for 0.0009-0.0011% in sodium carbonate and water surplus, wherein, the water/binder ratio of this blocking agent is 4.37-5.72.
In above-mentioned blocking agent, the effect of described cement is to provide the intensity after material cured.The preferred superfine cement of described cement, reaches secondary nanophase, its median particle diameter D
50be less than or equal to 1 μm, preferred 0.8-1 μm; Maximum particle diameter D
maxbe no more than 18 μm, more than 80% particle size is below 5 μm.
In above-mentioned blocking agent, described micro-silicon (silicon ash) is when smelting ferrosilicon or industrial silicon, after the silicon steam oxidation of being discharged by flue, collecting what obtain through dust-precipitator take amorphous silica as the product of main component, its effect is the intensity after improving blocking agent solidification, micro-silicon (WG) of nano-scale is adopted more to be conducive to gaining in strength, its median particle diameter D
50between 20-60nm.
In above-mentioned blocking agent, described sodium bentonite, its effect is bloating tendency, caking property, adsorptivity, catalytic, thixotropy, the suspension that increase blocking agent.Conventional drilling level swell soil selected by the present invention's sodium bentonite used, and namely the sodium bentonite namely meeting GB GB/T 5005-2010 drilling fluid materials specification can be used for the present invention.
In above-mentioned blocking agent, the effect of described retarding agent is the hardening time delaying blocking agent, keeps its plasticity.General cement retarding agent selected by the present invention's retarding agent used, such as lignosulfonates and derivative thereof, low molecular weight cellulose and derivative, hydroxycarboxylic acid, organic phospho acid, boric acid or its salt or compound, preferably have machine phosphonic acid, such as ethylene diamine tetra methylene phosphonic acid calcium (ethylenediamine tetramethylene phosphonic acid calcium), ethylene diamine tetra methylene phosphonic acid sodium (sodium ethylenediamine tetramethylenephosphonate), ethylenediamine five methylenephosphonic acid (ethylenediamine pentamethylene phosphonic acids).
In above-mentioned blocking agent, the effect of described polymeric dispersant is the slurry stability improving cured granulate, the polymer such as optional cellulose family, non-hydrolytic polyacrylamide, preferred viscosity average molecular weigh about 1,000,000 hydroxyethylcellulose.
In above-mentioned blocking agent, the effect of described aqueous sodium carbonate suppresses calcium ions and magnesium ions contained by swell soil in slurry, prevents its short coagulating from affecting slurry stability.
Moisture in the present invention's blocking agent used is higher, by improving the water/binder ratio of blocking agent, reduces the density of blocking agent.The density of blocking agent of the present invention can be controlled in 1.07-1.14g/cm
3, before and after solidification, density is constant, and now water ash mass ratio reaches 4.07-6.28.Blocking agent of the present invention hardening time is 48-72h, and solidification intensity is 0.22-0.43MPa.
The preparation method of the present invention's blocking agent used comprises: according to mass percent, the cement of solid phase, micro-silicon, sodium bentonite, polymeric dispersant is mixed, obtains solid phase mixing ash; According to mass percent, retarding agent, aqueous sodium carbonate, water are mixed, obtains mixed solution; Then gradually described solid phase mixing ash is joined in described mixed solution under stirring, form the blocking agent of mixing.
Adopt method of fracture-pore reservoir being carried out to water blockoff of the present invention, at least there is following beneficial effect: the blocking agent that the present invention uses density between highly mineralized formation brines and crude oil carries out water blockoff to fracture-pore reservoir, because blocking agent density used is low, can effectively prevent blocking agent because of gravity cause leakage; The blocking agent that the present invention uses its be oil, water non-dispersed system, after blocking agent is injected stratum, the oil-water interfaces that can reside in seam hole body solidify, realize selective shut-off; Shutoff method of the present invention has good infusion performance, can guarantee that safety is injected in construction.
Accompanying drawing explanation
Fig. 1 is the dynamic multiviscosisty curve of the blocking agent of embodiment 1.
Fig. 2 is the dynamic multiviscosisty curve of the blocking agent of embodiment 2.
Fig. 3 is the dynamic multiviscosisty curve of the blocking agent of embodiment 3.
Fig. 4 is the dynamic multiviscosisty curve of the blocking agent of embodiment 4.
Fig. 5 is the dynamic multiviscosisty curve of the blocking agent of embodiment 5.
Fig. 6 is the dynamic multiviscosisty curve of the blocking agent of embodiment 6.
Productive frontiers before and after Fig. 7 TH10421 well water blockoff.
Detailed description of the invention
For fully understanding the object of the present invention, feature and effect, by following concrete embodiment, the present invention is elaborated.
Large for fracture-pore reservoir reservoir space, fluid is easily through the advantage of density phase double replacement, the present invention adopts density between crude oil, formation water, and the blocking agent system that profit does not disperse, utilize the gravity between formation water, blocking agent, crude oil three, make blocking agent selective resident and automatically sprawl on oil-water interfaces, and on oil-water interfaces, form dividing plate after its solidification, stop end water too fast on invade.The present invention is applicable to formation water density at 1.09g/cm
3above high salt fracture and vug carbonate reservoir selective water plugging, the present invention's blocking agent used system can high temperature resistant (130 DEG C), resistance to high salt (23 × 10
4mg/L).
Fracture-pore reservoir is carried out to the method for water blockoff, the method comprises: the blocking agent selecting following composition, by percentage to the quality, this blocking agent comprises: cement 5.24-9.36%, micro-silicon 3.03-5.35%, sodium bentonite 4.01-5.43%, polymeric dispersant 0.52-0.55%, retarding agent 0.17-0.40%, the aqueous sodium carbonate accounting for 0.0008-0.0011% in sodium carbonate and water surplus, wherein, the water/binder ratio of this blocking agent is 4.07-6.28; Described blocking agent is injected oil well, and vexed well is after at least 72 hours, opening well and making production.
Set forth the present invention below by specific embodiment, one skilled in the art will appreciate that this should not be understood to the restriction to the claims in the present invention scope.
Raw material used in embodiment is bought from conventional commercial, and hydroxyethylcellulose is bought and worn Vad Petroleum Technology Co., Ltd from Kuerle, model HEC-3.The conventional water-plugging technology sealing compound of fracture-pore reservoir all can be applicable to the present invention, and in following examples, sealing compound main component used is density 1.5-1.8g/cm
3cementing concrete.
Blocking agent preparation method, determinator and assay method used during product analysis in embodiment below all with reference to GB/T 19139-2003 oil-well cement test method, are described as follows:
Density measuring device and method: adopt fluid under pressure densometer, measure according to the 6th article of cement slurry density method for measuring in GB/T 19139-2003 oil-well cement test method.
Dehydration determinator and method: adopt high-temperature and high-pressure filter press, measure according to the method for the 10th article of quiet loss-of-coolant experiment (LOCE) in GB/T 19139-2003 oil-well cement test method.
Bleed and 4stability determination: adopt 250mL glass cylinder, measure according to the 15.5th article of method leaving standstill the free liquid test of cement paste at room temperature environment in GB/T 19139-2003 oil-well cement test method.Leave standstill 2h, measure free liquid volume and be accurate to ± 0.2mL.
Blocking agent block preparation method and intensity test method: according to the method for the 7th article of oil well simulation compressive strength test in GB/T 19139-2003 oil-well cement test method, adopt 50.8mm × 50.8mm × 50.8mm standard die trial, under reservoir temperature, maintenance and preparation blocking agent block, adopt pressure testing machine to measure compressive strength.
Multiviscosisty assay method: according to the method for the 9th article of oil well simulation thickening time test in GB/T 19139-2003 oil-well cement test method, adopt HTHP multiviscosity meter to measure under reservoir temperature, pressure.
Static hardening time assay method: adopt 50.8mm × 50.8mm × 50.8mm standard die trial, HTHP maintenance (120 DEG C, 20.7MPa), whether take out to investigate at interval of 12h and solidify completely, maintenance process is according to the 7th article of oil well simulation compressive strength test in GB/T 19139-2003 oil-well cement test method.
Degree of mobilization assay method: blocking agent is injected rapidly in truncated cone circle mould, by doctor blade, truncated cone circle mould is mentioned by vertical direction, start to clock simultaneously, when appointing blocking agent to flow to 30s on a glass, measure the maximum gauge of the mutually perpendicular both direction of trickling part with ruler, average is degree of mobilization.
Blocking agent prepares embodiment
Embodiment 1
First by cement (D
50be 1 μm) 45g (5.24% quality), micro-silicon (D
50for 60nm) 26g (3.03% quality), sodium bentonite 40g (4.66% quality), hydroxyethylcellulose (viscosity average molecular weigh is 1,000,000) 4.7g (0.55% quality) mix, be made into combination ash; The aqueous sodium carbonate 0.8g (0.09% quality) of ethylenediamine tetramethylene phosphonic acid calcium 1.5g (0.17% quality), mass concentration 1% is added in the arm stirrer that 741g water (86.26% quality) is housed, be made into mixed solution, and then combination ash is slowly added in mixed solution, stir, form laboratory blocking agent sample 1#.This sample water gray scale is 6.28.
Embodiment 2
First by cement (D
50be 0.9 μm) 49g (5.74% quality), micro-silicon (D
50for 50nm) 28g (3.28% quality), sodium bentonite 43g (5.03% quality), hydroxyethylcellulose (viscosity average molecular weigh is 1,000,000) 4.6g (0.54% quality) mix, be made into combination ash; The aqueous sodium carbonate 0.86g (0.10% quality) of sodium ethylenediamine tetramethylenephosphonate 1.6g (0.19% quality), mass concentration 1% is added in the arm stirrer that 727g water (85.12% quality) is housed, be made into mixed solution, and then combination ash is slowly added in mixed solution, stir, form laboratory blocking agent sample 2#.This sample water gray scale is 5.72.
Embodiment 3
First by cement (D
50be 0.9 μm) 54g (6.38% quality), micro-silicon (D
50for 40nm) 31g (3.66% quality), sodium bentonite 46g (5.43% quality), hydroxyethylcellulose (viscosity average molecular weigh is 1,000,000) 4.5g (0.54% quality) mixing, be made into combination ash; The aqueous sodium carbonate 0.92g (0.11% quality) of ethylenediamine pentamethylene phosphonic acids 2.0g (0.24% quality), mass concentration 1% is added in the arm stirrer that 708g water (83.64% quality) is housed, be made into mixed solution, and then combination ash is slowly added in mixed solution, stir, form laboratory blocking agent sample 3#.This sample water gray scale is 5.11.
Embodiment 4
First by cement (D
50be 0.9 μm) 64g (7.26% quality), micro-silicon (D
50for 40nm) 36g (4.09% quality), sodium bentonite 46g (5.22% quality), hydroxyethylcellulose (viscosity average molecular weigh is 1,000,000) 4.7g (0.53% quality) mixing, be made into combination ash; The aqueous sodium carbonate 0.92g (0.10% quality) of ethylenediamine pentamethylene phosphonic acids 2.4g (0.27% quality), mass concentration 1% is added in the arm stirrer that 727g (85.52% quality) water is housed, be made into mixed solution, and then combination ash is slowly added in mixed solution, stir, form laboratory blocking agent sample 4#.This sample water gray scale is 4.72.
Embodiment 5
First by cement (D
50be 0.8 μm) 70g (8.25% quality), micro-silicon (D
50for 30nm) 40g (4.72% quality), sodium bentonite 40g (4.72% quality), hydroxyethylcellulose (viscosity average molecular weigh is 1,000,000) 4.5g (0.53% quality) mixing, be made into combination ash; The aqueous sodium carbonate 0.8g (0.09% quality) of sodium ethylenediamine tetramethylenephosphonate 2.8g (0.33% quality), mass concentration 1% is added in the arm stirrer that 690g (81.36% quality) water is housed, be made into mixed solution, and then combination ash is slowly added in mixed solution, stir, form laboratory blocking agent sample 5#.This sample water gray scale is 4.37.
Embodiment 6
First by cement (D
50be 0.8 μm) 70g (9.36% quality), micro-silicon (D
50for 20nm) 40g (5.35% quality), sodium bentonite 30g (4.01% quality), hydroxyethylcellulose (viscosity average molecular weigh is 1,000,000) 3.9g (0.52% quality) mixing, be made into combination ash; The aqueous sodium carbonate 0.6g (0.08% quality) of ethylenediamine tetramethylene phosphonic acid calcium 3.0g (0.40% quality), mass concentration 1% is added in the arm stirrer that 600g (80.27% quality) water is housed, be made into mixed solution, and then combination ash is slowly added in mixed solution, stir, form laboratory blocking agent sample 6#.This sample water gray scale is 4.07.
Effect experimental
Embodiment 1
Adopt the 7th article of oil well simulation compressive strength test in GB/T 19139-2003 oil-well cement test method, blocking agent 1#-6# slurry is sealed in die trial, HTHP maintenance (120 DEG C, 20.7MPa) 48h, after solidification, forms isopyknic blocking agent block.
Then 1#-6# blocking agent block is placed on kerosene and density 1.14g/cm
3formation water (formation water density 1.14g/cm
3, salinity 23 × 10
4mg/L, calcium ions and magnesium ions content about 1 × 10
4mg/L) between, visible blocking agent block swims on oil-water interfaces, shows because the density of blocking agent is between highly mineralized formation brines and crude oil, therefore automatically can sprawl on the oil-water interfaces of seam hole system.
Embodiment 2
Adopt said method, test blocking agent 1#-6#, result is as shown in the table:
It is the HTHP multiviscosisty curve of the slurry of blocking agent 1#-6# shown in Fig. 1-Fig. 6.Abscissa is time shaft (hours-minutes), and ordinate is respectively temperature (DEG C), pressure (MPa), denseness (Bc).Investigate temperature 120 DEG C, investigate pressure 75MPa, the increasing temperature and pressure time is set as 70min.Experimental facilities adopts HTHP multiviscosity meter.From the dynamic multiviscosisty curve of 8h, slurry denseness is basically stable at below 10Bc, particularly between 2.0-6.5, illustrates that blocking agent of the present invention has good infusion performance, can guarantee that safety is injected in construction.
As shown above, the static hardening time of blocking agent 1#-6# is 48-72h, and therefore in order to ensure solidifying completely, after using blocking agent of the present invention, the closed-in time is decided to be at least 72h.
Embodiment 3
Blocking agent 1#-6# is solidify to form each 10 pieces of blocking agent block, then airtight aging at 130 DEG C in conventional high temperature multiviscosity meter respectively, took out one piece of observation every 3 days, accumulation observation 30 days.Do not find any degraded and volume contraction phenomenon in this experiment, show that blocking agent has good stability.
Field trial example
The blocking agent of use prepared by embodiment 6 is at system in Tahe Oilfield carbonate oil reservoir (reservoir temperature 120 DEG C, formation water density 1.14g/cm
3, salinity 23 × 10
4mg/L, calcium ions and magnesium ions content about 1 × 10
4mg/L) application 7 mouthfuls of wells, 8 wells.Be twice, TH10421 well, TK847 well, TK834 well, TK744, TK666, TK608, TK1103 respectively, be seam hole type profit with section withdrawal well.Plug agent amount is designed to: when acidizing simulation crevice volume or communication Reservoir Body, blocking agent use amount is the 1/2-2/3 of fracturing fluid consumption.Without acid fracturing wells, with plugged well section 5-20m
3/ m calculates, and in site operation, discharge capacity 300-800L/min, adopts conventional oil pipe to inject above-mentioned oil well, and vexed well is after 72 hours, opening well and making production.8 wells time water blockoff, 6 wells obviously take effect (increasing oil more than 400t), and efficient 75%, add up to increase oily 8750t.
TH10421 well is for directly to go into operation without acid fracturing, and before water blockoff moisture 95%, plug face 6129.04m, pit shaft Open-Hole Section is remaining 14.04m only, belongs to seam hole type profit with section withdrawal well.As can be seen from Figure 7, adopt for twice the blocking agent of embodiment 3 to carry out water blockoff, all obtain positive effect.Wherein first time construction, accumulative injection 1.14g/cm
3low-density blocking agent 86.8m
3, 1.53g/cm
3cementing concrete (sealing compound) 6.8m
3, discharge capacity 380L/min, formation leakage is serious, and blocking agent normally enters stratum and do not play pressure, and casing pressure is always 0, and after stifled, plug face is constant.After using blocking agent of the present invention, decreasing water cut and increasing oil successful.Before stifled, electric pump is produced is a day production fluid 11.7t, day produce oil 0.59t, moisture 95%.After stifled, initial stage oil nozzle blowing is produced, and day production fluid 30t, day produce oil 29.7t are moisture hardly, i.e. the oily 1656t of tired increasing.
Along with water plugging effect is deteriorated gradually, moisturely again reach 98%, the blocking agent 120m of the second time construction usage embodiment of the present invention 6
3, 1.53g/cm
3cementing concrete (sealing compound) 15m
3, discharge capacity 740L/min, crosses replacement 6m
3, again recover blowing after stifled, add up to have increased oily 4282t.
TK847 well is that acid fracturing is gone into operation, potentiality segment length 6.5m.Fracturing fluid consumption 210m
3, accumulative injection 1.14g/cm
3low-density blocking agent 86.8m
3, discharge capacity 380L/min.Add up to have increased oily 1430t, period of validity was more than 190 days.The model of fracturing fluid employing (TulufanHami oil field company) sold is the fracturing fluid goods of (TH-GYL), it consists of: (0.5%) HPG melon glue (guar hydroxypropyltrimonium ammonium chloride)+(1.0%) LZ-1 cleanup additive+(1.0%) LP-1 demulsifier+(0.1%) LK-7 bactericide+(0.02%) pH value conditioning agent+(0.3%) LK-6 temperature stability agent+(1.0%) LK-8 clay stabilizer+(6%) LK-9 organic borate cross-linker+(1.0%) EFR friction reducer, all the other are water.Wherein, melon glue is generally guar hydroxypropyltrimonium ammonium chloride.
TK834 well is that acid fracturing is gone into operation, potentiality segment length 13m.Above-mentioned identical fracturing fluid consumption 286m
3, accumulative injection 1.14g/cm
3low-density blocking agent 121m
3, discharge capacity 380L/min.Add up to have increased oily 538t, period of validity was more than 170 days.
Shutoff method of the present invention can high temperature resistant (130 DEG C), resistance to high salt (23 × 10
4mg/L), utilize its water blockoff system low-density characteristic, blocking agent is detained the dividing plate solidifying to form selective water plugging at oil-water interfaces, has filled up domestic and international high temperature and high salt fracture and vug carbonate reservoir density selective water-plugging blank.Shutoff method of the present invention has a extensive future, and has stronger compliance, has promotional value.
Claims (7)
1. one kind is carried out the method for water blockoff to fracture-pore reservoir, the method comprises: the blocking agent selecting following composition, by percentage to the quality, described blocking agent comprises: cement 5.24-9.36%, micro-silicon 3.03-5.35%, sodium bentonite 4.01-5.43%, polymeric dispersant 0.52-0.55%, retarding agent 0.17-0.40%, the aqueous sodium carbonate accounting for 0.0008-0.0011% in sodium carbonate and water surplus, described polymeric dispersant be viscosity average molecular weigh 1,000,000 hydroxyethylcellulose; Described retarding agent is ethylenediamine tetramethylene phosphonic acid calcium, sodium ethylenediamine tetramethylenephosphonate or ethylenediamine pentamethylene phosphonic acids; Described cement median particle diameter D
50for being less than or equal to 1 μm; The median particle diameter D of described micro-silicon
50between 20-60nm;
Wherein, the water/binder ratio of this blocking agent is 4.07-6.28, and resistance to salinity reaches 23 × 10
4mg/L; Described blocking agent is injected oil well, and vexed well is after at least 72 hours, opening well and making production.
2. method of fracture-pore reservoir being carried out to water blockoff according to claim 1, is characterized in that, described plug agent amount is designed to: when acidizing simulation crevice volume or communication Reservoir Body, plug agent amount is the 1/2-2/3 of fracturing fluid consumption; Without during acid fracturing wells with plugged well section 5-20m
3/ m calculates.
3. method of fracture-pore reservoir being carried out to water blockoff according to claim 2, is characterized in that, described plug agent amount is designed to: without during acid fracturing wells with plugged well section 6.182-8.547m
3/ m calculates.
4. the method for fracture-pore reservoir being carried out to water blockoff according to any one of claim 1-3, is characterized in that, according to 300-800L/min discharge capacity, described blocking agent is injected oil well.
5. method of fracture-pore reservoir being carried out to water blockoff according to claim 4, it is characterized in that, by percentage to the quality, described blocking agent comprises: cement 5.74-8.25%, micro-silicon 3.28-4.72%, sodium bentonite 4.72-5.43%, polymeric dispersant 0.53-0.54%, retarding agent 0.19-0.33%, the aqueous sodium carbonate accounting for 0.0009-0.0011% in sodium carbonate and water surplus, wherein, the water/binder ratio of this blocking agent is 4.37-5.72.
6. method of fracture-pore reservoir being carried out to water blockoff according to claim 5, is characterized in that, described cement median particle diameter D
50for 0.8-1 μm.
7. the method for fracture-pore reservoir being carried out to water blockoff according to claim 1 or 6, is characterized in that, the density of described blocking agent is 1.07-1.14g/cm
3, solidification intensity is 0.22-0.43MPa.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201210061842.9A CN102587858B (en) | 2012-03-09 | 2012-03-09 | Method for blocking water for fracture and hole type reservoir |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201210061842.9A CN102587858B (en) | 2012-03-09 | 2012-03-09 | Method for blocking water for fracture and hole type reservoir |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN102587858A CN102587858A (en) | 2012-07-18 |
| CN102587858B true CN102587858B (en) | 2015-05-20 |
Family
ID=46477028
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201210061842.9A Active CN102587858B (en) | 2012-03-09 | 2012-03-09 | Method for blocking water for fracture and hole type reservoir |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN102587858B (en) |
Families Citing this family (13)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN102994057B (en) * | 2012-12-12 | 2016-09-07 | 中国石油化工股份有限公司 | A kind of temperature-resistant anti-salt profile control agent and preparation method thereof |
| CN103806890B (en) * | 2014-02-20 | 2016-03-23 | 中国石油化工股份有限公司 | Obtain the method for fracturing fluid consumption and acid solution consumption in fractured-vuggy reservoir acid fracturing method |
| CN104212422B (en) * | 2014-08-08 | 2017-02-08 | 左青山 | Heavy oil low cost modified clay-type water shutoff agent and usage method thereof |
| CN104879118B (en) * | 2015-04-21 | 2018-04-24 | 长江大学 | Cementing concrete returns deep with solid monitoring method and system under the conditions of the single, double drop ply in underground |
| CN107664020B (en) * | 2016-07-28 | 2020-02-04 | 中国石油化工股份有限公司 | Water plugging method for bottom water reservoir horizontal well |
| CN111073614A (en) * | 2018-10-18 | 2020-04-28 | 中国石油天然气股份有限公司 | Inorganic composite profile control and plugging agent and preparation method thereof |
| CN109826590B (en) * | 2019-02-27 | 2021-05-14 | 杨凌单色生物科技有限公司 | Water plugging and fracturing method for high-water-content old well in low-permeability oil and gas field |
| CN110424923B (en) * | 2019-08-06 | 2021-10-01 | 安东柏林石油科技（北京）有限公司 | Method for realizing self-plugging of water by accumulating packing particles, self-plugging water pipe column and well completion structure |
| CN110628401B (en) * | 2019-10-12 | 2021-11-16 | 青岛大学 | Preparation method of calcium ion sensitive oil well profile control water shutoff agent |
| CN110685637B (en) * | 2019-11-05 | 2021-06-01 | 西南石油大学 | Water plugging method for establishing large-area chemical partition plate on gas-water interface of water-gas reservoir |
| CN110702491B (en) * | 2019-11-11 | 2022-02-01 | 西南石油大学 | Method for determining water salinity and rock core salt washing degree of water-containing salt-soluble stratum |
| CN114427375A (en) * | 2020-09-21 | 2022-05-03 | 中国石油化工股份有限公司 | Karst cave oil reservoir density selective water plugging system and preparation method thereof |
| CN115093164B (en) * | 2022-04-23 | 2023-06-02 | 濮阳市华瑞通能源工程技术有限公司 | Adhesive agent and its preparation method |
Citations (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN1616589A (en) * | 2003-11-11 | 2005-05-18 | 新疆石油管理局钻井工艺研究院 | Potassium-calcium composite ion inhibitor for well drilling liquid |
| US7204310B1 (en) * | 2006-04-11 | 2007-04-17 | Halliburton Energy Services, Inc. | Methods of use settable drilling fluids comprising cement kiln dust |
| CN101857799A (en) * | 2010-06-28 | 2010-10-13 | 西南石油大学 | Curable leaking stoppage spacer fluid and preparation method thereof |
| CN102199418A (en) * | 2011-03-11 | 2011-09-28 | 中国石油大学(华东) | Inorganic solidifying system for controlling bottom water coning in fracture-cavity karst reservoir, and injection method thereof |
-
2012
- 2012-03-09 CN CN201210061842.9A patent/CN102587858B/en active Active
Patent Citations (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN1616589A (en) * | 2003-11-11 | 2005-05-18 | 新疆石油管理局钻井工艺研究院 | Potassium-calcium composite ion inhibitor for well drilling liquid |
| US7204310B1 (en) * | 2006-04-11 | 2007-04-17 | Halliburton Energy Services, Inc. | Methods of use settable drilling fluids comprising cement kiln dust |
| CN101857799A (en) * | 2010-06-28 | 2010-10-13 | 西南石油大学 | Curable leaking stoppage spacer fluid and preparation method thereof |
| CN102199418A (en) * | 2011-03-11 | 2011-09-28 | 中国石油大学(华东) | Inorganic solidifying system for controlling bottom water coning in fracture-cavity karst reservoir, and injection method thereof |
Also Published As
| Publication number | Publication date |
|---|---|
| CN102587858A (en) | 2012-07-18 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN102587858B (en) | Method for blocking water for fracture and hole type reservoir | |
| CN100543106C (en) | The preparation of composite cation blocking agent and stifled poly-using method | |
| EP2190942B1 (en) | Methods of using colloidal silica based gels | |
| CN103937475B (en) | Carbon dioxide acidification blocking remover and process of not reversely discharging raffinate after acidification | |
| CN103321606B (en) | A kind of Fracture with low permeability oil reservoir oilwell water shutoff screen method | |
| CN104087275B (en) | A kind of high-temperature-resistant high-salt tiny gels granular profile control agent and its preparation method and application | |
| CN105089600B (en) | The method that temporarily stifled diverting material auxiliary water horizontal well carries out drawing type water-jet transformation | |
| CN103013480A (en) | Modified petroleum coke granule composite profile control water blocking agent and multi-round bidirectional blocking control technology | |
| CN106566521B (en) | Preparation and application of anion clean fracturing fluid and gel breaker thereof | |
| CN104514531A (en) | Method for profile control and water shutoff in two-fluid process for three-low sandstone reservoir | |
| CN112210357B (en) | W/O/W type multiple emulsion water shutoff system and preparation method thereof | |
| CN103865513B (en) | A kind of surfactant self-priming is combined shale hydrofrac fluid and preparation method and application | |
| CN107739599A (en) | A kind of high temperature low-density water shutoff agent and preparation method thereof and onsite application method | |
| CN102746835B (en) | Carbonatite oil well density selectivity water shutoff agent and preparation process thereof | |
| CN102618232B (en) | Plugging agent for fractured-vuggy oil reservoir | |
| CN109826590A (en) | A kind of old well water blockoff fracturing process of hypotonic oil gas field High water cut | |
| CN106958438B (en) | A kind of method for removing blockage of polymer flooding blocking well | |
| CN103045215B (en) | Aluminate cement-based carbon dioxide corrosion resistant cement system for cementing of well | |
| EP1680572A1 (en) | Compositions and methods for preventing coagulation of water-in-oil emulsion polymers in aqueous saline well treating fluids | |
| CN111087997A (en) | Method for blocking water in oil reservoir and oil well | |
| CN103541683B (en) | Preposition leak stopping frozen glue grout in hot pursuit carries out the method for leak stopping | |
| CN103756656A (en) | Static gelatinous leaking stoppage liquid for stopping vicious leakage | |
| CN102911650A (en) | High-strength composite plugging system for plugging pipe flow channel and preparation method thereof | |
| CN102454396A (en) | Method for profile control by using formation polymer in offshore oil field polymer flooding process | |
| CN105567188B (en) | Auxiliary agent for improving the solidifying class sealing agent leak stopping performance of cyanogen and preparation method thereof, cyanogen coagulates class sealing agent |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| C06 | Publication | ||
| PB01 | Publication | ||
| C10 | Entry into substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| C14 | Grant of patent or utility model | ||
| GR01 | Patent grant |