CN105443094A - Multi-channel reservoir physical model of heavy oil thermal production well to be constructed and application thereof - Google Patents

Abstract

The invention relates to a multi-channel reservoir physical model of heavy oil thermal production well to be constructed. According to the model, a filling channel group which covers three penetration rate ranges of high, middle and low levels and is filled with oil-water with different degrees is prepared by stratum sand, crude oil and stratum water, or simulation stratum sand, simulation crude oil and simulation stratum water. By use of the model, in site channel sealing and water plugging by plugging agent injecting, solidification and plugging effects in a construction well of heavy oil thermal production are accurately simulated. Thus, simulation test of channel sealing and water plugging in heavy oil thermal production well is carried out, plugging agent property is regulated and optimized, and construction control data of in site channel sealing and water plugging in heavy oil well is tested and acquired to provide guidance for compiling construction designs of channel sealing and water plugging, to increase success rate of channel sealing and water plugging construction and to increase production. By applying the physical model and corresponding test method in guiding selective channel sealing and water plugging in site of heavy oil thermal production well, great economic benefit and social benefit will be brought about and the application aspect is quite broad.

Description

The multichannel reservoir model of a kind of heavy crude heat extraction well to be onstructed and application

Technical field

The invention belongs to technical field of petroleum extraction, relate to the multichannel reservoir model of a kind of heavy crude heat extraction well to be onstructed and analogue experiment method thereof and application, alter water-plugging technique by envelope carry out the multichannel reservoir model of the well to be onstructed of heavy crude heat extraction and analogue experiment method thereof and application in particular to a kind of.

Background technology

Current, the structure of world oil supply is constantly changing.In domestic crude output, heavy oil production proportion rises year by year.Viscous crude due to viscosity large, exploitation difficulty, substantially all adopts Simulation on whole pay zones mode, compared with developing, has that energy consumption is high, a difficult problem such as injection steamchanneling, oil well High water cut etc. with ordinary crude oils.Along with going deep into of Development of Viscous Crude Oil, the viscous crude main force producing regions such as China Petrochemical Industry's Shengli Oil Field, Henan Oil Field have entered the tail period stage, and ubiquity serious steam fingering, between onlap and well, vapour such as to alter at the problem.Meanwhile, alter linked up oil well and edge-bottom water layer due to vapour, thick oil thermal extraction is often at the several all after dates of production, and namely production fluid is moisture rises to more than 80%.Therefore, the vapour in heavy crude heat extraction exploitation is altered, water breakthrough problem makes well yield decline to a great extent, and production fluid intractability increases, and reduces recovery ratio and the economic benefit of heavy crude heat extraction exploitation to a great extent.

Heavy crude heat extraction development scheme is the oil production method grown up according to viscous crude viscosity-temperature characteristic.Usually, there is non-linear relation in viscosity and the temperature of viscous crude, and namely temperature raises the viscosity significantly reducing viscous crude.Simulation on whole pay zones mode injects a large amount of high temperature and high pressure steam exactly in oil reservoir, utilize the feature that steam heat capacity ratio is high, heat energy carrying capacity is strong, by the heating temperatures of part reservoir to the scope that Viscosity of Heavy Crude Oil can be made to be reduced to the conventional mechanical such as oil pumper, screw pump artificial lifting way can normally work.Current worldwide heavy oil block, more than 90% all adopts Simulation on whole pay zones.

Heavy crude heat extraction development scheme can be divided into two large classes, i.e. steam flooding and steam soak.Steam flooding mode is that oil well is divided into steam injection well and producing well, and steam injection well injects high temperature and high pressure steam incessantly, and producing well recovers the oil incessantly.Steam soak mode first in heavy oil wells, injects high temperature and high pressure steam, after injecting some, closing well several days, then in well under enter mechanical pump and recover the oil.

In steam-drive process, due to the impact of the unfavorable factors such as high mobility ratio by thick oil reservoir heterogeneous body, steam and viscous crude, in oil reservoir, often there is steam overlap and steam fingering, and then cause that vapour occurs between well and well and alter phenomenon.Vapour is altered and is made the vertical upper gas entry profile of oil reservoir uneven, and the uneven propelling of steam in plane, makes the swept volume of steam diminish, thus reduces heavy crude heat extraction recovery ratio and increase energy consumption.For shutoff vapour is altered, usual by high temperature resistant chemical plugging agent injection reservoir at present, as various inorganic sealing agent, organic sealing agent, foam plugging agent etc., rely on the effects such as sealing agent solidification, precipitation or foam viscous to alter vapour and carry out shutoff.

Another problem of puzzlement heavy crude heat extraction exploitation is exactly the water breakthrough problem of formation water.Because Viscosity of Heavy Crude Oil is very high, under normal circumstances, the viscous crude in heavy crude reservoir is in relative static conditions.After injecting high temperature and high pressure steam to reservoir, Viscosity of Heavy Crude Oil declines and starts flowing.Because vapour is altered, there is the situation such as fingering, channelling in steam in heavy crude reservoir, and after steamchanneling enters edge-bottom water layer, formation water will enter producing well, reduces well temperature, Viscosity of Heavy Crude Oil is increased, flow difficulties.Therefore, after being subject to formation water intrusion, often there is the situations such as output declines to a great extent, the moisture rapid rising of Produced Liquid in thick oil thermal extraction, in the not long time, oil well will stop production due to High water cut or water logging.

Vapour for thick oil thermal extraction is altered, edge-bottom water is altered and carried out envelope and alter water blockoff, is the effective means improving viscous crude resource Simulation on whole pay zones recovery ratio and development benefit, is also the vital task of current viscous crude field exploitation.Envelope alters water blockoff cost-effectively, while stable heavy crude heat extraction output, the thermal efficiency of steam soak and steam flooding can be improved, reduce the water treatment expense of ton oil energy consumption and minimizing production fluid, keep stable yields and economic development to have important practical significance to heavy crude reservoir.

Alter water blockoff field in thick oil thermal extraction envelope, prior art utilizes high temperature resistant chemical plugging agent to carry out shutoff to the fluid-channeling channel of steam, formation water.As (development of heat resist modification phenolic resins composite plugging agent system and performance evaluations such as Fu Minjie, Speciality Petrochemicals is in progress, Vol.14,2013 (3): 8-10) induration partial cross-linked for chemical gel is adopted phenolic resins parcel, make a kind of organo-mineral complexing particle blocking agent of high temperature resistant, high strength, for heavy oil thermal recovery fleeing proof water blockoff.(the Developing Application of GH-high temp profile control agent such as Longhua, special reservoirs, Vol.9,2002 (5): 88-90) the high temperature resistant blocking agent of PF resin and inorganic matter compound is developed, gelling temperature is between 50-120 DEG C, and gelation time is adjustable at 8-72h, and this system is under steam injection is washed away, sealing ratiod still reaches more than 90%, has good resistance to elevated temperatures and sealing characteristics.Zhao repaiies and waits very much (the stifled architectural study Overview of Progress of heavy crude heat extraction tune, special reservoirs, Vol.20, 2013 (4): 1-5) in conjunction with Chinese HEAVY OIL RESERVOIR characteristic sum exploitation via steam injection process conditions, describe the mechanism of action of conventional heavy crude heat extraction plugging agent, progress and application present situation, review polymer gel, solid phase particles blocking agent, foam, w/o type emulsion and salt precipitating 5 kinds of heavy crude heat extractions adjust stifled system, point out that the development trend of the profile control and water plugging of heavy crude heat extraction is synthesis low cost, the chemical agent of high temperature tolerance, exploitation compound is adjusted stifled system and is studied novel Low Damage environment-friendly type plugging technology.

Chinese patent CN1594827A discloses a kind of heavy oil wells water-plugging technology method for heavy oil wells shutoff water layer, suggestions for improvement, degradable organic blocking agent is utilized oil reservoir to be carried out to the selective shut-off of large radius, then high temperature resistant inorganic blocking agent is utilized to seal, different blocking agent adopts different pressures to inject, and realizes selective water plugging by Stress control and organic degraded.

Chinese patent CN101824979B discloses a kind of emulsion process profile control and water shutoff method of thickened oil steam-stimulated well, high temperature resistance water-in-oil emulsifier is adopted to inject in advance before steam injection or with steam injection steam-stimulated well, utilize the emulsion of remaining viscous crude in water layer to have high viscosity characteristic and carry out shutoff to water layer.

Alter water blockoff field in thick oil thermal extraction envelope, prior art mainly pays close attention to the high temperature resistant blocking agent of exploitation.To alter in water-blocking construction method research in envelope less, relevant report is also less.Because the development scheme of thick oil thermal extraction is special, its envelope alters the shutoff method that water-blocking construction method should be different from conventional oil field.Water blockoff field is altered to the demand of working design technology and prior art limitation for current thick oil thermal extraction envelope, study the envelope setting up thick oil thermal extraction special and alter shutoff method, plug water construction success rate is altered for raising envelope, reduce construction cost, promote the output after oil well plugging and the stable yields cycle all very important.

Summary of the invention

Technical problem to be solved by this invention is for the deficiencies in the prior art, provide the multichannel reservoir model of a kind of heavy crude heat extraction well to be onstructed, this model adopts the reservoir sand of well output to be onstructed, crude oil and formation water, or simulated formation sand, Simulation of Crude Oil and simulated formation water be made into cover high, medium and low three permeability range, in various degree by the filling channel group that profit is full of completely, this model can be used for simulated field heavy oil thermal recovery fleeing proof plug water construction well comparatively accurately and carry out the simulated tests such as blocking agent injection, solidification and plugging effect.

Present invention also offers a kind of analogue experiment method above-mentioned reservoir model being carried out to blocking agent injection, the method adopts above-mentioned reservoir model to alter the test of water blockoff Simulation evaluation to carry out thick oil thermal extraction envelope, regulates to optimize blocking agent performance and measure heavy oil wells envelope and alter water blockoff site operation control data, with the establishment instructing envelope to alter plug water construction design.

Present invention also offers a kind of heavy oil thermal recovery fleeing proof water-blocking construction method, the experimental technique parameter that the method utilizes above-mentioned analogue experiment method to obtain is to ask for working design technological parameter and relevant blocking agent performance parameter, these parameters may be used for instructing thick oil thermal extraction shutoff vapour to alter the establishment with water breakthrough working design, improve success rate and effect of increasing production that envelope alters plug water construction.

Invention further provides above-mentioned heavy oil thermal recovery fleeing proof water-blocking construction method and alter application in water blockoff site operation in the selective envelope of heavy crude heat extraction.

For this reason, first aspect present invention provides the multichannel reservoir model of a kind of heavy crude heat extraction well to be onstructed, it comprises three filling channel groups be arranged in parallel, described filling channel is made up of the filler loaded in passage and passage, each filling channel group comprises at least 2 filling channels, and described filler comprises reservoir sand, crude oil and formation water or simulated formation sand, Simulation of Crude Oil and simulated formation water;

Three filling channel groups are respectively: high permeability filling channel group, middle permeability filling channel group and low-permeability filling channel group, wherein,

High permeability filling channel group: water surveys the 100%-200% that permeability is well reservoir maximum permeability to be onstructed, and presses filling channel quantity by permeability by 10%-40% amplification terraced distribution, and fluid wherein 100% is formation water or simulated formation water.

Middle permeability filling channel group: water surveys the 50%-99% that permeability is well reservoir maximum permeability to be onstructed, and press filling channel quantity by permeability by 10%-40% amplification terraced distribution, in fluid wherein, 40%-60% is formation water or simulated formation water, and 40%-60% is crude oil or Simulation of Crude Oil.

Low-permeability filling channel group: water surveys the 70%-110% that permeability is the minimum permeability of well reservoir to be onstructed, and presses filling channel quantity by permeability by 10%-40% amplification terraced distribution, and fluid wherein 100% is crude oil or Simulation of Crude Oil.

In some embodiments of the invention, the span of the water survey permeability of high permeability filling channel group and middle permeability filling channel group is chosen according to the steam injection periodicity of well to be onstructed, wherein,

The water of high permeability filling channel group surveys permeability:

When the injection cycle is 1-2 round, choose 100%-130%;

When the injection cycle is 3-5 round, choose 131%-150%;

When the cycle of injecting >=6 round, choose 151%-200%.

The water of middle permeability filling channel group surveys permeability:

When the injection cycle is 1-6 round, choose 50%-80%;

When the cycle of injecting >=7 round, choose 81%-99%.

In other embodiments of the present invention, after filling channel test permeability, choose different fluid centering permeability filling channel group according to the recovery percent of reserves of well to be onstructed and carry out filling, be full of completely to make the interstitial space in each passage of middle permeability filling channel group, wherein

When recovery percent of reserves is greater than 15%, in fluid wherein, 50%-70% is formation water or simulated formation water;

When recovery percent of reserves is less than 15%, in fluid wherein, 50%-70% is crude oil or Simulation of Crude Oil.

When heavy oil wells recovery percent of reserves to be onstructed is high time, in reservoir, oil content declines, and the oil content therefore in physical model hole of the present invention also changes.

In the present invention, described reservoir model is adopt the reservoir sand of construction well output, crude oil and formation water, or simulated formation sand, Simulation of Crude Oil and simulated formation water make high, medium and low three permeability range of covering, in various degree by filling channel group that profit is full of completely.

In some embodiments of the invention, the radial section of described passage is polygon, circle or oval.The material forming described passage exterior contour comprises metal, macromolecular material or hydraulicity inorganic coagulation material.

In the present invention, described metal includes but not limited to ordinary carbon steel, 304 stainless steels, various alloy steel, cast iron, copper, aluminium etc.; Described macromolecular material includes but not limited to polyolefin, polyurethane and polyamide etc., and wherein polyolefin can be such as High molecular weight polyethylene; Described hydraulic inorganic coagulation material includes but not limited to portland cement, aluminate cement, sulphate aluminium cement and ferrous aluminate cement etc.

Also known as " mineral rubber gel material ", term described in the present invention " inorganic coagulation material " refers to that self is through series of physical, chemical action, or after mixing with other materials (as water etc.) together with through series of physical, chemical action, hard solid can be become by oar body, and loose material (as sand, stone etc.) or block, flaky material (as brick, stone etc.) can be cemented to overall material.Air hardening cementitious materials can only harden in atmosphere, and can only keep in atmosphere or develop its intensity, as gypsum, lime etc.Hydraulic cementing materials then can not only in atmosphere, and can harden better in water, keeps and develops its intensity, as portland cement etc.

In some embodiments of the invention, the cross section of described passage is circular, and the length of described passage is 200.0-1000.0mm, and internal diameter is 20.0-200.0mm.The tubing forming described passage exterior contour is straight tube.

According to the reservoir model of heavy oil thermal recovery fleeing proof water blockoff of the present invention well to be onstructed, be provided with the filling channel group of high, medium and low three permeability grade respectively, multiple filling channel is comprised in its each filling channel group, by the permeability of each filling channel in reasonable disposition each filling channel group and profit filling proportion and degree, the HEAVY OIL RESERVOIR after the certain round of Simulation on whole pay zones can be simulated well, improve the degree of accuracy of result of the test.Therefore, this reservoir model is mainly used to that Study In Reservoir heterogeneity of petrophysical property difference is large, the heavy crude reservoir of core sample permeability grade Kmn >=1.5.

Second aspect present invention provides the analogue experiment method that a kind of reservoir model described to the first aspect of the present invention carries out blocking agent injection, and it comprises:

Steps A, injects in three filling channel groups by blocking agent;

Step B, judge to inject the middle part whether blocking agent leading edge arrives permeability filling channel group, and in blocking agent leading edge does not arrive during the middle part of permeability filling channel group, adjustment blocking agent experiment apparent viscosity and blocking agent experiment injection rate, make blocking agent test actual injection rate equal blocking agent empirical theory injection rate time, inject the middle part that blocking agent leading edge arrives permeability filling channel group;

Step C, record experimental technique parameter, described experimental technique parameter comprises blocking agent experiment apparent viscosity, blocking agent experiment injection rate, blocking agent tests initial injection pressure, blocking agent tests flowing pressure gradient, blocking agent tests shutoff pressure and experiment viscous crude phase starting pressure;

In stepb, blocking agent is kept to test actual injection rate constant;

Blocking agent tests the voids volume sum that actual injection rate is all passages in permeability filling channel group in the voids volume and 50% of all passages in high permeability filling channel group;

Described blocking agent empirical theory injection rate is the 45%-55% sum (or the summation of the fluid volume gone out by displacement) of the oil phase of all passages in the aqueous phase volume of all passages in high permeability filling channel group and middle permeability filling channel group and/or aqueous phase volume.

According to the present invention, in stepb, when in central permeability filling channel group, the liquid outlet quantity of all channel outlets is equivalent to the 45%-55% of the voids volume of all passages in middle permeability filling channel group, be then judged as injecting the middle part that blocking agent leading edge has arrived permeability filling channel group.

During the leading edge of blocking agent of the present invention arrives the middle part of permeability filling channel group refer to the leading edge of injecting blocking agent along injection direction arrive permeability filling channel group each passage physical midpoint cross section ± 10cm within the scope of, during the leading edge of preferred blocking agent arrives along injection direction in permeability filling channel group each passage physical midpoint cross section ± 6cm within the scope of.More preferred, during the leading edge of blocking agent arrives along injection direction in permeability filling channel group each passage physical midpoint cross section ± 2cm within the scope of.Even more preferred, the physical midpoint cross section of each passage in permeability filling channel group during the leading edge of blocking agent arrives along injection direction.

In one embodiment of the invention, in stepb, adjustment blocking agent experiment apparent viscosity and blocking agent experiment injection rate, when making blocking agent experiment injection pressure reach blocking agent experiment shutoff force value, at least the blocking agent of 50v%-80v% is all injected among high permeability filling channel group.

In some embodiments of the invention, carry out in blocking agent simulated injection experimentation utilizing reservoir model of the present invention, first adjustment is optimized to the rheological property of blocking agent, its control method is: according to the flow regime of blocking agent in simulated test, the rheological property (mainly adjusting blocking agent experiment apparent viscosity) of adjustment blocking agent, blocking agent is made to test injection pressure when reaching blocking agent experiment shutoff force value, have and accounted for total injection rate 50% and all enter among high permeability filling channel group with the injection blocking agent of upper volume, more excellently all to enter among high permeability filling channel group with the injection blocking agent of upper volume for accounting for total injection rate 70%.Record now blocking agent experiment charge velocity, blocking agent experiment apparent viscosity and blocking agent experiment injection pressure, when this k value is exactly blocking agent preparation in site operation, need the working design apparent viscosity value reached; This blocking agent experiment charge velocity (the blocking agent cumulative volume percentage injected in the unit interval) is the working design injection rate of site operation blocking agent after converting; This blocking agent experiment injection pressure is the higher limit of the working design injection pressure of blocking agent in site operation.

In other embodiments of the present invention, inject the simulated test of reservoir model in blocking agent, need reading to record following data as experimental technique parameter, for estimating parameters of construction technology in design heavy oil thermal recovery fleeing proof plug water construction scheme.

Blocking agent experiment injection rate: the maximum volume injecting filling channel group in parallel in the blocking agent unit interval.

Initial experiment injection pressure: blocking agent injects minimum injection pressure during high permeability filling channel group.

Blocking agent experiment flowing pressure gradient: blocking agent in the process of lasting injection high permeability filling channel group, the rising gradient of pressure.

Blocking agent experiment shutoff pressure: the maximum injection pressure during blocking agent arrives in the middle part of permeability filling channel group in process.

Experiment viscous crude phase starting pressure: in simulated test, blocking agent enters maximum injection pressure during low-permeability filling channel group.

Third aspect of the present invention provides a kind of heavy oil thermal recovery fleeing proof water-blocking construction method, and the experimental technique parameter that the analogue experiment method of its working design technological parameter according to above-mentioned second aspect obtains calculates and obtains, wherein,

Blocking agent working design apparent viscosity equals blocking agent experiment apparent viscosity;

Working design maximum pressure equals experiment viscous crude phase starting pressure;

Blocking agent working design injection rate calculates according to formula (I):

Blocking agent working design injection rate=η × blocking agent experiment injection rate (I)

In formula (I),

The unit of blocking agent working design injection rate is L/min;

The unit of blocking agent experiment injection rate is ml/min;

η is the conversion coefficient between blocking agent experiment injection rate and blocking agent working design injection rate, calculates according to formula (II):

The span of η is 1.0 × 10 ⁵-15.0 × 10 ⁵;

The blocking agent working design normal temperature cure time be the 1-10 of blocking agent working design injection length doubly, described blocking agent working design injection length calculates according to formula (III):

According to the present invention, described blocking agent working design injection rate equals high seepage channel volume, and described high seepage channel volume calculates according to formula (IV):

$V_X=(M_{\mathrm{oil}}-L\×\mathrm{\π}\×r_{\mathrm{heat}}^2\×\mathrm{\φ}\×S_o)\×K_{\mathrm{channel}}\÷10000---\left(\mathrm{IV}\right)$

In formula (IV):

Vx: high seepage channel volume, m ³;

M _oil: oil well cumulative oil production, m ³;

L: straight well is core intersection, horizontal well is oil reservoir horizontal section length, m;

π：3.14；

R _heat: only rely on heat exchange pattern, inject the covering radius of steam heat effect, m;

r _heatcover the average pore of pit shaft reservoir, %;

S _o: r _heatcover the average oil saturation of pit shaft reservoir, %;

K _channel: high seepage channel coefficient, its span is 0.01%-30%.

In Specific construction design, high seepage channel coefficient should carry out value according to the production status of oil well.

In some embodiments of the invention, the span of described high seepage channel coefficient comprises further:

The injection cycle of new brought in well is when being 1-2,0.01%-1.99%;

The injection cycle of new brought in well is when being 3-5,2.0%-4.99%;

New brought in well injection cycle >=6 rounds, 5%-10%;

For the long-term shutdowns well caused due to High water cut, 10.01%-30%.

The fuel factor injecting steam described in the present invention comprises convection current, radiation and heat transfer three kinds, and wherein convection current is direct heating, and operating distance is short, rapid-action; Radiation and heat transfer are due to the restriction by subsurface reservoir lithosome, and operating distance is short, and onset is slow.

Term described in the present invention " high seepage channel volume " refers to that thick oil thermal extraction is after certain production time, and the injection steam formed or formation water are between well or the fluid-channeling channel volume of oil well-edge-bottom water interflow.。

Term described in the present invention " fluid-channeling channel " refers to due to the original non-homogeneity of oil reservoir or the high seepage channel from a bite oil well or steam injection well to another mouthful of oil well or edge-bottom water layer that injects steam flush and formed at oil reservoir, after forming high seepage channel, steam is injected in thermal recovery will enter other producing wells along this passage, cause producing well generation vapour to be altered; Formed after high permeability path, formation water will enter producing well along this passage, cause producing well generation water breakthrough and High water cut or water logging.Near thick oil thermal extraction, in reservoir, the formation of steam or formation water fluid-channeling channel is formed by combined factors effects such as reservoir heterogeneity, fluid simulator, completion mode, injection steam physics chemical action, gravity effect, producing pressure differentials.Specifically, thick oil thermal extraction fluid-channeling channel is with thermal recovery manufacturing process, is formed gradually in reservoir, and it comprises alters the high seepage channel of well to adjacent oil well or edge-bottom water layer from vapour.

Can find out, time in the present invention by calculating high seepage channel volume and knowing construction, total injection rate of blocking agent is actually the fluid-channeling channel situation needing shutoff according to oil well, estimates the volume needing shutoff.

According to third aspect of the present invention provide in heavy oil thermal recovery fleeing proof water-blocking construction method formula (IV) the blocking agent working design injection rate in the on-the-spot plugging construction of well to be onstructed can be calculated.The blocking agent that the blocking agent that the simulated experiment that the described to the first aspect of the present invention reservoir model of analogue experiment method provided according to a second aspect of the present invention carries out blocking agent injection can obtain well to be onstructed injects simulated experiment tests actual injection rate, and the blocking agent that the blocking agent of well to be onstructed injects simulated experiment tests the voids volume sum of voids volume that actual injection rate is all passages of high permeability filling channel group and all passages of 50% permeability filling channel group.Certain incidence relation is there is between the blocking agent working design injection rate that the blocking agent that the blocking agent of well to be onstructed injects simulated experiment tests actual injection rate and the on-the-spot plugging construction of well to be onstructed, its conversion coefficient can be calculated by formula (II), proportionate relationship is set up thus between simulation laboratory test of the present invention and site operation, thus reach the effect using simulation laboratory test result to carry out guide field construction, change current thick oil thermal extraction envelope and alter the present situation that plug water construction only relies on micro-judgment.

In certain embodiments of the present invention, the heavy oil thermal recovery fleeing proof water-blocking construction method described in third aspect of the present invention is utilized to obtain parameters of construction technology, performance indications and the construction parameter of blocking agent needed for efficient shutoff thick oil thermal extraction steam or formation water fluid-channeling channel can be obtained thus, such as, under reservoir temperature, apparent viscosity is 30-70mPa.s, tool high viscosity and have strong thixotropy, the injection pressure upper limit is 8MPa, charge velocity be 1.5v%/hour etc.The design that thick oil thermal extraction envelope alters plug water construction scheme can be carried out further based on above-mentioned parameter, and by carrying out the carrying out of guide field construction to the control of blocking agent rheological characteristic, charge velocity and injection pressure in work progress, ensure that the envelope of thick oil thermal extraction alters plug water construction effect.

Water-blocking construction method is altered according to thick oil thermal extraction envelope of the present invention, controlled by blocking agent property regulation and injection technology, can by blocking agent Selective implantation to the fluid-channeling channel needing shutoff, realize selective shut-off, effective control thick oil thermal extraction vapour is altered, water breakthrough phenomenon, reduce produced liquid in oil well moisture content, increase heavy oil production.

Term described in the present invention " selective shut-off " refers to that selective envelope alters water blockoff, is to causing thermal production well vapour to be altered or the high seepage channel of water breakthrough carries out targeted shutoff, controls to inject steamchanneling, reduces oil well and produce water.

According to the reservoir model of the heavy crude heat extraction well to be onstructed proposed in above-mentioned three aspects of the present invention, the analogue experiment method of blocking agent injection is carried out to described reservoir model and heavy oil thermal recovery fleeing proof water-blocking construction method both can independently be used to guide laboratory test and/or site operation, a kind of comprehensive thick oil thermal extraction envelope of formation can be combined with each other again and alter water-blocking construction method, the method can after selected envelope alters water blockoff plan construction well, the oil reservoir of the selected oil well of analysis and research, development data, set up reservoir model to carry out envelope and alter water blockoff simulated test, in the different blocking agent performance of indoor test and construction technology on the impact of plugging effect, the scheme of success rate and effect of increasing production the best is filtered out in conjunction with site operation requirement, form the working design that the selective envelope of high temperature resistant sealing agent alters water blockoff.The method successfully solves thick oil thermal extraction and seals three key issues of altering in water blockoff process:

The first, oil well needs the fluid-channeling channel situation of shutoff, estimates the volume and sealing agent consumption that need shutoff.

The second, realize the sealing agent performance requirement that effective shutoff needs.

3rd, how to realize the selective shut-off to fluid-channeling channel in construction.

The present invention the 4th aspect provides a kind of construction method according to third aspect of the present invention and alters application in water blockoff site operation in the selective envelope of thick oil thermal extraction.

In a specific embodiment of the present invention, altering or the thick oil thermal extraction of formation water water breakthrough for there is steam vapour, carrying out the construction that blocking agent envelope alters water blockoff, forming site operation scheme.Described construction method comprises the steps:

1) construction well reservoir model is set up;

2) carry out the injection test of simulation sealing agent, obtain working design data;

3) the sealing agent volume that plugging construction injects is calculated;

4) Design of Performance of sealing agent is carried out;

5) the on-the-spot scheme of plugging construction is worked out;

6) plugging construction is carried out.

The method is applied through scene, achieves the moisture and effect of increasing production of significant reduction.

In the present invention, term used " blocking agent " is also known as " sealing agent ", refers to and to prepare on ground and to inject subterranean oil gas reservoir, can carry out chemical agent or the chemical agent mixture of shutoff to the high seepage channel of entry well fluid channelling.Blocking agent basic recipe, such as, can be: 5% stabilizing agent+10% crosslinking agent+20% filler.

Term described in the present invention " charge velocity " refers to blocking agent injection rate and the ratio injecting blocking agent cumulative volume in the unit interval, laboratory test and site operation can be united by conversion coefficient η.

Term described in the present invention " formation water " or claim " oil-reservoir water " refer to Bian Shui and Di Shui of oil reservoir edge and bottom, intermediary water and with the general name of crude oil with the irreducible water of layer.Remain in the water in hole when irreducible water is reservoir formation, it and oil gas coexist but do not participate in flowing, but its distribution characteristics in oil reservoir microscopic void directly affects oil reservoir oil saturation.

Term described in the present invention " simulated formation water " refers to according to zwitterion quantity contained in certain formation water and ratio, prepares, form the salinity water identical or close with this formation water at indoor employing distilled water and various salt.

Term described in the present invention " reservoir sand " refers to that heavy oil wells in process of production, along with profit is from the reservoir sand grains (Chinese heavy crude reservoir major part all exists with loose sand, and the main composition of reservoir rock is exactly the sand grains of loose cementation) of down-hole extraction.

Term described in the present invention " simulated formation sand " refers to particle size range according to reservoir sand and domain size distribution rule, the similar particle size range picked out and the quartz sand of domain size distribution rule.

Term described in the present invention " Simulation of Crude Oil " refers to the dewatered oil treating plugging construction heavy oil wells output, or the dewatered oil of adjacent well output.

Term described in the present invention " water survey permeability " refers to the method for testing according to permeability, adopts distilled water to carry out testing obtained permeability as tested media.

Term described in the present invention " blocking agent leading edge " or " leading edge of blocking agent " refer on blocking agent injection direction, inject blocking agent advancing front foremost.

Term described in the present invention " middle part of middle permeability filling channel group " refers to the middle permeability filling channel group radial section (cross section) residing for physical midpoint in the axial direction.

Term of the present invention " multichannel reservoir model " refers to and is formed in parallel by the filling channel group that profit is full of in various degree by three groups containing multiple filling channel respectively, covers the heavy crude heat extraction reservoir model of high, medium and low three permeability range respectively.

Because in domestic crude output, heavy oil production proportion rises year by year, along with going deep into of Development of Viscous Crude Oil, the viscous crude main force producing regions such as Sinopec Shengli Oil Field, Henan Oil Field have entered the tail period stage, thick oil thermal extraction is often at the several all after dates of production, and namely production fluid is moisture rises to more than 80%.Production fluid intractability increases, and reduces recovery ratio and the economic benefit of heavy crude heat extraction exploitation to a great extent.Therefore, utilize the reservoir model of heavy oil thermal recovery fleeing proof plug water construction well of the present invention, the analogue experiment method described reservoir model being carried out to blocking agent injection and heavy oil thermal recovery fleeing proof water-blocking construction method to carry out envelope and alter plug water construction, once enter practicality, to produce huge economic and social profit, application prospect is very wide.

Detailed description of the invention

For making the present invention easier to understand, describe the present invention in detail below in conjunction with embodiment, these embodiments only play illustrative effect, are not limited to range of application of the present invention.

Embodiment

Embodiment 1:

Utilize physical model of the present invention, simulating lab test before plugging construction and working design are carried out to certain oil-field thick-oil thermal recovery producing well A1 well, the reservoir maximum permeability of A1 well to be onstructed is 500mD, minimum permeability is 100mD, 6 rounds are produced, the method utilizing physical model of the present invention and analogue experiment method to carry out working design is described for the working design of this mouthful of well and implementation result, and detailed process is as follows:

(1) the multichannel reservoir model of heavy crude heat extraction well to be onstructed is set up

The reservoir sand of A1 well output, crude oil and formation water sample is adopted to set up the reservoir multichannel physical model of heavy oil thermal recovery fleeing proof plug water construction well, produce the filling channel group of high, medium and low three permeability range, and be full of completely with crude oil, formation water respectively, the detailed data of three filling channel groups is as follows:

High permeability filling channel group:

Filling channel H1#, length 1.0 meters, interior diameter 100mm, outside material is stainless steel, and permeability is 1000mD, voids volume 183cm ³, 100% formation water.

Filling channel H2#, length 1.0 meters, interior diameter 100mm, outside material is stainless steel, and permeability is 660mD, voids volume 178cm ³, 100% formation water.

Middle permeability filling channel group:

Filling channel M1#: length 1.0 meters, interior diameter 100mm, outside material is stainless steel, and permeability is 400mD, voids volume 146cm ³, wherein fluid, 60% is that formation water, 40% is for crude oil.

Filling channel M2#: length 1.0 meters, interior diameter 100mm, outside material is stainless steel, and permeability is 260mD, voids volume 132cm ³, wherein fluid, 60% is that formation water, 40% is for crude oil.

Low-permeability filling channel group:

Filling channel L1#: length 1.0 meters, interior diameter 100mm, outside material is stainless steel, and permeability is 110mD, voids volume 114cm ³, 100% crude oil.

Filling channel L2#: length 1.0 meters, interior diameter 100mm, outside material is stainless steel, and permeability is 66mD, voids volume 108cm ³, 100% crude oil.

(2) sealing agent is carried out to the reservoir model of set up heavy crude heat extraction well to be onstructed and inject simulated test, ask for working design data

The voids volume sum of voids volume that blocking agent amount is all passages of high permeability filling channel group and all passages of 50% permeability filling channel group is injected, i.e. 500cm in (I) above-mentioned reservoir model ³.

(II) calculates A1 well shutoff water breakthrough passage by formula (IV) needs sealing agent working design injection rate:

$V_X=(M_{\mathrm{oil}}-L\×\mathrm{\π}\×r_{\mathrm{heat}}^2\×\mathrm{\φ}\×S_o)\×K_{\mathrm{channel}}\÷10000---\left(\mathrm{IV}\right)$

In formula (IV):

V _x: high seepage channel volume, m ³;

M _oil: oil well cumulative oil production, m ³;

L: straight well is core intersection, horizontal well is oil reservoir horizontal section length, m;

π：3.14；

R _heat: only rely on heat transfer, the covering radius of steam heat effect, m;

r _heatcover the average pore of pit shaft reservoir, %;

S _o: r _heatcover the average oil saturation of pit shaft reservoir, %;

K _channel: high seepage channel coefficient, span: 0.01-30%;

A1 well calculates data value, oil well cumulative oil production 3765m ³, effective pay thickiness L gets 5.8m, r _heat=25m, degree of porosity average oil saturation ρ=50%, K _channelvalue is 10%, then calculate V _x(i.e. the working design consumption of blocking agent) is: 267m ³.

(III) opens injection pump, with certain injection rate, blocking agent is injected three groups of filling channels in parallel, and collect, measure the fluid situation of the variant permeability port of export of high, medium and low three groups of filling channels, in the middle of the liquid outlet quantity summation of permeability filling channel group two ports of export when reaching the 45%-55% of its voids volume, namely can be considered the leading edge of blocking agent arrive in the middle part of permeability filling channel group.Repetition test, continuous adjustment blocking agent experiment apparent viscosity and blocking agent experiment injection rate, make blocking agent test actual injection rate when reaching blocking agent empirical theory injection rate, the leading edge injecting sealing agent arrives the middle part of permeability filling channel group, and it is as follows to record related data:

Blocking agent experiment apparent viscosity: 40mPa.s;

Blocking agent experiment injection rate: 0.80ml/min;

Blocking agent tests initial injection pressure: 0.0MPa;

Blocking agent experiment flowing pressure gradient: 0.015MPa/ml;

Blocking agent experiment shutoff pressure: 6.2MPa;

Experiment viscous crude phase starting pressure: 9MPa.

(3) according to test and well information, the Design of Performance of resistance to sealing agent is completed

Due to the yardstick of laboratory test instrument and on-the-spot injection device and reservoir yardstick difference very large, the conversion coefficient η obtained between blocking agent experiment injection rate and blocking agent working design injection rate through indoor and field trial evaluation is 5.34 × 10 ⁵, calculating corresponding blocking agent working design injection rate is 42.7L/min.

The blocking agent working design consumption determined according to A1 well data and experiment parameter and blocking agent working design injection rate calculate, and complete 267m with 42.7L/min speed ³the working design injection length of blocking agent is 104.2 hours, then the working design of the blocking agent normal temperature consolidated time should be greater than 105 hours, to ensure construction safety.

According to the plugging construction parameter that logistics organizations is determined be:

Blocking agent working design apparent viscosity: 40mPa.s;

Blocking agent working design injection rate: 42.7L/min;

The initial injection pressure of blocking agent working design: 0.0MPa;

Working design maximum pressure: 9MPa.

Embodiment 2:

Utilize physical model of the present invention, simulating lab test before plugging construction and working design are carried out to certain oil-field thick-oil thermal recovery producing well A2 well, the reservoir maximum permeability of A2 well to be onstructed is 1000mD, minimum permeability is 300mD, 4 rounds are produced, the method utilizing physical model of the present invention and analogue experiment method to carry out working design is described for the working design of this mouthful of well and implementation result, and detailed process is as follows:

(1) the multichannel reservoir model of heavy crude heat extraction well to be onstructed is set up

The reservoir sand of A2 well output, crude oil and formation water sample is adopted to set up the reservoir model of heavy oil thermal recovery fleeing proof plug water construction well, produce the filling channel group of high, medium and low three permeability range, and be full of completely with crude oil, formation water respectively, the detailed data of three groups of filling channels is as follows:

High permeability filling channel group:

Filling channel H1#, length 600mm, interior diameter 200mm, outside material is stainless steel, and permeability is 1310mD, voids volume 220cm ³, 100% formation water.

Filling channel H2#, length 600mm, interior diameter 200mm, outside material is stainless steel, and permeability is 1500mD, voids volume 240cm ³, 100% formation water.

Middle permeability filling channel group:

Filling channel M1#: length 600mm, interior diameter 200mm, outside material is stainless steel, and permeability is 500mD, voids volume 150cm ³, wherein fluid, 50% is that formation water, 50% is for crude oil.

Filling channel M2#: length 600mm, interior diameter 200mm, outside material is stainless steel, and permeability is 600mD, voids volume 156cm ³, wherein fluid, 50% is that formation water, 50% is for crude oil.

Low-permeability filling channel group:

Filling channel L1#: length 600mm, interior diameter 200mm, outside material is stainless steel, and permeability is 150mD, voids volume 120cm ³, 100% crude oil.

Filling channel L2#: length 600mm, interior diameter 200mm, outside material is stainless steel, and permeability is 150mD, voids volume 120cm ³, 100% crude oil.

(2) sealing agent is carried out to the reservoir model of set up heavy crude heat extraction well to be onstructed and inject simulated test, ask for working design data

The voids volume sum of voids volume that blocking agent amount is all passages of high permeability filling channel group and all passages of 50% permeability filling channel group is injected, i.e. 613cm in (I) above-mentioned reservoir model ³.

(II) calculates A2 well shutoff water breakthrough passage by formula (IV) needs sealing agent working design injection rate:

$V_X=(M_{\mathrm{oil}}-L\×\mathrm{\π}\×r_{\mathrm{heat}}^2\×\mathrm{\φ}\×S_o)\×K_{\mathrm{channel}}\÷10000---\left(\mathrm{IV}\right)$

In formula (IV):

V _x: high seepage channel volume, m ³;

M _oil: oil well cumulative oil production, m ³;

L: straight well is core intersection, horizontal well is oil reservoir horizontal section length, m;

π：3.14；

R _heat: only rely on heat transfer, the covering radius of steam heat effect, m;

r _heatcover the average pore of pit shaft reservoir, %;

S _o: r _heatcover the average oil saturation of pit shaft reservoir, %;

K _channel: high seepage channel coefficient, span: 0.01-30%;

A2 well calculates data value, oil well cumulative oil production 4700m ³, effective pay thickiness L gets 7m, r _heat=20m, degree of porosity average oil saturation ρ=45%, K _channelvalue is 4.9%, then calculate V _x(i.e. the working design consumption of blocking agent) is: 180m ³.

(III) opens injection pump, with certain injection rate, blocking agent is injected three groups of filling channels in parallel, and collect, measure the fluid situation of high, medium and low three groups of different permeability filling channel ports of export, in the middle of the liquid outlet quantity of permeability filling channel group port of export when reaching the 45%-55% of its voids volume, namely can be considered blocking agent arrive in the middle part of permeability filling channel group.Repetition test, continuous adjustment blocking agent experiment apparent viscosity and blocking agent experiment injection rate, make blocking agent test actual injection rate when reaching blocking agent empirical theory injection rate, the leading edge injecting sealing agent arrives the middle part of permeability filling channel group, and it is as follows to record related data:

Blocking agent experiment apparent viscosity: 26mPa.s;

Blocking agent experiment injection rate: 0.90ml/min;

Blocking agent tests initial injection pressure: 0.0MPa;

Blocking agent experiment flowing pressure gradient: 0.010MPa/ml;

Blocking agent experiment shutoff pressure: 5.0MPa;

Experiment viscous crude phase starting pressure: 7.5MPa.

(3) according to test and well information, the Design of Performance of resistance to sealing agent is completed

Due to the yardstick of laboratory test instrument and on-the-spot injection device and reservoir yardstick difference very large, the conversion coefficient η obtained between blocking agent experiment injection rate and blocking agent working design injection rate through indoor and field trial evaluation is 2.93 × 10 ⁵, calculating corresponding blocking agent working design injection rate is 264L/min.

The blocking agent working design consumption determined according to A2 well data and experiment parameter and blocking agent working design injection rate calculate, and complete 180m with 180L/min speed ³the working design injection length of blocking agent is 11 hours, then the working design of the blocking agent normal temperature consolidated time should much larger than 40 hours, to ensure construction safety.

According to the plugging construction parameter that logistics organizations is determined be:

Blocking agent working design apparent viscosity: 26mPa.s;

Blocking agent working design injection rate: 264L/min;

The initial injection pressure of blocking agent working design: 0.0MPa;

Working design maximum pressure: 7.5MPa.

Embodiment 3:

Physical model of the present invention is utilized to carry out the simulating lab test before plugging construction and working design to certain oil-field thick-oil thermal recovery producing well A3 well, the reservoir maximum permeability of A3 well to be onstructed is 800mD, minimum permeability is 100mD, 2 rounds are produced, the method utilizing physical model of the present invention and analogue experiment method to carry out working design is described for the working design of this mouthful of well and implementation result, and detailed process is as follows:

(1) the multichannel reservoir model of heavy crude heat extraction well to be onstructed is set up

The reservoir sand of A3 well output, crude oil and formation water sample is adopted to set up the reservoir model of heavy oil thermal recovery fleeing proof plug water construction well, produce the filling channel of high, medium and low three permeability range, and be full of completely with crude oil, formation water respectively, the detailed data of three groups of filling channels is as follows:

High permeability filling channel group:

Filling channel H1#, length 200mm, interior diameter 50mm, outside material is stainless steel, and permeability is 1040mD, voids volume 38cm ³, 100% formation water.

Filling channel H2#, length 200mm, interior diameter 50mm, outside material is stainless steel, and permeability is 900mD, voids volume 35cm ³, 100% formation water.

Filling channel H3#, length 200mm, interior diameter 50mm, outside material is stainless steel, and permeability is 830mD, voids volume 28cm ³, 100% formation water.

Filling channel H4#, length 200mm, interior diameter 50mm, outside material is stainless steel, and permeability is 800mD, voids volume 26cm ³, 100% formation water.

Middle permeability filling channel group:

Filling channel M1#: length 200mm, interior diameter 50mm, outside material is stainless steel, and permeability is 640mD, voids volume 20cm ³, wherein fluid, 40% is that formation water, 60% is for crude oil.

Filling channel M2#: length 200mm, interior diameter 50mm, outside material is stainless steel, and permeability is 480mD, voids volume 18cm ³, wherein fluid, 40% is that formation water, 60% is for crude oil.

Filling channel M3#: length 200mm, interior diameter 50mm, outside material is stainless steel, and permeability is 400mD, voids volume 16cm ³, wherein fluid, 40% is that formation water, 60% is for crude oil.

Low-permeability filling channel group:

Filling channel L1#: length 200mm, interior diameter 50mm, outside material is stainless steel, and permeability is 50mD, voids volume 8cm ³, 100% crude oil.

Filling channel L2#: length 200mm, interior diameter 50mm, outside material is stainless steel, and permeability is 50mD, voids volume 8cm ³, 100% crude oil.

(2) sealing agent is carried out to the reservoir model of set up heavy crude heat extraction well to be onstructed and inject simulated test, ask for working design data

The voids volume sum of voids volume that blocking agent amount is all passages of high permeability filling channel group and all passages of 50% permeability filling channel group is injected, i.e. 154cm in (I) above-mentioned reservoir model ³.

(II) calculates A1 well shutoff water breakthrough passage by formula (IV) needs sealing agent working design injection rate:

$V_X=(M_{\mathrm{oil}}-L\×\mathrm{\π}\×r_{\mathrm{heat}}^2\×\mathrm{\φ}\×S_o)\×K_{\mathrm{channel}}\÷10000---\left(\mathrm{IV}\right)$

In formula (IV):

V _x: high seepage channel volume, m ³;

M _oil: oil well cumulative oil production, m ³;

L: straight well is core intersection, horizontal well is oil reservoir horizontal section length, m;

π：3.14；

R _heat: only rely on heat transfer, the covering radius of steam heat effect, m;

r _heat cover the average pore of pit shaft reservoir, %;

S _o: r _heatcover the average oil saturation of pit shaft reservoir, %;

K _channel: high seepage channel coefficient, span: 0.01-30%;

A3 well calculates data value, oil well cumulative oil production 3000m ³, effective pay thickiness L gets 5m, r _heat=20m, degree of porosity average oil saturation ρ=50%, K _channelvalue is 1.9%, then calculate V _x(i.e. the working design consumption of blocking agent) is ≈ 40m ³.

(III) opens injection pump, with certain injection rate, blocking agent is injected three groups of filling channels in parallel, and collect, measure the fluid situation of high, medium and low three groups of different permeability filling channel ports of export, in the middle of the liquid outlet quantity of permeability filling channel group port of export when reaching the 45%-55% of its voids volume, namely can be considered blocking agent arrive in the middle part of permeability filling channel group.Repetition test, continuous adjustment blocking agent experiment apparent viscosity and blocking agent experiment injection rate, make blocking agent test actual injection rate when reaching blocking agent empirical theory injection rate, the leading edge injecting sealing agent arrives the middle part of permeability filling channel group, and it is as follows to record related data:

Blocking agent experiment apparent viscosity: 22mPa.s;

Blocking agent experiment injection rate: 0.60ml/min;

Blocking agent tests initial injection pressure: 0.0MPa;

Blocking agent experiment flowing pressure gradient: 0.015MPa/ml;

Blocking agent experiment shutoff pressure: 6.0MPa;

Experiment viscous crude phase starting pressure: 10.0MPa.

(3) according to test and well information, the Design of Performance of resistance to sealing agent is completed

Due to the yardstick of laboratory test instrument and on-the-spot injection device and reservoir yardstick difference very large, the conversion coefficient η obtained between blocking agent experiment injection rate and blocking agent working design injection rate through indoor and field trial evaluation is 2.59 × 10 ⁵, calculating corresponding blocking agent working design injection rate is 155L/min.

The blocking agent working design consumption determined according to A3 well data and experiment parameter and blocking agent working design injection rate calculate, and complete 40m with 155L/min speed ³the working design injection length of blocking agent is 4.3 hours, then the working design of the blocking agent normal temperature consolidated time should much larger than 43 hours, to ensure construction safety.

According to the plugging construction parameter that logistics organizations is determined be:

Blocking agent working design apparent viscosity: 22mPa.s;

Blocking agent working design injection rate: 155L/min;

The initial injection pressure of blocking agent working design: 0.0MPa;

Working design maximum pressure: 10MPa.

Embodiment 4:

Physical model of the present invention is utilized to carry out the simulating lab test before plugging construction and working design to certain oil-field thick-oil thermal recovery producing well A4 well, the reservoir maximum permeability of A4 well to be onstructed is 2000mD, minimum permeability is 500mD, 8 rounds are produced, the method utilizing physical model of the present invention and analogue experiment method to carry out working design is described for the working design of this mouthful of well and implementation result, and detailed process is as follows:

(1) the multichannel reservoir model of heavy crude heat extraction well to be onstructed is set up

The reservoir sand of A3 well output, crude oil and formation water sample is adopted to set up the reservoir model of heavy oil thermal recovery fleeing proof plug water construction well, produce the filling channel group of high, medium and low three groups of permeability range, and be full of completely with crude oil, formation water respectively, the detailed data of three filling channel groups is as follows:

High permeability filling channel group:

Filling channel H1#, length 400mm, interior diameter 20mm, outside material is High molecular weight polyethylene, and permeability is 4000mD, voids volume 136cm ³, 100% formation water.

Filling channel H2#, length 400mm, interior diameter 20mm, outside material is High molecular weight polyethylene, and permeability is 3600mD, voids volume 124cm ³, 100% formation water.

Filling channel H3#, length 400mm, interior diameter 20mm, outside material is High molecular weight polyethylene, and permeability is 3020mD, voids volume 116cm ³, 100% formation water.

Middle permeability filling channel group:

Filling channel M1#: length 400mm, interior diameter 20mm, outside material is High molecular weight polyethylene, and permeability is 1980mD, voids volume 100cm ³, wherein fluid, 40% is that formation water, 60% is for crude oil.

Filling channel M2#: length 400mm, interior diameter 20mm, outside material is High molecular weight polyethylene, and permeability is 1860mD, voids volume 96cm ³, wherein fluid, 40% is that formation water, 60% is for crude oil.

Filling channel M3#: length 400mm, interior diameter 20mm, outside material is High molecular weight polyethylene, and permeability is 1740mD, voids volume 93cm ³, wherein fluid, 40% is that formation water, 60% is for crude oil.

Filling channel M4#: length 400mm, interior diameter 20mm, outside material is High molecular weight polyethylene, and permeability is 1620mD, voids volume 89cm ³, wherein fluid, 40% is that formation water, 60% is for crude oil.

Low-permeability filling channel group:

Filling channel L1#: length 400mm, interior diameter 20mm, outside material is High molecular weight polyethylene, and permeability is 550mD, voids volume 68cm ³, 100% crude oil.

Filling channel L2#: length 400mm, interior diameter 20mm, outside material is High molecular weight polyethylene, and permeability is 450mD, voids volume 62cm ³, 100% crude oil.

Filling channel L3#: length 400mm, interior diameter 20mm, outside material is High molecular weight polyethylene, and permeability is 350mD, voids volume 59cm ³, 100% crude oil.

(2) sealing agent is carried out to the reservoir model of set up heavy crude heat extraction well to be onstructed and inject simulated test, ask for working design data

The voids volume sum of voids volume that blocking agent amount is all passages of high permeability filling channel group and all passages of 50% permeability filling channel group is injected, i.e. 565cm in (I) above-mentioned reservoir model ³.

(II) calculates A4 well shutoff water breakthrough passage by formula (IV) needs sealing agent working design injection rate:

$V_X=(M_{\mathrm{oil}}-L\×\mathrm{\π}\×r_{\mathrm{heat}}^2\×\mathrm{\φ}\×S_o)\×K_{\mathrm{channel}}\÷10000---\left(\mathrm{IV}\right)$

In formula (IV):

V _x: high seepage channel volume, m ³;

M _oil: oil well cumulative oil production, m ³;

L: straight well is core intersection, horizontal well is oil reservoir horizontal section length, m;

π：3.14；

R _heat: only rely on heat transfer, the covering radius of steam heat effect, m;

r _heatcover the average pore of pit shaft reservoir, %;

S _o: r _heatcover the average oil saturation of pit shaft reservoir, %;

K _channel: high seepage channel coefficient, span: 0.01-30%;

A4 well calculates data value, oil well cumulative oil production 7600m ³, effective pay thickiness L gets 20m, r _heat=20m, degree of porosity average oil saturation ρ=35%, K _channelvalue is 15%, then calculate V _x(i.e. the working design consumption of blocking agent) is ≈ 690m ³.

(III) opens injection pump, with certain injection rate, blocking agent is injected three groups of filling channels in parallel, and collect, measure the fluid situation of high, medium and low three groups of different permeability filling channel ports of export, in the middle of the liquid outlet quantity of permeability filling channel group port of export when reaching the 45%-55% of its voids volume, namely can be considered blocking agent arrive in the middle part of permeability filling channel group.Repetition test, continuous adjustment blocking agent experiment apparent viscosity and blocking agent experiment injection rate, make blocking agent test actual injection rate when reaching blocking agent empirical theory injection rate, the leading edge injecting sealing agent arrives the middle part of permeability filling channel group, and it is as follows to record related data:

Blocking agent experiment apparent viscosity: 20mPa.s;

Blocking agent experiment injection rate: 0.65ml/min;

Blocking agent tests initial injection pressure: 0.0MPa;

Blocking agent experiment flowing pressure gradient: 0.018MPa/ml;

Blocking agent experiment shutoff pressure: 5.0MPa;

Experiment viscous crude phase starting pressure: 6.0MPa.

(3) according to test and well information, the Design of Performance of resistance to sealing agent is completed

Due to the yardstick of laboratory test instrument and on-the-spot injection device and reservoir yardstick difference very large, the conversion coefficient η obtained between blocking agent experiment injection rate and blocking agent working design injection rate through indoor and field trial evaluation is 12.2 × 10 ⁵, calculating corresponding blocking agent working design injection rate is 793L/min.

The blocking agent working design consumption determined according to A4 well data and experiment parameter and blocking agent working design injection rate calculate, and complete 690m with 793L/min speed ³the working design injection length of blocking agent is 14.5 hours, then the working design of the blocking agent normal temperature consolidated time should much larger than 45 hours, to ensure construction safety.

According to the plugging construction parameter that logistics organizations is determined be:

Blocking agent working design apparent viscosity: 20mPa.s;

Blocking agent working design injection rate: 793L/min;

The initial injection pressure of blocking agent working design: 0.0MPa;

Working design maximum pressure: 6.0MPa.

Embodiment 5:

Physical model of the present invention is utilized to carry out the simulating lab test before plugging construction and working design to certain oil-field thick-oil thermal recovery producing well C well, the reservoir maximum permeability of C well to be onstructed is 2000mD, minimum permeability is 500mD, 10 rounds are produced, the method utilizing physical model of the present invention and analogue experiment method to carry out working design is described for the working design of this mouthful of well and implementation result, and detailed process is as follows:

(1) the multichannel reservoir model of heavy crude heat extraction well to be onstructed is set up

Because C well is long-term shutdowns well, the reservoir sand sample of this well output, crude oil sample and formation water sample can not be collected.Therefore according to interrelated data and the adjacent well situation of this well, particle diameter is selected to be that the bead of 10-40 scope is as simulated formation sand, with the viscous crude of C well periphery producing well output for simulated oil, with 20,000 salinity water of indoor preparation for simulated formation water, produce the filling channel group of high, medium and low three permeability range, and be full of completely with simulated oil, water respectively, the detailed data of three filling channel groups is as follows:

High permeability filling channel group:

Filling channel H1#, length 400mm, interior diameter 20mm, outside material is High molecular weight polyethylene, and permeability is 4000mD, voids volume 136cm ³, 100% formation water.

Filling channel H2#, length 400mm, interior diameter 20mm, outside material is High molecular weight polyethylene, and permeability is 3600mD, voids volume 124cm ³, 100% formation water.

Filling channel H3#, length 400mm, interior diameter 20mm, outside material is High molecular weight polyethylene, and permeability is 3200mD, voids volume 120cm ³, 100% formation water.

Middle permeability filling channel group:

Filling channel M1#: length 400mm, interior diameter 20mm, outside material is High molecular weight polyethylene, and permeability is 1980mD, voids volume 100cm ³, wherein fluid, 40% is that formation water, 60% is for crude oil.

Filling channel M2#: length 400mm, interior diameter 20mm, outside material is High molecular weight polyethylene, and permeability is 1900mD, voids volume 97cm ³, wherein fluid, 40% is that formation water, 60% is for crude oil.

Filling channel M3#: length 400mm, interior diameter 20mm, outside material is High molecular weight polyethylene, and permeability is 1800mD, voids volume 94cm ³, wherein fluid, 40% is that formation water, 60% is for crude oil.

Filling channel M4#: length 400mm, interior diameter 20mm, outside material is High molecular weight polyethylene, and permeability is 1700mD, voids volume 91cm ³, wherein fluid, 40% is that formation water, 60% is for crude oil.

Low-permeability filling channel group:

Filling channel L1#: length 400mm, interior diameter 20mm, outside material is High molecular weight polyethylene, and permeability is 550mD, voids volume 68cm ³, 100% crude oil.

Filling channel L2#: length 400mm, interior diameter 20mm, outside material is High molecular weight polyethylene, and permeability is 450mD, voids volume 62cm ³, 100% crude oil.

Filling channel L3#: length 400mm, interior diameter 20mm, outside material is High molecular weight polyethylene, and permeability is 350mD, voids volume 59cm ³, 100% crude oil.

(2) sealing agent is carried out to the reservoir model of the heavy crude heat extraction well to be onstructed set up and inject simulated test, ask for working design data

The voids volume sum of voids volume that blocking agent amount is all passages of high permeability filling channel group and all passages of 50% permeability filling channel group is injected, i.e. 571cm in (I) above-mentioned reservoir model ³.

(II) calculates C well shutoff water breakthrough passage by formula (IV) needs sealing agent working design injection rate:

$V_X=(M_{\mathrm{oil}}-L\×\mathrm{\π}\×r_{\mathrm{heat}}^2\×\mathrm{\φ}\×S_o)\×K_{\mathrm{channel}}\÷10000---\left(\mathrm{IV}\right)$

In formula (IV):

V _x: high seepage channel volume, m ³;

M _oil: oil well cumulative oil production, m ³;

L: straight well is core intersection, horizontal well is oil reservoir horizontal section length, m;

π：3.14；

R _heat: only rely on heat transfer, the covering radius of steam heat effect, m;

r _heatcover the average pore of pit shaft reservoir, %;

S _o: r _heatcover the average oil saturation of pit shaft reservoir, %;

K _channel: high seepage channel coefficient, span: 0.01-30%;

C well calculates data value, oil well cumulative oil production 1778m ³, effective pay thickiness L gets 7.4m, r _heat=20m, degree of porosity average oil saturation ρ=45, K _channelvalue is 27%, then calculate V _x(i.e. the working design consumption of blocking agent) is: 129.8m ³.

(III) opens injection pump, with certain injection rate, blocking agent is injected three groups of filling channels in parallel, and collect, measure the fluid situation of high, medium and low three groups of different permeability filling channel ports of export, in the middle of the liquid outlet quantity of permeability filling channel group port of export when reaching the 45%-55% of its voids volume, namely can be considered blocking agent arrive in the middle part of permeability filling channel group.Repetition test, continuous adjustment blocking agent experiment apparent viscosity and blocking agent experiment injection rate, make blocking agent test actual injection rate when reaching blocking agent empirical theory injection rate, the leading edge injecting sealing agent arrives the middle part of permeability filling channel group, and it is as follows to record related data:

Blocking agent experiment apparent viscosity: 32mPa.s;

Blocking agent experiment injection rate: 0.75ml/min;

Blocking agent tests initial injection pressure: 0.0MPa;

Blocking agent experiment flowing pressure gradient: 0.012MPa/ml;

Blocking agent experiment shutoff pressure: 8MPa;

Experiment viscous crude phase starting pressure: 9MPa.

(3) according to test and well information, optimize sealing agent performance, determine construction parameter

Due to the yardstick of laboratory test instrument and on-the-spot injection device and reservoir yardstick difference very large, the conversion coefficient η obtained between blocking agent experiment injection rate and blocking agent working design injection rate through indoor and field trial evaluation is 2.27 × 10 ⁵, calculating corresponding blocking agent working design injection rate is 170L/min.

The blocking agent working design consumption determined according to C well data and experiment parameter and blocking agent working design injection rate calculate, and complete 129.8m with 170L/min speed ³the working design injection length of blocking agent is 12.7 hours, then the working design of the blocking agent normal temperature consolidated time should much larger than 120 hours, to ensure construction safety.

(4) complete design prepares, establishment shutoff Field design.

Through above step, determine the technical data of construction control, required that blocking agent is prepared at make-up station according to blocking agent performance design, and after the assay was approved, be transported to C well well site for subsequent use.

Site operation program:

A. just blocking agent slug 130m is squeezed ³, it is 0.15m that pump speed is injected in strict control ³/ min;

B. anti-clear water displacement fluid 15m is squeezed ³, just squeezing clear water and crossing displacement fluid 20m ³.

C. closing well reaction 6-12 hour, visits punching to sand control Position on the top of the fish, adopting sewage high flow rate washover to going out well liquid clean appearance, tripping out water plugging string, prepare steam injection.

Job site technical controlling main points:

In (I) blocking agent injection process, should ensure that bottomhole injection pressure is less than viscous crude phase starting pressure 9MPa, once pressure reaches 9MPa, even if 130m ³blocking agent is injected not yet completely, also should stop immediately injecting, and starts to replace.

In (II) work progress, a cementing truck connects sleeve gate, requires to beat clear water displacement fluid according to condition of construction sleeve pipe in work progress, according to site operation situation adjustable.

(III) envelope is altered plug water construction and should be combined closely with steam injection, after envelope alters plug water construction, should start steam injection as early as possible, to promote that blocking agent is solidified, produces plugging effect.

(5) C well carries out plugging construction

On June 30th, 2013, carry out C well plugging construction in X oil recovery factory.Site operation injects temperature-sensitive phase in version Gelling Plugging Agent 130m altogether ³, strict implement designing requirement in work progress, construction results shows, the blocking agent injection pressure in site operation meets the result of the test of reservoir model in the present invention.Obtain parameter according to indoor physical simulation test method of the present invention, establishment working design, and guides construction, has ensured that plugging construction completes smoothly.

On August 11st, 2013, day production fluid 36.2t/d, day produce oil 8.4t/d after the operation of C well, comprehensive water cut drops to 76.8%, only produces and just increases oily 114t in 20 days.The C well plugging construction undertaken by the inventive method succeeds, and achieves the moisture and effect of increasing production of significant reduction.

The present inventor utilizes the reservoir model of heavy oil thermal recovery fleeing proof plug water construction well of the present invention, described reservoir model is carried out to the simulated experiment of blocking agent injection, the parameter utilizing simulated experiment to obtain is to design heavy oil thermal recovery fleeing proof plug water construction parameter, obtain heavy oil thermal recovery fleeing proof water-blocking construction method thus, and utilize the method to implement the heavy oil wells water blockoff turn-week construction of certain oil field X oil recovery factory C well.On August 11st, 2013, day production fluid 36.2t/d, day produce oil 8.4t/d after the operation of C well, comprehensive water cut drops to 76.8%, only produces and just increases oily 114t in 20 days.The C well plugging construction undertaken by the inventive method succeeds, and achieves the moisture and effect of increasing production of significant reduction.

The foregoing is only preferred embodiment of the present invention, not in order to limit the present invention, within the spirit and principles in the present invention all, any amendment done, equivalent replacement, improvement etc., all should be included within protection scope of the present invention.

Claims (12)

1. the multichannel reservoir model of a heavy crude heat extraction well to be onstructed, it comprises three filling channel groups be arranged in parallel, described filling channel is made up of the filler loaded in passage and passage, each filling channel group comprises at least 2 filling channels, and described filler comprises reservoir sand, crude oil and formation water or simulated formation sand, Simulation of Crude Oil and simulated formation water;

Three filling channel groups are respectively: high permeability filling channel group, middle permeability filling channel group and low-permeability filling channel group, wherein,

High permeability filling channel group: water surveys the 100%-200% that permeability is well reservoir maximum permeability to be onstructed, and presses filling channel quantity by permeability by 10%-40% amplification terraced distribution, and fluid wherein 100% is formation water or simulated formation water;

Middle permeability filling channel group: water surveys the 50%-99% that permeability is well reservoir maximum permeability to be onstructed, and press filling channel quantity by permeability by 10%-40% amplification terraced distribution, in fluid wherein, 40%-60% is formation water or simulated formation water, and 40%-60% is crude oil or Simulation of Crude Oil;

Low-permeability filling channel group: water surveys the 70%-110% that permeability is the minimum permeability of well reservoir to be onstructed, and presses filling channel quantity by permeability by 10%-40% amplification terraced distribution, and fluid wherein 100% is crude oil or Simulation of Crude Oil.

2. reservoir model according to claim 1, is characterized in that,

The span of the water survey permeability of high permeability filling channel group and middle permeability filling channel group is chosen according to the steam injection periodicity of well to be onstructed, wherein,

The water of high permeability filling channel group surveys permeability:

When the injection cycle is 1-2 round, choose 100%-130%;

When the injection cycle is 3-5 round, choose 131%-150%;

When the cycle of injecting >=6 round, choose 151%-200%;

The water of middle permeability filling channel group surveys permeability:

When the injection cycle is 1-6 round, choose 50%-80%;

When the cycle of injecting >=7 round, choose 81%-99%.

3. reservoir model according to claim 1 and 2, it is characterized in that, after filling channel test permeability, choose different fluid centering permeability filling channel group according to the recovery percent of reserves of well to be onstructed and carry out filling, be full of completely to make the interstitial space in each passage of middle permeability filling channel group, wherein

When recovery percent of reserves is greater than 15%, in fluid wherein, 50%-70% is formation water or simulated formation water;

When recovery percent of reserves is less than 15%, in fluid wherein, 50%-70% is crude oil or Simulation of Crude Oil.

4., according to the reservoir model in Claim 1-3 described in any one, it is characterized in that,

The radial section of described passage is polygon, circle or oval;

The material forming described passage exterior contour comprises metal, macromolecular material or hydraulicity inorganic coagulation material.

5. reservoir model according to claim 3, is characterized in that,

The cross section of described passage is circular, and the length of described passage is 200.0-1000.0mm, and internal diameter is 20.0-200.0mm;

The tubing forming described passage exterior contour is straight tube.

6. the reservoir model in claim 1-5 described in any one is carried out to an analogue experiment method for blocking agent injection, it comprises:

Steps A, injects in three filling channel groups by blocking agent;

Step B, judge to inject the middle part whether blocking agent leading edge arrives permeability filling channel group, and in blocking agent leading edge does not arrive during the middle part of permeability filling channel group, adjustment blocking agent experiment apparent viscosity and blocking agent experiment injection rate, make blocking agent test actual injection rate equal blocking agent empirical theory injection rate time, inject the middle part that blocking agent leading edge arrives permeability filling channel group;

Step C, record experimental technique parameter, described experimental technique parameter comprises blocking agent experiment apparent viscosity, blocking agent experiment injection rate, blocking agent tests initial injection pressure, blocking agent tests flowing pressure gradient, blocking agent tests shutoff pressure and experiment viscous crude phase starting pressure;

In stepb, blocking agent is kept to test actual injection rate constant;

Blocking agent tests the voids volume sum that actual injection rate is all passages in permeability filling channel group in the voids volume and 50% of all passages in high permeability filling channel group;

Described blocking agent empirical theory injection rate is the oil phase of all passages and/or the 45%-55% sum of aqueous phase volume in the aqueous phase volume of all passages in high permeability filling channel group and middle permeability filling channel group.

7. analogue experiment method according to claim 6, it is characterized in that, in stepb, when in central permeability filling channel group, the liquid outlet quantity of all channel outlets is equivalent to the 45%-55% of the voids volume of all passages in middle permeability filling channel group, be then judged as injecting the middle part that blocking agent leading edge has arrived permeability filling channel group.

8. the analogue experiment method according to claim 6 or 7, it is characterized in that, in stepb, adjustment blocking agent experiment apparent viscosity and blocking agent experiment injection rate, when making blocking agent experiment injection pressure reach blocking agent experiment shutoff force value, at least the blocking agent of 50v%-80v% is all injected among high permeability filling channel group.

9. a heavy oil thermal recovery fleeing proof water-blocking construction method, its working design technological parameter calculates according to the experimental technique parameter that the analogue experiment method in claim 6-8 described in any one obtains and obtains, wherein,

Blocking agent working design apparent viscosity equals blocking agent experiment apparent viscosity;

Working design maximum pressure equals experiment viscous crude phase starting pressure;

Blocking agent working design injection rate calculates according to formula (I):

Blocking agent working design injection rate=η × blocking agent experiment injection rate (I)

In formula (I),

The unit of blocking agent working design injection rate is L/min;

The unit of blocking agent experiment injection rate is ml/min;

η is the conversion coefficient between blocking agent experiment injection rate and blocking agent working design injection rate, calculates according to formula (II):

The span of η is 1.0 × 10 ⁵-15.0 × 10 ⁵;

The blocking agent working design normal temperature cure time be the 1-10 of blocking agent working design injection length doubly, described blocking agent working design injection length calculates according to formula (III):

10. construction method according to claim 9, is characterized in that, described blocking agent working design injection rate equals high seepage channel volume, and described high seepage channel volume calculates according to formula (IV):

$V_X=(M_{\mathrm{oil}}-L\×\mathrm{\π}\×r_{\mathrm{heat}}^2\×\mathrm{\φ}\×S_o)\×K_{\mathrm{channel}}\÷10000---\left(\mathrm{IV}\right)$

In formula (IV):

Vx: high seepage channel volume, m ³;

M _oil: oil well cumulative oil production, m ³;

L: straight well is core intersection, horizontal well is oil reservoir horizontal section length, m;

π：3.14；

R _heat: only rely on heat exchange pattern, inject the covering radius of steam heat effect, m;

r _heatcover the average pore of pit shaft reservoir, %;

S _o: r _heatcover the average oil saturation of pit shaft reservoir, %;

K _channel: high seepage channel coefficient, its span is 0.01%-30%.

11. analogue experiment methods according to claim 10, is characterized in that, the span of described high seepage channel coefficient comprises further:

The injection cycle of new brought in well is when being 1-2,0.01%-1.99%;

The injection cycle of new brought in well is when being 3-5,2.0%-4.99%;

New brought in well injection cycle >=6 rounds, 5%-10%;

For the long-term shutdowns well caused due to High water cut, 10.01%-30%.

The application in water blockoff site operation is altered in the selective envelope of thick oil thermal extraction for 12. 1 kinds according to the construction method in claim 9-11 described in any one.