CN105651665A - Method for evaluating influence of drilling and completion fluid on oil and water permeability of rock core - Google Patents
Method for evaluating influence of drilling and completion fluid on oil and water permeability of rock core Download PDFInfo
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- 230000035699 permeability Effects 0.000 title claims abstract description 158
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- VEXZGXHMUGYJMC-UHFFFAOYSA-M Chloride anion Chemical compound [Cl-] VEXZGXHMUGYJMC-UHFFFAOYSA-M 0.000 description 2
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 description 2
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- Investigation Of Foundation Soil And Reinforcement Of Foundation Soil By Compacting Or Drainage (AREA)
- Earth Drilling (AREA)
Abstract
The invention discloses a method for evaluating influence of a drilling and completion fluid on the oil and water permeability of a rock core. The method includes the steps: (1) preparing a rock core and a experimental fluid; (2) establishing irreducible water saturation and determining the oil phase permeability under an irreducible water state; (3) determining the original oil and water permeability of the rock core; and (4) determining the oil and water permeability after the drilling and completion fluid pollution; according to a value change of the oil and water relative permeability of the drilling and completion fluid before and after pollution, determining the influence of the drilling and completion fluid on the rock core. Good or bad reservoir protection effect of the drilling and completion fluid system can be evaluated; according to the method, a fluid flowing situation with the coexistence of an oil phase and a water phase in a reservoir can be fully simulated, and change laws of respective seepage abilities of the two phase fluids are obtained; compared with a traditional single-phase rock core flowing experiment, the result is more accurate, and has more guiding significance on drilling operation. The method is mainly used for evaluation of rock cores with the gas phase permeability of greater than 50 millidarcies.
Description
Technical field
The present invention relates to reservoir protection assessment technique field, particularly a kind of drilling and completing fluids in oil drilling process rock core profit permeability is affected to evaluation method.
Background technology
Reservoir protection is a system engineering through Oil/gas Well exploration and development overall process. The internal cause of formation damage is reservoir nature, and as lithology, physical property and formation water characteristic, and the external cause of formation damage is the impact of the outside fluid that enters reservoir. Wherein, the intrusion infringement of Drilling and completion fluids is the first ring of reservoir damage, contacts always and interacts at whole brill completion work progress with stratum. In the time that positive differential pressure is opened reservoir; solid phase in drilling and completing fluids and liquid phase inevitably enter reservoir; thereby the various sensitiveness of stopping up oil-gas Layer passage and bringing out reservoir; the infringements such as quick in speed, water-sensitive, acid-sensitive, salt is quick, alkali is quick, impact and the extent of damage evaluation of visible drilling and completing fluids on reservoir is the important step of reservoir protection work. Current various evaluation method is all the mensuration based on to in-place permeability, laboratory core test analysis be in various permeability determination methods the most directly, the most reliable method. By the rock core flowing experiment of simulation drilling process; investigate drilling and completing fluids to the impact of experiment core permeability; evaluate the extent of damage of oil-gas Layer; thereby preferably drilling and completing fluids formula; formulate rational reservoir protection scheme; be the major way of current each prospect pit and the work of producing well reservoir protection, be related to especially the key that can find oil-gas Layer, correctly evaluate its storage and collection performance and Oil/gas Well and can obtain high yield.
On core permeability, impact is mainly the mensuration of carrying out oleic permeability recovery rate to oil drilling industry evaluation drilling and completing fluids at present. In rock core flowing experiment, first measure rock core original permeability, after using certain drilling and completing fluids of filling a prescription to pollute, redeterminate and pollute rear core permeability, thereby obtain the situation that oleic permeability recovers. Although this method can reflect damage and the reservoir protection effect of drilling and completing fluids to rock core the most intuitively, cannot truly reflect the flow condition of formation fluid, there is certain limitation. Because while no matter carrying out oil phase or water phase permeability mensuration, in rock core, only there is a kind of fluid flowing, measure the result obtaining and only can reflect permeability variation situation when monophasic fluid passes through; But reservoir fluid profit two-phase coexistent often in actual production, therefore investigate two-phase fluid by time core permeability situation of change can reflect more exactly down-hole truth.
For the deficiencies in the prior art, the present invention intends utilizing relative permeability method of testing to investigate in the situation that oil-water two-phase flow body coexists its situation of change of permeability separately, to obtain more truly reflecting the reservoir protection data of reservoir situation. Relative permeability test is widely used in oil recovery field, the important foundation data that in porous media, multiphase porous flow is dynamic and oilfield water flooding development index is predicted can be provided, and permeability saturation curve is the requisite data in aspect such as oil field development calculation of parameter, reservoir numerical simulation and dynamic analysis. So-called relative permeability is corresponding absolute permeability. The permeability obtaining there is no physics chemical action when only having monophasic fluid to flow with rock in blowhole time is absolute permeability, and in the time that heterogeneous fluid coexists and flow in stratum, the wherein size of a certain phase fluid handling capacity in rock, just be called the effective permeability of this phase fluid, the ratio of effective permeability and absolute permeability is the relative permeability of this phase fluid. It can be the permeability of oil under air absolute permeability, 100% water/oily permeability and irreducible water state as the denominator of ratio. Be not difficult to find out, the data that conventional rock core flowing experiment method obtains are at present absolute permeabilities of oil/water phase, obtain the absolute permeability of water while measuring water phase permeability, obtain the permeability of oil under irreducible water state while measuring oleic permeability recovery rate. And the rock core flowing experiment that adopts relative permeability tester and method to carry out, mobility status can fully simulate profit two-phase coexistent in reservoir time, and obtain the two-phase fluid Changing Pattern of percolation ability separately, compare to traditional single-phase rock core flowing experiment, its result is more accurate, and wellbore construction is had more to directive significance.
According to displacement mode difference, the method for experimental determination rock core relative permeability mainly comprises steady state method and unstable state method. In steady state method test by profit by certain flow ratio simultaneously constant speed inject rock sample, unstable state method is that rock core is used to a kind of saturated with fluid in advance in testing, and carries out displacement by one other fluid. The advantage of unstable state method is that the testing time is short, and instrument and equipment is fairly simple; But more serious for anisotropism, preferentially water-wet or there is the rock core of mixed wettability, or viscosity ratio of oil and water is when very large, and be difficult to obtain reliable permeability saturation curve by unstable state method under local emulsification situation; The JBN computational methods of unstable state method are in addition loaded down with trivial details, and error is very large under above-mentioned special status. Therefore thinking and reliability two aspect factors are evaluated in integrated reservoir protection, the final employing steady state method of selecting, and profit injection ratio adopts 10:1 to 1:10, substantially can the actual seepage state of real simulation reservoir fluid. It should be noted that in addition, the main theoretical basis of the reform of Chinese economic structure that steady state method is measured oil-water relative permeability is one dimension darcy flow theory, and LOW PERMEABILITY RESERVOIR seepage flow does not meet Darcy's law, there is starting pressure and non linear fluid flow through porous medium section, seepage flow characteristics is had to larger impact, may there is certain deviation in the data obtained, therefore this method is mainly applicable to the evaluation of medium to high permeable rate rock core.
At present, also do not have other to adopt relative permeability method of testing to realize the drilling and completing fluids relevant report that impact is evaluated on rock core profit permeability.
Summary of the invention
The object of the invention is to overcome the deficiencies in the prior art, the one providing more accurately drilling and completing fluids affects evaluation method to rock core profit permeability; The method can more truly reflect reservoir fluid seepage flow situation; The method is mainly used in the evaluation of medium to high permeable rate rock core.
A kind of drilling and completing fluids of the present invention affects evaluation method to rock core profit permeability and comprises:
(1) preparation of rock core and Experimental Flowing Object:
Rock core to be measured is dried, claim dry weight, and measure its length, diameter, gas phase permeability, porosity parameter, according to concrete evaluation experimental situation preparation experiment fluid-simulated formation water and simulated oil, by rock core vacuumizing saturation simulation formation water, claim weight in wet base, determine rock core active porosity volume;
(2) set up irreducible water saturation and measure the oleic permeability under irreducible water state:
Rock core is packed in the core holding unit of dynamic core flooding test device, first measure its water phase permeability, then set up irreducible water saturation by oily expelling water method: first carry out oily expelling water with low discharge, increase gradually displacement flow until not water outlet obtains irreducible water saturation; The rock core of having set up irreducible water saturation is packed in the core holding unit of relative permeability analyzer and reach after 10-15 times of pore volume with simulated oil displacement, measure the oleic permeability under irreducible water saturation;
(3) mensuration of the original profit permeability of rock core:
Keep under the certain condition of total flow, oil, water are injected to rock core by three groups of flow proportionals of setting successively, while stablizing wait flowing, record rock core inlet and outlet pressure, oil, discharge, balance quality, the oil phase, water that calculates corresponding three groups of profit flow-rate ratios is effectively and relative permeability and corresponding water saturation;
(4) drilling and completing fluids pollutes the mensuration of rear profit permeability:
Choose experiment drilling and completing fluids, take off rock core and pack in the core holding unit of dynamic core flooding test device, a period of time formation mud cake at a certain temperature circulates, then rock core is taken out and reloaded in the core holding unit of relative permeability analyzer, the oil phase, water of measuring corresponding three groups of profit flow-rate ratios according to method in (3) effectively and relative permeability and corresponding water saturation;
The numerical value change of oil-water relative permeability before and after polluting according to drilling and completing fluids, judge the impact of this brill/completion fluid on rock core, when after polluting, the decline of rock core water relative permeability is larger, think that the mud cake that this brill/completion fluid forms has stronger plugging function, after polluting, oil relative permeability declines hour, thinks that this brill/completion fluid has from de-plugging ability.
In this evaluation method, rock core is prepared, Experimental Flowing Object preparation, set up irreducible water saturation, profit permeability determination, and the computing formula of rock core active porosity volume, water saturation, profit permeability is all according to related content in SY/T5345-2007 " two-phase fluid relative permeability assay method in rock ".
Described dynamic core flooding test device adopts JHMD-II HTHP rock core the dynamic damage evaluation system, the key technical indexes of described relative permeability analyzer: maximum loop is pressed: 60MPa, displacement pressure: 0-50MPa, maximum operation temperature: 150 DEG C, be suitable for rock core size: φ 25.4mm × (25-80) mm, displacement flow: 0-10mL/min.
The middle oleic permeability of measuring under irreducible water saturation of described step (2), when while measuring drilling and completing fluids pollution front and back profit permeability in step (3), (4), in probe temperature and step (4), drilling and completing fluids pollutes rock core, circulating temperature is 25 DEG C-120 DEG C.
When setting up irreducible water saturation in described step (2) and measuring the oleic permeability under irreducible water state, ring is pressed as 1.5MPa-12.5MPa; While measuring drilling and completing fluids pollution front and back profit permeability in step (3), (4), test wrapper is pressed as 5-15MPa; When in step (4), drilling and completing fluids pollutes rock core, ring is pressed as 6-12MPa.
While setting up irreducible water saturation in described step (2), oil expelling water displacement flow is 0.1-3.0mL/min, and low speed displacement flow is 0.1-0.3mL/min, and while measuring the oleic permeability under irreducible water state, displacement flow is 0.2-2.0mL/min.
While measuring drilling and completing fluids pollution front and back profit permeability in described step (3), (4), profit total flow is 0.5-5.0mL/min; Three groups of profit flow-rate ratios are between 10:1-1:10.
While measuring drilling and completing fluids pollution front and back profit permeability in described step (3), (4), profit total flow can be selected 1.0-3.0mL/min; Three groups of profit flow-rate ratios can be selected 10:1,5:1,3:1,2:1,3:2,1:1,2:3,1:2,1:3,1:5, any three groups of ratios among 1:10.
When in described step (4), drilling and completing fluids pollutes rock core, be 2-5h circulation timei.
When rock core packs the core holding unit of relative permeability analyzer in described step (2), (3), (4), a high rock core that oozes can respectively be added at rock core two ends in the time being no more than length range, to reduce the impact of end effect.
The present invention compared with prior art has following advantage: the mensuration of evaluation method of the present invention based on to rock core oil-water relative permeability, experiment is carried out in relative permeability analyzer, fluid mobility status can fully simulate profit two-phase coexistent in reservoir time, and obtain the two-phase fluid Changing Pattern of percolation ability separately, compare to traditional single-phase rock core flowing experiment, its result is more accurate, and wellbore construction is had more to directive significance. The method is mainly used in the evaluation that gas phase permeability is greater than the rock core of 50 millidarcies.
Detailed description of the invention
Example 1:
The reservoir protection effect of evaluation experimental slurry (formula: 6% sodium bentonite slurry+0.2% NaOH+0.2% polyacrylamide PAM+1.0%LV-CMC+3%SMP-2+3% polymeric alcohol+1.5% high temperature resistance filtrate loss reduction additive HX-KYG+2% nanoemulsions+2% oil-soluble resin); it is the artificial sand rock rock core of 1385.20 millidarcies that experiment rock core is selected gas phase permeability; porosity is 27.32%; be of a size of: length 6.21cm, diameter 2.53cm.
(1) preparation of rock core and Experimental Flowing Object:
Rock core to be measured is dried, claim dry weight, experimental temperature is selected 25 DEG C, and simulated formation water total salinity is 1000mg/L, and 25 DEG C time, viscosity isSimulated oil use crude oil and kerosene are formulated, and density is 0.84g/cm3, 25 DEG C time, viscosity isViscosity ratio of oil and water is 3.5:1; By rock core vacuumizing saturation simulation formation water, claim weight in wet base, determine rock core active porosity volume.
(2) set up irreducible water saturation and measure the oleic permeability under irreducible water state:
Rock core is packed in the core holding unit of dynamic core flooding test device, first at 25 DEG C, measure its water phase permeability KwThen set up irreducible water saturation by oily expelling water method: add ring and press 1.5MPa, the speed displacement by simulated oil with 0.2mL/min, goes out after water speed slows down to increase flow gradually until 2.0mL/min until accumulative total, constantly the water yield displaced in record, calculates the irreducible water saturation S in rock corews, until not water outlet. The rock core of having set up irreducible water saturation is packed in the core holding unit of relative permeability analyzer, add ring and press 5.5MPa, open insulating box, keep 25 DEG C of constant temperature more than 2 hours, flow with 1.0mL/min reaches after 10 times of pore volumes with simulated oil displacement, measures the oleic permeability K under irreducible water saturationo(Sws)。
(3) mensuration of the original profit permeability of rock core:
Setting ring presses as 5MPa, maintenance total flow is 2.0mL/min, the fluid-mixing that is 10:1 by oil phase/water phase flow-rate ratio at 25 DEG C injects rock core, after pressure, stability of flow, record rock core inlet and outlet pressure, oil, discharge, balance quality, unload ring and press, removal of core is weighed, and calculates water saturation SwAnd oil phase effective permeability Koe, water effective permeability Kwe, oil relative permeability KroWith water relative permeability Krw; Changing oil phase/water phase flow-rate ratio is 3:2 and 1:10, repeats above-mentioned steps, and the oil phase, water that obtains corresponding two groups of profit flow-rate ratios effectively and relative permeability and water saturation.
(4) drilling and completing fluids pollutes the mensuration of rear profit permeability:
Choose experiment drilling fluid, take off rock core and pack in the core holding unit of dynamic core flooding test device, set ring and press as 6MPa, the 2h that circulates at 25 DEG C forms mud cake; Then rock core is taken out and reloaded in the core holding unit of relative permeability analyzer, the oil phase, water of measuring corresponding three groups of profit flow-rate ratios according to method in (3) effectively and relative permeability and corresponding water saturation.
Example 2:
The reservoir protection effect of evaluation experimental slurry (formula: aluminium base polymer+2% hydrophobically modified of 5% sodium bentonite slurry+0.3%IND30+3%SMP-2+3% nanoemulsions+0.5% amido polyalcohols+0.4% starch HNC-1+1.5% nano-calcium carbonate); experiment rock core is selected the husky three sections of rock cores of blue or green eastern 8 wells of triumph; take from 1212.10～1214.15 meters of the degree of depth; porosity is 26.15%; gas phase permeability is 399.78 millidarcies; be of a size of: length 6.23cm, diameter 2.53cm.
(1) preparation of rock core and Experimental Flowing Object:
Rock core to be measured is dried, claim dry weight, according to the eastern 8 well reservoir geology situation choice experiment temperature of green grass or young crops preparation experiment fluid-simulated formation water and simulated oil; Wherein, experimental temperature is selected 46 DEG C, and simulated formation water total salinity is 4755mg/L, and chloride ion content is 1991mg/L, and potassium sodium content is 1223.72mg/L, and heavy carbonic radical content is 258mg/L, and when pH value is 8.1,46 DEG C, viscosity isSimulated oil use this block degassed crude and kerosene formulated, density is 0.92g/cm3, 46 DEG C time, viscosity isViscosity ratio of oil and water is 48:1; By rock core vacuumizing saturation simulation formation water, claim weight in wet base, determine rock core active porosity volume.
(2) set up irreducible water saturation and measure the oleic permeability under irreducible water state:
Rock core is packed in the core holding unit of dynamic core flooding test device, first at 46 DEG C, measure its water phase permeability KwThen set up irreducible water saturation by oily expelling water method: add ring and press 5.0MPa, the speed displacement by simulated oil with 0.3mL/min, goes out after water speed slows down to increase flow gradually until 3.0mL/min until accumulative total, constantly the water yield displaced in record, calculates the irreducible water saturation S in rock corews, until not water outlet. The rock core of having set up irreducible water saturation is packed in the core holding unit of relative permeability analyzer, add ring and press 8MPa, open insulating box, keep 46 DEG C of constant temperature more than 2 hours, flow with 2.0mL/min reaches after 15 times of pore volumes with simulated oil displacement, measures the oleic permeability K under irreducible water saturationo(Sws)。
(3) mensuration of the original profit permeability of rock core:
Setting ring presses as 10MPa, maintenance total flow is 3.0mL/min, the fluid-mixing that is 5:1 by oil phase/water phase flow-rate ratio at 46 DEG C injects rock core, after pressure, stability of flow, record rock core inlet and outlet pressure, oil, discharge, balance quality, unload ring and press, removal of core is weighed, and calculates water saturation SwAnd oil phase effective permeability Koe, water effective permeability Kwe, oil relative permeability KroWith water relative permeability Krw; Changing oil phase/water phase flow-rate ratio is 2:3 and 1:5, repeats above-mentioned steps, and the oil phase, water that obtains corresponding two groups of profit flow-rate ratios effectively and relative permeability and water saturation.
(4) drilling and completing fluids pollutes the mensuration of rear profit permeability:
Choose experiment drilling fluid, take off rock core and pack in the core holding unit of dynamic core flooding test device, set ring and press as 8MPa, the 3h that circulates at 46 DEG C forms mud cake; Then rock core is taken out and reloaded in the core holding unit of relative permeability analyzer, the oil phase, water of measuring corresponding three groups of profit flow-rate ratios according to method in (3) effectively and relative permeability and corresponding water saturation.
Example 3:
Evaluate the reservoir protection effect of on-the-spot slurry (formula: the coated inhibitor IND30+1.0%～1.5% high temperature resistance filtrate loss reduction additive HX-KYG+2%～3% polymeric alcohol+1%～2% natural polymer fluid loss additive NAT20+3%～5% ideal filling agent+2%～3% Waterproof lock agent YFS-3 of 5～8% sodium bentonite slurry+0.2%～0.3% NaOH+0.3%～0.5% natural polymer), experiment rock core is selected triumph field of razor clam north 326 well Dongying Formation rock cores, take from 3489.00～3502.00 meters of the degree of depth, porosity is 17.87%, gas phase permeability is 93.90 millidarcies, be of a size of: length 6.26cm, diameter 2.53cm.
(1) preparation of rock core and Experimental Flowing Object:
Rock core to be measured is dried, claim dry weight, according to field of razor clam north 326 well reservoir geology situation choice experiment temperature preparation experiment fluid-simulated formation water and simulated oil; Wherein, experimental temperature is selected 120 DEG C, and simulated formation water total salinity is 10616mg/L, and chloride ion content is 6215mg/L, and when pH value is 8,120 DEG C, viscosity isSimulated oil use this block degassed crude and kerosene formulated, density is 0.86g/cm3, 120 DEG C time, viscosity isViscosity ratio of oil and water is 1.2:1; By rock core vacuumizing saturation simulation formation water, claim weight in wet base, determine rock core active porosity volume.
(2) set up irreducible water saturation and measure the oleic permeability under irreducible water state:
Rock core is packed in the core holding unit of dynamic core flooding test device, first at 120 DEG C, measure its water phase permeability KwThen set up irreducible water saturation by oily expelling water method: add ring and press 10.0MPa, the speed displacement by simulated oil with 0.1mL/min, goes out after water speed slows down to increase flow gradually until 1.0mL/min until accumulative total, constantly the water yield displaced in record, calculates the irreducible water saturation S in rock corews, until not water outlet. The rock core of having set up irreducible water saturation is packed in the core holding unit of relative permeability analyzer, add ring and press 12.5MPa, open insulating box, keep 120 DEG C of constant temperature more than 2 hours, flow with 0.2mL/min reaches after 15 times of pore volumes with simulated oil displacement, measures the oleic permeability K under irreducible water saturationo(Sws)。
(3) mensuration of the original profit permeability of rock core:
Setting ring presses as 15MPa, maintenance total flow is 1.0mL/min, the fluid-mixing that is 3:1 by oil phase/water phase flow-rate ratio at 120 DEG C injects rock core, after pressure, stability of flow, record rock core inlet and outlet pressure, oil, discharge, balance quality, unload ring and press, removal of core is weighed, and calculates water saturation SwAnd oil phase effective permeability Koe, water effective permeability Kwe, oil relative permeability KroWith water relative permeability Krw; Changing oil phase/water phase flow-rate ratio is 1:1 and 1:3, repeats above-mentioned steps, and the oil phase, water that obtains corresponding two groups of profit flow-rate ratios effectively and relative permeability and water saturation.
(4) drilling and completing fluids pollutes the mensuration of rear profit permeability:
Choose experiment drilling fluid, take off rock core and pack in the core holding unit of dynamic core flooding test device, set ring and press as 12MPa, the 5h that circulates at 120 DEG C forms mud cake; Then rock core is taken out and reloaded in the core holding unit of relative permeability analyzer, the oil phase, water of measuring corresponding three groups of profit flow-rate ratios according to method in (3) effectively and relative permeability and corresponding water saturation.
The evaluation result of embodiment
Table 1 embodiment evaluation result
Can be found out oil phase and the water phase permeability equal decrease to some degree of rock core after drilling fluid contamination in embodiment by table 1 result. In three embodiment, water relative permeability all shows significantly and reduces, the water blockoff ability that three kinds of drilling fluid systems are described is all outstanding, especially the drilling fluid system in embodiment 2, water sealing ratiod, especially up to 96.8% left and right, is illustrated to it can effectively stop filtrate to invade reservoir in wellbore construction; In embodiment 1, after drilling fluid contamination, oil relative permeability obtains certain recovery, but recovery extent is not high; After polluting in embodiment 2, oil relative permeability still can keep higher numerical value, illustrate that this drilling fluid possesses certain for de-plugging ability, its oleic permeability is along with completion construction operation time lengthening raises gradually, can automatically return mediate stifled, infer reason be in this drilling fluid system hydrophobically modified starch and these two kinds of inorganic agents of nano-calcium carbonate can be in drilling process improvement of mud cake, in mud cake, form hydrophobic channel, set up effective oil flow channel for in-place oil flows out; After polluting in embodiment 3, oil relative permeability declines by a big margin, even exceed water phase permeability and reduced amplitude, mud cake that visible this drilling fluid system forms is all very strong to the shut-off capacity of profit, and need to after completion, carry out the means de-pluggings such as acidifying, pressure break. In sum, in embodiment 2, drilling fluid reservoir protection effect is best, is well suited for the wellbore construction for blue or green Dong8Jing.
As can be seen here; drilling and completing fluids provided by the present invention affects evaluation method to rock core profit permeability and can be used in the reservoir protection effect quality of evaluating drilling and completing fluids system; the numerical value change of oil-water relative permeability before and after polluting according to drilling and completing fluids; judge the impact of drilling and completing fluids on rock core, thus further guide field drilling fluid construction. Fluid mobility status when the method can fully be simulated profit two-phase coexistent in reservoir; and obtain the two-phase fluid Changing Pattern of percolation ability separately; compare to traditional single-phase rock core flowing experiment, its result is more accurate, aspect drilling and completing fluids reservoir protection evaluation of effect, has real value.
Claims (9)
1. drilling and completing fluids affects an evaluation method to rock core profit permeability, it is characterized in that comprising:
(1) preparation of rock core and Experimental Flowing Object:
Rock core to be measured is dried, claim dry weight, and measure its length, diameter, gas phase permeability, porosity ginsengNumber, according to concrete evaluation experimental situation preparation experiment fluid---simulated formation water and simulated oil, takes out rock coreVacuum saturation simulation formation water, claims weight in wet base, determines rock core active porosity volume;
(2) set up irreducible water saturation and measure the oleic permeability under irreducible water state:
Rock core is packed in the core holding unit of dynamic core flooding test device, first measures its water phase permeability,Then set up irreducible water saturation by oily expelling water method: first carry out oily expelling water with low discharge, increase gradually displacement streamAmount is until not water outlet obtains irreducible water saturation; Pack the rock core of having set up irreducible water saturation into phaseTo reaching after 10-15 times of pore volume with simulated oil displacement in the core holding unit of permeability detector, measure constraintOleic permeability under water saturation;
(3) mensuration of the original profit permeability of rock core:
Keep under the certain condition of total flow, oil, water injected to rock cores by three groups of flow proportionals of setting successively,While stablizing wait flowing, record rock core inlet and outlet pressure, oil, discharge, balance quality, calculates correspondenceThe oil phase of three groups of profit flow-rate ratios, water are effectively and relative permeability and corresponding water saturation;
(4) drilling and completing fluids pollutes the mensuration of rear profit permeability:
Choose experiment drilling and completing fluids, take off rock core and pack the rock core clamping of dynamic core flooding test device intoIn device, a period of time of circulating at a certain temperature forms mud cake, then rock core is taken out to reload relatively and oozesThoroughly in the core holding unit of rate analyzer, according to method in (3) measure corresponding three groups of profit flow-rate ratios oil phase,Water effectively and relative permeability and water saturation accordingly;
Before and after polluting according to drilling and completing fluids, the numerical value change of oil-water relative permeability, judges this brill/completion fluid pairThe impact of rock core, when the decline of rock core water relative permeability is larger after polluting, thinks what this brill/completion fluid formedMud cake has stronger plugging function, and after polluting, oil relative permeability declines hour, thinks this brill/completionLiquid has from de-plugging ability.
2. drilling and completing fluids as claimed in claim 1 affects evaluation method to rock core profit permeability, its featureBe: rock core described in step (1)-(4) is measured, Experimental Flowing Object preparation, set up irreducible water saturation,The calculating public affairs of profit permeability determination and rock core active porosity volume, water saturation, profit permeabilityFormula is all according to inside the Pass phase in SY/T5345-2007 " two-phase fluid relative permeability assay method in rock "Hold.
3. drilling and completing fluids as claimed in claim 1 or 2 affects evaluation method to rock core profit permeability, itsFeature is: described dynamic core flooding test device adopts JHMD-II HTHP rock core the dynamic damage to evaluateSystem.
4. drilling and completing fluids as claimed in claim 3 affects evaluation method to rock core profit permeability, its featureBe: oleic permeability, step (3) and (4) middle mensuration of in described step (2), measuring under irreducible water saturation have been boredCirculation when drilling and completing fluids pollutes rock core in probe temperature when well liquid pollutes front and back profit permeability and step (4)Temperature is 25 DEG C-120 DEG C.
5. drilling and completing fluids as claimed in claim 4 affects evaluation method to rock core profit permeability, its featureBe: the ring when setting up irreducible water saturation in described step (2) and measuring the oleic permeability under irreducible water statePress as 1.5MPa-12.5MPa; Survey while measuring drilling and completing fluids pollution front and back profit permeability in step (3), (4)Test ring is pressed as 5-15MPa; Ring when drilling and completing fluids pollutes rock core in step (4) is pressed as 6-12MPa.
6. drilling and completing fluids as claimed in claim 5 affects evaluation method to rock core profit permeability, its featureBe: the oily expelling water displacement flow while setting up irreducible water saturation in described step (2) is 0.1-3.0mL/min, lowSpeed displacement flow is 0.1-0.3mL/min, and the displacement flow while measuring the oleic permeability under irreducible water state is0.2-2.0mL/min。
7. drilling and completing fluids as claimed in claim 6 affects evaluation method to rock core profit permeability, its featureBe: the profit total flow while measuring drilling and completing fluids pollution front and back profit permeability in described step (3), (4) is0.5-5.0mL/min; Three groups of profit flow-rate ratios are between 10:1-1:10.
8. drilling and completing fluids as claimed in claim 7 affects evaluation method to rock core profit permeability, its featureBe: be 2-5h circulation timei when drilling and completing fluids pollutes rock core in described step (4).
9. drilling and completing fluids as claimed in claim 8 affects evaluation method to rock core profit permeability, its featureBe: can be not when in described step (2), (3), (4), rock core packs the core holding unit of relative permeability analyzer intoWhile exceeding length range, respectively add a high rock core that oozes at rock core two ends.
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